United States
Environmental Protection
Agency
Office of Air Quality
Planning and Standards
Research Triangle Park NC 27711
EPA-454/R-98-008
May 1998
Air
NATIONAL AIR POLLUTANT
EMISSION TRENDS,
PROCEDURES DOCUMENT,
1900-1996
Sources PM-10
Point gJ!
Area I I
On-road ^r •»,
Top 25 Emitting Point, Area, and On-road Sources of PM-10 and
VOC Emissions in 1996 by MSAs
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CONTENTS
Page
TABLES AND FIGURES xxii
ACRONYMS AND ABBREVIATIONS xxix
SECTION 1.0
INTRODUCTION 1-1
1.1 REFERENCES 1-2
SECTION 2.0
1900 - 1939 METHODOLOGY 2-1
2.1 DESCRIPTION OF EMISSION ESTIMATION METHODOLOGIES FOR SO2 AND NOX2-1
2.1.1 State-Level Estimates 2-1
2.1.2 Emissions from Fuel Combustion, Excluding On-road Vehicles 2-2
2.1.3 Emissions from Fuel Combustion by On-road Vehicles 2-3
2.1.4 Emissions from Material Processing, Manufacturing, Miscellaneous Combustion, and
Miscellaneous Burning 2-4
2.1.4.1 Coke Plants 2-4
2.1.4.2 Smelters 2-4
2.1.4.3 Cement Plants 2-5
2.1.4.4 Wildfires 2-5
2.1.4.5 Miscellaneous Industrial Processes 2-5
2.1.4.6 Miscellaneous Other Processes 2-6
2.1.5 Yearly State-Level Emissions 2-6
2.1.6 Allocation of Emission Estimates to Tier I Categories 2-7
2.2 DESCRIPTION OF EMISSION ESTIMATION METHODOLOGY FOR VOC 2-8
2.2.1 National VOC Emission Estimates (every 5 years between 1900 and 1970) 2-9
2.2.2 Yearly National Emissions 2-10
2.2.3 Changes in Emissions 2-10
2.2.4 Allocation of Emission Estimates to Tier I Categories 2-11
2.3 REFERENCES 2-11
SECTION 3.0
1940 - 1984 METHODOLOGY 3-1
3.1 INTRODUCTION 3-1
3.1.1 General Procedure 3-2
3.1.2 Organization of Procedures 3-5
3.2 FUEL COMBUSTION ELECTRIC UTILITY - COAL: 01-01 3-21
3.2.1 Technical Approach 3-21
3.2.2 Activity Indicator 3-22
3.2.3 Emission Factor 3-22
3.2.4 Control Efficiency 3-23
3.2.4.1 Anthracite Coal 3-23
3.2.4.2 Bituminous, Subbituminous, and Lignite Coal 3-23
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 111 Contents
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CONTENTS (continued)
Page
3.2.5 References 3-25
3.3 FUEL COMBUSTION ELECTRIC UTILITY - OIL: 01-02 3-27
3.3.1 Technical Approach 3-27
3.3.2 Activity Indicators 3-27
3.3.3 Emission Factors 3-28
3.3.4 Control Efficiency 3-29
3.3.5 References 3-29
3.4 FUEL COMBUSTION ELECTRIC UTILITY - GAS: 01-03 3-31
3.4.1 Technical Approach 3-31
3.4.2 Activity Indicator 3-31
3.4.3 Emission Factor 3-32
3.4.4 Control Efficiency 3-32
3.4.5 References 3-32
3.5 FUEL COMBUSTION INDUSTRIAL - COAL: 02-01 3-34
3.5.1 Technical Approach 3-34
3.5.2 Activity Indicator 3-34
3.5.3 Emission Factors 3-35
3.5.4 Control Efficiency 3-35
3.5.5 References: 3-36
3.6 FUEL COMBUSTION INDUSTRIAL - OIL: 02-02 3-38
3.6.1 Technical Approach 3-38
3.6.2 Activity Indicator 3-38
3.6.3 Emission Factor 3-39
3.6.4 Control Efficiency 3-40
3.6.5 References 3-40
3.7 FUEL COMBUSTION INDUSTRIAL - GAS: 02-03 3-42
3.7.1 Technical Approach 3-42
3.7.2 Activity Indicator 3-43
3.7.3 Emission Factor 3-43
3.7.4 Control Efficiency 3-44
3.7.5 References 3-44
3.8 FUEL COMBUSTION INDUSTRIAL - OTHER: 02-04 3-46
3.8.1 Technical Approach 3-46
3.8.2 Activity Indicator 3-46
3.8.3 Emission Factor 3-47
3.8.4 Control Efficiency 3-48
3.8.5 References 3-48
3.9 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL COAL: 03-01 ..3-50
3.9.1 Technical Approach 3-50
3.9.2 Activity Indicator 3-51
3.9.3 Emission Factors 3-52
3.9.4 Control Efficiency 3-53
3.9.5 References 3-54
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 IV Contents
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CONTENTS (continued)
Page
3.10 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL OIL: 03-02 3-56
3.10.1 Technical Approach 3-56
3.10.2 Activity Indicator 3-56
3.10.3 Emission Factor 3-57
3.10.4 Control Efficiency 3-57
3.10.5 References 3-58
3.11 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL GAS: 03-03 3-59
3.11.1 Technical Approach 3-59
3.11.2 Activity Indicator 3-59
3.11.3 Emission Factor 3-60
3.11.4 Control Efficiency 3-60
3.11.5 References 3-60
3.12 FUEL COMBUSTION OTHER - RESIDENTIAL WOOD: 03-05 3-61
3.12.1 Technical Approach 3-61
3.12.2 Activity Indicator 3-61
3.12.3 Emission Factor 3-62
3.12.4 Control Efficiency 3-63
3.12.5 References 3-63
3.13 FUEL COMBUSTION OTHER - RESIDENTIAL OTHER: 03-06 3-64
3.13.1 Technical Approach: 3-64
3.13.2 Activity Indicator: 3-65
3.13.3 Emission Factors: 3-66
3.13.4 Control Efficiency 3-67
3.13.5 References 3-67
3.14 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - ORGANIC CHEMICAL
MANUFACTURING: 04-01 3-69
3.14.1 Technical Approach 3-69
3.14.2 Activity Indicator 3-69
3.14.2.1 CO Emissions 3-69
3.14.2.2 NOX Emissions 3-70
3.14.2.3 PM-10 and TSP Emissions 3-70
3.14.2.4 VOC Emissions 3-70
3.14.3 Emission Factor 3-70
3.14.3.1 CO Emissions 3-70
3.14.3.2 NOX Emissions 3-71
3.14.3.3 PM-10 and TSP Emissions 3-71
3.14.3.4 VOC Emissions 3-71
3.14.4 Control Efficiency 3-72
3.14.4.1 CO Emissions 3-72
3.14.4.2 NOX Emissions 3-72
3.14.4.3 PM-10 and TSP Emissions 3-72
3.14.4.4 VOC Emissions 3-72
3.14.5 References 3-73
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 V Contents
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CONTENTS (continued)
Page
3.15 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - INORGANIC
CHEMICAL MANUFACTURING: 04-02 3-77
3.15.1 Technical Approach 3-77
3.15.2 Activity Indicator 3-78
3.15.2.1 CO Emissions 3-78
3.15.2.2 NOX Emissions 3-78
3.15.2.3 PM-10 and TSP Emissions 3-78
3.15.2.4 SO2 Emissions 3-78
3.15.2.5 VOC Emissions 3-78
3.15.3 Emission Factor 3-78
3.15.3.1 CO Emissions 3-78
3.15.3.2 NOX Emissions 3-79
3.15.3.3 PM-10 and TSP Emissions 3-79
3.15.3.4 SO2 Emissions 3-79
3.15.3.5 VOC Emissions 3-79
3.15.4 Control Efficiency 3-80
3.15.5 References 3-80
3.16 CHEMICAL AND ALLIED PRODUCTS MANUFACTURING - POLYMER AND
RESIN MANUFACTURING: 04-03 3-82
3.16.1 Technical Approach 3-82
3.16.2 Activity Indicator 3-82
3.16.3 Emission Factor 3-82
3.16.4 Control Efficiency 3-83
3.16.5 References 3-83
3.17 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - AGRICULTURAL
CHEMICAL MANUFACTURING: 04-04 3-85
3.17.1 Technical Approach 3-85
3.17.2 Activity Indicator 3-85
3.17.3 Emission Factor 3-86
3.17.4 Control Efficiency 3-86
3.17.5 References 3-87
3.18 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - PAINT, VARNISH,
LACQUER, AND ENAMEL MANUFACTURING: 04-05 3-89
3.18.1 Technical Approach 3-89
3.18.2 Activity Indicator 3-89
3.18.3 Emission Factor 3-89
3.18.4 Control Efficiency 3-89
3.18.5 References 3-90
3.19 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - PHARMACEUTICAL
MANUFACTURING: 04-06 3-91
3.19.1 Technical Approach 3-91
3.19.2 Activity Indicator 3-91
3.19.3 Emission Factor 3-91
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CONTENTS (continued)
Page
3.19.4 Control Efficiency 3-91
3.19.5 References 3-91
3.20 CHEMICAL AND ALLIED PRODUCTS MANUFACTURING - OTHER CHEMICAL
MANUFACTURING: 04-07 3-92
3.20.1 Technical Approach 3-92
3.20.2 Activity Indicator 3-92
3.20.2.1 CO Emissions 3-92
3.20.2.2 PM-10 and TSP Emissions 3-93
3.20.2.3 SO2 Emissions 3-93
3.20.2.4 VOC Emissions 3-93
3.20.3 Emission Factor 3-93
3.20.3.1 CO Emissions 3-93
3.20.3.2 PM-10 and TSP Emissions 3-94
3.20.3.3 SO2 Emissions 3-94
3.20.3.4 VOC Emissions 3-94
3.20.4 Control Efficiency 3-95
3.20.4.1 CO Emissions 3-95
3.20.4.2 PM-10 and TSP Emissions 3-95
3.20.4.3 SO2 Emissions 3-95
3.20.4.4 VOC Emissions 3-96
3.20.5 References 3-96
3.21 METALS PROCESSING - NONFERROUS: 05-01 3-97
3.21.1 Technical Approach 3-97
3.21.2 Activity Indicator 3-98
3.21.2.1 CO Emissions 3-98
3.21.2.2 PM-10 and TSP Emissions 3-98
3.21.2.3 SO2 Emissions 3-99
3.21.3 Emission Factor 3-101
3.21.3.1 CO Emissions 3-101
3.21.3.2 PM-10 and TSP Emissions 3-101
3.21.3.3 SO2 Emissions 3-104
3.21.4 Control Efficiency 3-104
3.21.4.1 CO Emissions 3-104
3.21.4.2 PM-10 and TSP Emissions 3-104
3.21.4.3 SO2 Emissions 3-105
3.21.5 References 3-105
3.22 METALS PROCESSING - FERROUS: 05-02 3-110
3.22.1 Technical Approach 3-110
3.22.2 Activity Indicator 3-111
3.22.2.1 CO Emissions 3-111
3.22.2.2 NOX Emissions 3-111
3.22.2.3 PM-10 and TSP Emissions 3-111
3.22.2.4 SO2 Emissions 3-113
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CONTENTS (continued)
Page
3.22.2.5 VOC Emissions 3-113
3.22.3 Emission Factor 3-114
3.22.3.1 CO Emissions 3-114
3.22.3.2 NOX Emissions 3-114
3.22.3.3 PM-10 and TSP Emissions 3-115
3.22.3.4 SO2 Emissions 3-117
3.22.3.5 VOC Emissions 3-118
3.22.4 Control Efficiency 3-118
3.22.4.1 CO Emissions 3-118
3.22.4.2 NOX Emissions 3-119
3.22.4.3 PM-10 and TSP Emissions 3-119
3.22.4.4 SO2 Emissions 3-121
3.22.4.5 VOC Emissions 3-121
3.22.5 References 3-121
3.23 METALS PROCESSING - NOT ELSEWHERE CLASSIFIED: 05-03 3-124
3.23.1 Technical Approach 3-124
3.23.2 Activity Indicator 3-124
3.23.3 Emission Factor 3-125
3.23.4 Control Efficiency 3-125
3.23.5 References 3-126
3.24 PETROLEUM AND RELATED INDUSTRIES - OIL AND GAS PRODUCTION: 06-
01 3-128
3.24.1 Technical Approach 3-128
3.24.2 Activity Indicator 3-128
3.24.3 Emission Factor 3-128
3.24.4 Control Efficiency 3-129
3.24.5 References 3-129
3.25 PETROLEUM AND RELATED INDUSTRIES - PETROLEUM REFINERIES AND
RELATED INDUSTRIES: 06-02 3-130
3.25.1 Technical Approach 3-130
3.25.2 Activity Indicator 3-131
3.25.2.1 CO Emissions 3-131
3.25.2.2 NOX Emissions 3-131
3.25.2.3 PM-10 and TSP Emissions 3-131
3.25.2.4 SO2 Emissions 3-132
3.25.2.5 VOC Emissions 3-132
3.25.3 Emission Factor 3-133
3.25.3.1 CO Emissions 3-133
3.25.3.2 NOX Emissions 3-133
3.25.3.3 PM-10 and TSP Emissions 3-133
3.25.3.4 SO2 Emissions 3-133
3.25.3.5 VOC Emissions 3-133
3.25.4 Control Efficiency 3-134
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CONTENTS (continued)
Page
3.25.4.1 CO Emissions 3-134
3.25.4.2 NOX Emissions 3-134
3.25.4.3 PM-10 and TSP Emissions 3-134
3.25.4.4 VOC Emissions 3-134
3.25.5 References 3-136
3.26 PETROLEUM AND RELATED INDUSTRIES - ASPHALT MANUFACTURING:
06-03 3-138
3.26.1 Technical Approach 3-138
3.26.2 Activity Indicator 3-138
3.26.3 Emission Factor 3-139
3.26.4 Control Efficiency 3-139
3.26.5 References 3-140
3.27 OTHER INDUSTRIAL PROCESSES - AGRICULTURE, FOOD, AND KINDRED
PRODUCTS: 07-01 3-142
3.27.1 Technical Approach 3-142
3.27.2 Activity Indicator 3-143
3.27.2.1 PM-10 and TSP Emissions 3-143
3.27.2.2 VOC Emissions 3-144
3.27.3 Emission Factor 3-144
3.27.3.1 PM-10 and TSP Emissions 3-144
3.27.3.2 VOC Emissions 3-145
3.27.4 Control Efficiency 3-145
3.27.4.1 PM-10 and TSP Emissions 3-145
3.27.4.2 VOC Emissions 3-146
3.27.5 References 3-146
3.28 OTHER INDUSTRIAL PROCESSES - WOOD, PULP AND PAPER, AND
PUBLISHING PRODUCTS: 07-03 3-149
3.28.1 Technical Approach 3-149
3.28.2 Activity Indicator 3-149
3.28.3 Emission Factor 3-150
3.28.4 Control Efficiency 3-151
3.28.5 References 3-152
3.29 OTHER INDUSTRIAL PROCESSES - RUBBER AND MISCELLANEOUS PLASTIC
PRODUCTS: 07-04 3-154
3.29.1 Technical Approach 3-154
3.29.2 Activity Indicator 3-154
3.29.3 Emission Factor 3-154
3.29.4 Control Efficiency 3-154
3.29.5 References 3-154
3.30 OTHER INDUSTRIAL PROCESSES - MINERAL PRODUCTS: 07-05 3-156
3.30.1 Technical Approach 3-156
3.30.2 Activity Indicator 3-157
3.30.2.1 CO Emissions 3-157
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Procedures Document for 1900-1996 IX Contents
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CONTENTS (continued)
Page
3.30.2.2 NOX Emissions 3-157
3.30.2.3 PM-10 and TSP Emissions 3-157
3.30.2.4 SO2 Emissions 3-158
3.30.2.5 VOC Emissions 3-159
3.30.3 Emission Factor 3-159
3.30.3.1 CO Emissions 3-159
3.30.3.2 NOX Emissions 3-159
3.30.3.3 PM-10 and TSP Emissions 3-159
3.30.3.4 SO2 Emissions 3-162
3.30.3.5 VOC Emissions 3-163
3.30.4 Control Efficiency 3-163
3.30.4.1 CO, NOX, SO2, and VOC Emissions 3-163
3.30.4.2 PM-10 and TSP Emissions 3-164
3.30.5 References 3-165
3.31 SOLVENT UTILIZATION - DECREASING: 08-01 3-170
3.31.1 Technical Approach 3-170
3.31.2 Activity Indicator 3-170
3.31.3 Emission Factor 3-170
3.31.4 Control Efficiency 3-170
3.31.5 References 3-171
3.32 SOLVENT UTILIZATION - GRAPHIC ARTS: 08-02 3-172
3.32.1 Technical Approach 3-172
3.32.2 Activity Indicator 3-172
3.32.3 Emission Factor 3-172
3.32.4 Control Efficiency 3-172
3.32.5 References 3-173
3.33 SOLVENT UTILIZATION - DRY CLEANING: 08-03 3-174
3.33.1 Technical Approach 3-174
3.33.2 Activity Indicator 3-174
3.33.3 Emission Factor 3-174
3.33.4 Control Efficiency 3-174
3.33.5 References 3-174
3.34 SOLVENT UTILIZATION - SURFACE COATINGS: 08-04 3-176
3.34.1 Technical Approach 3-176
3.34.2 Activity Indicator 3-176
3.34.3 Emission Factor 3-178
3.34.4 Control Efficiency 3-178
3.34.5 References 3-179
3.35 SOLVENT UTILIZATION - OTHER INDUSTRIAL: 08-05 3-184
3.35.1 Technical Approach 3-184
3.35.2 Activity Indicator 3-184
3.35.3 Emission Factor 3-185
3.35.4 Control Efficiency 3-185
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CONTENTS (continued)
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3.35.5 References 3-185
3.36 SOLVENT UTILIZATION - NONINDUSTRIAL: 08-06 3-187
3.36.1 Technical Approach 3-187
3.36.2 Activity Indicator 3-187
3.36.3 Emission Factor 3-188
3.36.4 Control Efficiency 3-188
3.36.5 References 3-188
3.37 STORAGE AND TRANSPORT - BULK TERMINALS AND PLANTS: 09-01 . . 3-190
3.37.1 Technical Approach 3-190
3.37.2 Activity Indicator 3-190
3.37.3 Emission Factor 3-190
3.37.4 Control Efficiency 3-190
3.37.5 References 3-191
3.38 STORAGE AND TRANSPORT - PETROLEUM AND PETROLEUM PRODUCT
STORAGE: 09-02 3-192
3.38.1 Technical Approach 3-192
3.38.2 Activity Indicator 3-192
3.38.3 Emission Factor 3-193
3.38.4 Control Efficiency 3-193
3.38.5 References 3-193
3.39 STORAGE AND TRANSPORT - PETROLEUM AND PETROLEUM PRODUCT
TRANSPORT: 09-03 3-194
3.39.1 Technical Approach 3-194
3.39.2 Activity Indicator 3-194
3.39.3 Emission Factor 3-195
3.39.4 Control Efficiency 3-195
3.39.5 References 3-195
3.40 STORAGE AND TRANSPORT - SERVICE STATIONS: STAGE I: 09-04 3-196
3.40.1 Technical Approach 3-196
3.40.2 Activity Indicator 3-196
3.40.3 Emission Factor 3-196
3.40.4 Control Efficiency 3-196
3.40.5 References 3-197
3.41 STORAGE AND TRANSPORT - SERVICE STATIONS: STAGE II: 09-05 3-198
3.41.1 Technical Approach 3-198
3.41.2 Activity Indicator 3-198
3.41.3 Emission Factor 3-198
3.41.4 Control Efficiency 3-198
3.41.5 References 3-199
3.42 STORAGE AND TRANSPORT - ORGANIC CHEMICAL STORAGE: 09-07 ..3-200
3.42.1 Technical Approach 3-200
3.42.2 Activity Indicator 3-200
3.42.3 Emission Factor 3-200
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CONTENTS (continued)
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3.42.4 Control Efficiency 3-200
3.42.5 References 3-200
3.43 WASTE DISPOSAL AND RECYCLING - INCINERATION: 10-01 3-202
3.43.1 Technical Approach 3-202
3.43.2 Activity Indicator 3-202
3.43.3 Emission Factor 3-203
3.43.4 Control Efficiency 3-204
3.43.5 References 3-204
3.44 WASTE DISPOSAL AND RECYCLING - OPEN BURNING: 10-02 3-205
3.44.1 Technical Approach 3-205
3.44.2 Activity Indicator 3-205
3.44.3 Emission Factor 3-206
3.44.4 Control Efficiency 3-206
3.44.5 References 3-206
3.45 WASTE DISPOSAL AND RECYCLING - OTHER: 10-07 3-207
3.45.1 Technical Approach 3-207
3.45.2 Activity Indicator 3-207
3.45.3 Emission Factor 3-207
3.45.4 Control Efficiency 3-207
3.45.5 References 3-207
3.46 ON-ROAD VEHICLES: 11 3-208
3.46.1 Technical Approach 3-208
3.46.2 Activity Indicator 3-208
3.46.3 Emission Factors 3-212
3.46.4 Calculation of Emissions 3-213
3.46.5 References 3-214
3.47 NON-ROAD ENGINES AND VEHICLES - NON-ROAD GASOLINE
ENGINES: 12-01 3-218
3.47.1 Technical Approach 3-218
3.47.2 Activity Indicator 3-219
3.47.3 Emission Factor 3-220
3.47.4 Control Efficiency 3-221
3.47.5 References 3-221
3.48 NON-ROAD ENGINES AND VEHICLES - NON-ROAD DIESEL ENGINES:
12-02 3-224
3.48.1 Technical Approach 3-224
3.48.2 Activity Indicator 3-224
3.48.3 Emission Factor 3-225
3.48.4 Control Efficiency 3-225
3.48.5 References 3-225
3.49 NON-ROAD ENGINES AND VEHICLES - AIRCRAFT: 12-03 3-227
3.49.1 Technical Approach 3-227
3.49.2 Activity Indicator 3-227
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Procedures Document for 1900-1996 xii Contents
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CONTENTS (continued)
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3.49.3 Emission Factor 3-228
3.49.4 Control Efficiency 3-229
3.49.5 References 3-230
3.50 NON-ROAD ENGINES AND VEHICLES - MARINE VESSELS: 12-04 3-232
3.50.1 Technical Approach 3-232
3.50.2 Activity Indicator 3-232
3.50.3 Emission Factor 3-233
3.50.4 Control Efficiency 3-234
3.50.5 References 3-234
3.51 NON-ROAD ENGINES AND VEHICLES - RAILROADS: 12-05 3-235
3.51.1 Technical Approach 3-235
3.51.2 Activity Indicator 3-235
3.51.3 Emission Factor 3-236
3.51.4 Control Efficiency 3-236
3.51.5 References 3-236
3.52 MISCELLANEOUS - OTHER COMBUSTION: 14-02 3-237
3.52.1 Technical Approach 3-237
3.52.2 Activity Indicator 3-237
3.52.3 Emission Factor 3-238
3.52.4 Control Efficiency 3-239
3.52.5 References 3-239
SECTION 4.0
NATIONAL CRITERIA POLLUTANT ESTIMATES
1985 - 1996 METHODOLOGY 4-1
4.1 INTRODUCTION 4-1
4.1.1 Lead Emissions 4-2
4.1.2 Carbon Monoxide, Nitrogen Oxides, Volatile Organic Compounds, Sulfur Dioxide,
Particulate Matter (PM-10 and PM-2.5), and Ammonia Emissions 4-2
4.1.3 References 4-2
4.2 FUEL COMBUSTION - ELECTRIC UTILITY 4-23
4.2.1 1985-1995 Steam Electric Utility Emission Inventories 4-23
4.2.1.1 Processing Computerized Raw Data 4-24
4.2.1.2 Emissions Algorithms 4-25
4.2.1.3 National Allowance Data Base (NADB) SO2 Emissions and Heat Input . . . 4-27
4.2.1.4 1985-1994 Acid Rain Division (ARD) NOX Rates 4-27
4.2.1.5 1994 and 1995 ETS/CEM Data 4-27
4.2.1.6 Ozone Season Daily Emissions Data 4-28
4.2.2 1996 Steam Emission Inventory 4-28
4.2.3 Augmentation Process 4-29
4.2.4 Sample Calculation 4-29
4.2.5 References 4-29
4.3 INDUSTRIAL 4-36
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Procedures Document for 1900-1996 xiii Contents
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CONTENTS (continued)
Page
4.3.1 1990 Interim Inventory 4-37
4.3.1.1 Control Efficiency Revisions 4-38
4.3.1.2 Rule Effectiveness Assumptions 4-38
4.3.1.3 Emission Factor Changes 4-39
4.3.1.4 Emissions Calculations 4-40
4.3.1.5 Revised Emissions 4-41
4.3.2 Emissions, 1985 to 1989 4-42
4.3.2.1 Point Source Growth 4-42
4.3.2.2 Area Source Growth 4-43
4.3.3 1990 National Emission Trends 4-44
4.3.3.1 OTAG 4-44
4.3.3.2 Grand Canyon Visibility Transport Commission Inventory 4-48
4.3.3.3 AIRS/FS 4-48
4.3.3.4 Data Gaps 4-48
4.3.4 Emissions, 1991 to 1994 4-50
4.3.4.1 Grown Estimates 4-50
4.3.4.2 AIRS/FS 4-51
4.3.5 1995 Emissions 4-52
4.3.5.1 Grown Estimate 4-52
4.3.5.2 NOX RACT 4-52
4.3.5.3 Rule Effectiveness 4-52
4.3.5.4 Cotton Ginning 4-53
4.3.6 1996 Emissions 4-56
4.3.6.1 Grown Estimates 4-56
4.3.6.2 1996 VOC Controls 4-57
4.3.6.3 NOX Controls 4-60
4.3.7 References 4-60
4.4 OTHER COMBUSTION 4-101
4.4.1 1990 Interim Inventory 4-102
4.4.1.1 Control Efficiency Revisions 4-103
4.4.1.2 Rule Effectiveness Assumptions 4-104
4.4.1.3 Emissions Calculations 4-104
4.4.2 Emissions, 1985 to 1989 4-105
4.4.2.1 Point Source Growth 4-105
4.4.2.2 Area Source Growth 4-106
4.4.3 1990 National Emission Trends 4-106
4.4.3.1 OTAG 4-107
4.4.3.2 GCVTC Inventory 4-110
4.4.3.3 AIRS/FS 4-111
4.4.3.4 Data Gaps 4-111
4.4.4 Emissions, 1991 to 1994 4-113
4.4.4.1 Grown Estimates 4-113
4.4.4.2 AIRS/FS 4-114
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 xiv Contents
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CONTENTS (continued)
Page
4.4.5 1995 Emissions 4-115
4.4.5.1 Grown Estimate 4-115
4.4.5.2 NOX RACT 4-115
4.4.5.3 Rule Effectiveness 4-115
4.4.6 1996 Emissions 4-115
4.4.7 Alternative Base Inventory Calculations 4-116
4.4.7.1 Forest Fires/Wildfires 4-116
4.4.7.2 Prescribed/Slash and Managed Burning 4-118
4.4.7.3 Residential Wood 4-118
4.4.7.4 SO2 and PM Residential Nonwood Combustion 4-121
4.4.8 References 4-121
4.5 SOLVENT UTILIZATION 4-140
4.5.1 1990 Interim Inventory 4-140
4.5.1.1 Area Source Emissions, VOC Only 4-141
4.5.1.2 Point Sources, All Pollutants 4-143
4.5.2 Emissions, 1985 to 1989 4-145
4.5.2.1 Area Sources 4-145
4.5.2.2 Point Sources 4-145
4.5.3 1990 National Emission Trends 4-146
4.5.3.1 OTAG 4-146
4.5.3.2 Grand Canyon Visibility Transport Commission Inventory 4-150
4.5.3.3 AIRS/FS 4-151
4.5.3.4 Data Gaps 4-151
4.5.4 Emissions, 1991 to 1994 4-152
4.5.4.1 Grown Estimates 4-152
4.5.4.2 AIRS/FS 4-153
4.5.5 1995 Emissions 4-154
4.5.5.1 Grown Estimate 4-154
4.5.5.2 Rule Effectiveness 4-154
4.5.6 1996 Emissions 4-155
4.5.6.1 Grown Estimates 4-155
4.5.6.2 1996 VOC Controls 4-155
4.5.7 References 4-156
4.6 ON-ROAD VEHICLES 4-175
4.6.1 VMT 4-175
4.6.1.1 Background on Highway Performance Monitoring System 4-175
4.6.1.2 Distribution of HPMS VMT, 1980 to 1995 4-176
4.6.1.3 Distribution of VMT, 1970 to 1979 and 1996 4-179
4.6.1.4 State-Provided 1990 VMT 4-180
4.6.2 Development of VOC, NOX, and CO Emission Factors 4-180
4.6.2.1 Temperature 4-180
4.6.2.2 RVP 4-181
4.6.2.3 Speed 4-183
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XV Contents
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CONTENTS (continued)
Page
4.6.2.4 Operating Mode 4-184
4.6.2.5 Altitude 4-184
4.6.2.6 Registration Distribution/Month 4-184
4.6.2.7 MONTH Flag 4-189
4.6.2.8 Additional Area Specific Inputs from OTAG 4-189
4.6.2.9 Control Program Inputs 4-189
4.6.3 Development of PM and SO2 Emission Factors 4-193
4.6.3.1 Registration Distribution 4-193
4.6.3.2 Speed 4-194
4.6.3.3 HDDV Vehicle Class Weighting 4-194
4.6.3.4 Exhaust PM Emissions 4-194
4.6.3.5 Exhaust SO2 Emissions 4-194
4.6.3.6 PM Brake Wear Emissions 4-194
4.6.3.7 PM Tire Wear Emissions 4-195
4.6.3.8 1970 to 1984 PM and SO2 Emissions 4-195
4.6.4 Calculation of Ammonia (NH3) Emission Factors 4-197
4.6.5 Calculation of Emissions 4-198
4.6.6 References 4-199
4.7 NON-ROAD ENGINES AND VEHICLES 4-245
4.7.1 1990 Interim Inventory 4-245
4.7.1.1 Non-road Engines and Vehicle Emissions 4-245
4.7.1.2 Aircraft, Marine Vessels and Railroads 4-246
4.7.2 Emissions, 1970 through 1989 4-250
4.7.3 1990 National Emissions Trends 4-250
4.7.4 Emissions, 1991 through 1994 4-251
4.7.5 1995 Emissions 4-253
4.7.6 1996 Emissions 4-253
4.7.6.1 Grown Estimates 4-253
4.7.6.2 Non-road Engine Controls-Spark-Ignition Engines < 25 hp 4-253
4.7.6.3 Non-road Diesel Engines 4-254
4.7.7 1995 and 1996 Emission Revisions 4-254
4.7.8 References 4-255
4.8 FUGITIVE DUST 4-270
4.8.1 Natural Sources, Geogenic, Wind Erosion 4-270
4.8.1.1 Determination of Correction Parameters 4-271
4.8.1.2 1990-1996 Modification 4-272
4.8.1.3 Activity Data 4-272
4.8.1.4 County Distribution (1985-1989) 4-272
4.8.1.5 County Distribution (1990-1996) 4-272
4.8.2 Miscellaneous Sources 4-273
4.8.2.1 Agricultural Crops (1985-1989) 4-273
4.8.2.3 Agricultural Livestock 4-276
4.8.2.4 PM Emissions from Reentrained Road Dust from Unpaved Roads 4-277
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 xvi Contents
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CONTENTS (continued)
Page
4.8.2.5 PM Emissions from Reentrained Road Dust from Paved Roads 4-281
4.8.2.6 Calculation of PM-2.5 Emissions from Paved and Unpaved Roads 4-283
4.8.2.7 Other Fugitive Dust Sources 4-283
4.8.2.8 Grown Emissions 4-288
4.8.9 References 4-296
SECTION 5.0
LEAD EMISSIONS METHODOLOGY 5-1
5.1 INTRODUCTION 5-1
5.1 INTRODUCTION 5-1
5.1.1 Background 5-1
5.1.2 General Procedure 5-1
5.1.3 Organization of Procedures 5-2
5.2 FUEL COMBUSTION ELECTRIC UTILITY - COAL: 01-01 5-7
5.2.1 Technical Approach 5-7
5.2.2 Activity Indicator 5-7
5.2.3 Emission Factor 5-7
5.2.4 Control Efficiency 5-7
5.2.5 References 5-8
5.3 FUEL COMBUSTION ELECTRIC UTILITY - OIL: 01-02 5-9
5.3.1 Technical Approach 5-9
5.3.2 Activity Indicators 5-9
5.3.3 Emission Factors 5-9
5.3.4 Control Efficiency 5-9
5.3.5 References 5-10
5.4 FUEL COMBUSTION INDUSTRIAL - COAL: 02-01 5-11
5.4.1 Technical Approach 5-11
5.4.2 Activity Indicator 5-11
5.4.3 Emission Factors 5-11
5.4.4 Control Efficiency 5-11
5.4.5 References 5-12
5.5 FUEL COMBUSTION INDUSTRIAL - OIL: 02-02 5-13
5.5.1 Technical Approach 5-13
5.5.2 Activity Indicator 5-13
5.5.3 Emission Factor 5-13
5.5.4 Control Efficiency 5-14
5.5.5 References 5-14
5.6 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL COAL: 03-01 ..5-15
5.6.1 Technical Approach 5-15
5.6.2 Activity Indicator 5-15
5.6.3 Emission Factors 5-16
5.6.4 Control Efficiency 5-16
5.6.5 References 5-17
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 xvii Contents
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CONTENTS (continued)
Page
5.7 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL OIL: 03-02 5-18
5.7.1 Technical Approach 5-18
5.7.2 Activity Indicator 5-18
5.7.3 Emission Factor 5-18
5.7.4 Control Efficiency 5-18
5.7.5 References 5-19
5.8 FUEL COMBUSTION OTHER - MISCELLANEOUS FUEL COMBUSTION (EXCEPT
RESIDENTIAL): 03-04 5-20
5.8.1 Technical Approach 5-20
5.8.2 Activity Indicator 5-20
5.8.3 Emission Factor 5-20
5.8.4 Control Efficiency 5-20
5.8.5 References 5-20
5.9 FUEL COMBUSTION OTHER - RESIDENTIAL OTHER: 03-06 5-22
5.9.1 Technical Approach 5-22
5.9.2 Activity Indicator 5-22
5.9.3 Emission Factors 5-23
5.9.4 Control Efficiency 5-23
5.9.5 References 5-23
5.10 CHEMICAL AND ALLIED PRODUCT MANUFACTURE - INORGANIC CHEMICAL
MANUFACTURE: 04-02 5-25
5.10.1 Technical Approach 5-25
5.10.2 Activity Indicator 5-25
5.10.3 Emission Factor 5-25
5.10.4 Control Efficiency 5-25
5.10.5 References 5-25
5.11 METALS PROCESSING - NONFERROUS: 05-01 5-26
5.11.1 Technical Approach 5-26
5.11.2 Activity Indicator 5-26
5.11.2.1 Nonferrous Metals 5-26
5.11.2.2 Secondary Metals 5-27
5.11.2.3 Miscellaneous Process Sources 5-27
5.11.3 Emission Factor 5-28
5.11.3.1 Nonferrous Metals 5-28
5.11.3.2 Secondary Metals 5-28
5.11.3.3 Miscellaneous Process Sources 5-28
5.11.4 Control Efficiency 5-28
5.11.4.1 Nonferrous Metals 5-28
5.11.4.2 Secondary Metals 5-28
5.11.4.3 Miscellaneous Process Sources 5-28
5.11.5 References 5-29
5.12 METALS PROCESSING - FERROUS: 05-02 5-30
5.12.1 Technical Approach 5-30
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 xviii Contents
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CONTENTS (continued)
Page
5.12.2 Activity Indicator 5-30
5.12.2.1 Iron and Steel 5-30
5.12.2.2 Nonferrous Metals 5-31
5.12.2.3 Secondary Metals 5-31
5.12.3 Emission Factor 5-31
5.12.3.1 Iron and Steel 5-31
5.12.3.2 Nonferrous Metals 5-31
5.12.3.3 Secondary Metals - Grey Iron Foundries 5-31
5.12.4 Control Efficiency 5-32
5.12.5 References 5-32
5.13 METALS PROCESSING - NOT ELSEWHERE CLASSIFIED: 05-03 5-34
5.13.1 Technical Approach 5-34
5.13.2 Activity Indicator 5-34
5.13.3 Emission Factor 5-34
5.13.4 Control Efficiency 5-34
5.13.5 References 5-35
5.14 OTHER INDUSTRIAL PROCESSES - MINERAL PRODUCTS: 07-05 5-36
5.14.1 Technical Approach 5-36
5.14.2 Activity Indicator 5-36
5.14.3 Emission Factor 5-36
5.14.4 Control Efficiency 5-36
5.14.5 References 5-37
5.15 OTHER INDUSTRIAL PROCESSES - MISCELLANEOUS INDUSTRIAL
PRODUCTS: 07-10 5-38
5.15.1 Technical Approach 5-38
5.15.2 Activity Indicator 5-38
5.15.3 Emission Factor 5-39
5.15.4 Control Efficiency 5-39
5.15.5 References 5-39
5.16 WASTE DISPOSAL AND RECYCLING : 10-01 5-40
5.16.1 Technical Approach 5-40
5.16.2 Activity Indicator 5-40
5.16.3 Emission Factor 5-41
5.16.4 Control Efficiency 5-41
5.16.5 References 5-41
5.17 ON-ROAD VEHICLES: 11 5-43
5.17.1 Technical Approach 5-43
5.17.2 Activity Indicator 5-43
5.17.3 Emission Factor 5-43
5.17.4 Control Efficiency 5-44
5.17.5 Allocation of Emissions to the Tier II Categories 5-44
5.17.6 References 5-44
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 xix Contents
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CONTENTS (continued)
Page
5.18 NON-ROAD ENGINES AND VEHICLES - NONROAD GASOLINE: 12-01 5-47
5.18.1 Technical Approach 5-47
5.18.2 Activity Indicator 5-47
5.18.3 Emission Factor 5-49
5.18.4 Control Efficiency 5-49
5.18.5 References 5-49
SECTION 6.0
NATIONAL CRITERIA POLLUTANT ESTIMATES
PROJECTIONS METHODOLOGY 6-1
6.1 INTRODUCTION 6-1
6.2 NONUTILITY POINT SOURCE PROJECTIONS 6-1
6.2.1 Growth Factors 6-1
6.2.2 Control Assumptions/Factors 6-2
6.2.2.1 VOC Controls 6-2
6.2.2.2 NOX Controls 6-2
6.2.2.3 CO, SO2, and PM Controls 6-3
6.2.3 Other Issues 6-3
6.2.3.1 Industrial Emissions Adjustments 6-3
6.2.3.2 Commercial/Institutional and Residential Emission Adjustments 6-4
6.2.4 References 6-4
6.3 UTILITY PROJECTIONS 6-11
6.3.1 Existing Unit Projections 6-11
6.3.2 Planned Units 6-12
6.3.3 Generic Units 6-12
6.3.4 Control Assumptions 6-13
6.3.4.1 NOX Controls 6-13
6.3.4.2 SO2 Controls 6-14
6.3.5 Other Issues 6-15
6.3.5.1 Particulate Matter Emissions 6-15
6.3.6 References 6-16
6.4 AREA SOURCE PROJECTIONS 6-19
6.4.1 Growth Factors 6-19
6.4.2 Control Assumptions/Factors 6-19
6.4.2.1 VOC Controls 6-19
6.4.2.2 NOX Controls 6-19
6.4.2.3 PM Controls 6-19
6.4.3 Other Issues 6-19
6.5 HIGHWAY MOBILE SOURCE PROJECTIONS 6-22
6.5.1 VMT Projection Methodologies 6-22
6.5.2 Registration Distribution for Projection Years Used as MOBILE5b Inputs 6-23
6.5.3 Additional MOBILE5b Inputs 6-23
6.5.3.1 RVP Values 6-23
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XX Contents
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CONTENTS (continued)
Page
6.5.3.2 Temperature Data 6-23
6.5.3.3 Speed Data 6-23
6.5.3.4 Operating Mode 6-24
6.5.3.5 Altitude 6-24
6.5.3.6 MONTH Flag 6-24
6.5.3.7 Additional Inputs from OTAG 6-24
6.5.3.8 Control Program Inputs 6-24
6.5.4 Additional PART5 Model Inputs 6-28
6.5.5 Calculation of Highway Vehicle Emission Inventories 6-28
6.5.6 References 6-28
6.6 NON-ROAD MOBILE SOURCES 6-51
6.6.1 Growth Factors 6-51
6.6.2 Control Factors 6-51
6.6.3 Use of OMS National Emissions Estimates 6-51
6.6.4 References 6-52
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 xxi Contents
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TABLES AND FIGURES
Tables Page
1-1. Estimating Methods Used in the 1997 Trends Report 1-3
2-1. Historic NOX and SO2 Emission Source Categories, Fuel Types, and Descriptions 2-12
2-2. Historic NOX and SO2 Emission Source Categories Not Estimated 2-13
2-3. Processes Included in the Miscellaneous Source Category 2-13
2-4. Major Source Categories for SO2 andNOx Historic Emissions 2-14
2-5. Correlation between Tier I Categories and Historic Major Source Categories for SO2 and NOX
Emission Estimates 2-14
2-6. Source Categories and Activity Indicators for Historic VOC Emission Estimates 2-15
2-7. Adjusted VOC Emission Factors for External Fuel Combustion, Wood 2-17
2-8. Correlation between Tier I Categories and Historic Major Source Categories for VOC Emission
Estimates 2-18
3.1-1. Correspondence Between Tier II Categories and 1940-1984 Methodology Emission Source
Categories 3-6
3.1-2. Example Spreadsheet - Distillate Oil Combustion and Emission Factors for Year 19xx . . . 3-18
3.1-3. Supplemental PM-10 Emission Factors 3-19
3.3-1. Emission Factor SCCs for Distillate Oil Combustion by Electric Utility 3-30
3.4-1. Emission Factor SCCs for the Combustion of Natural Gas by Electric Utility 3-33
3.4-2. NOX Emission Factors by Boiler Types for the Combustion of Natural Gas by Electric
Utility 3-33
3.8-1. Emission Factors for Miscellaneous Fuels - Industrial (coke) 3-49
3.14-1. Chemical Products, SCCs, and Weighting Factors for VOC Emission Factors 3-75
3.17-1. Ammonium Nitrate Emission Factor SCCs and Weighting Factors 3-88
3.17-2. Urea Emission Factor SCCs and Weighting Factors 3-88
3.21-1. PM-10 Emission Factors SCCs for the Primary Metals Industry - Aluminum 3-108
3.21-2. PM-10 and SO2 Emission Factors SCCs and Weighting Factors for the Primary Metals Industry
- Copper Roaster 3-108
3.21-3. PM-10 Emission Factors SCCs and Weighting Factors for the Primary Metals Industry -
Copper Smelting 3-108
3.21-4. PM-10 Emission Factors SCCs and Weighting Factors for the Secondary Metals Industry -
Copper Brass and Bronze Casting 3-108
3.21-5. SO2 Emission Factors SCCs and Weighting Factors for the
Primary Metals Industry - Copper Smelting 3-109
3.21-6. SO2 Emission Factors SCCs and Weighting Factors for the
Primary Metals Industry - Copper Converting 3-109
3.23-1. PM-10 and TSP Emission Factor SCCs for Taconite Processing 3-127
3.23-2. PM-10 and TSP Emission Factor Processes for Copper Ore Crushing 3-127
3.25-1. Emission Factors Used in the Calculation of the Control Efficiencies for the Blow Down
Systems, Process Drains, and Vacuum Jets Subcategories 3-137
3.27-1. Conversion of Grain Volume (in bushels) to Weight (in pounds) 3-147
3.27-2. PM-10 and TSP Emission Factor SCCs for Country Elevators 3-147
3.27-3. PM-10 and TSP Emission Factor SCCs for Terminal Elevators 3-148
3.27-4. PM-10 and TSP Emission Factor SCCs for Feed Mills 3-148
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XX11 Tables and Figures
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TABLES AND FIGURES (continued)
Tables Page
3.27-5. PM-10 and TSP Emission Factor SCCs for Soybean Milling 3-148
3.29-1. VOC Emissions Factor SCCs for Tire Production 3-155
3.30-1. NOX Emission Factor SCCs and Weighting Factors for Glass Manufacturing 3-168
3.30-2. PM-10 and TSP Emission Factor SCCs for Kilns Used in Brick Manufacturing 3-168
3.30-3. PM-10 and TSP Emission Factor SCCs for Clay Sintering 3-168
3.30-4. PM-10 and TSP Emission Factor SCCs for Fiber Glass Furnaces 3-168
3.30-5. PM-10 and TSP Emission Factor SCCs for Stone and Rock Crushing 3-169
3.30-6. Uncontrolled SO2 Emissions Factors for Cement Manufacturing 3-169
3.31-1. Solvents and Weighting Factors for Degreasing 3-171
3.32-1. Solvents and Weighting Factors for Graphic Arts 3-173
3.33-1. Solvents and Weighting Factors for Dry Cleaning 3-175
3.34-1. Determination of Activity Indicator for Architectural Coating Processes: Paint Types ..3-180
3.34-2. Determination of Activity Indicator for Miscellaneous Organic Solvent Extraction (other
solvent use): Included Solvents 3-180
3.34-3. Determination of Activity Indicators for 14 Surface Coating Operations: Solvent Contents and
Reference 4 Categories 3-181
3.34-4. Determination of Activity Indicator for Production of Pressure Tape and Labels: Solvents Used
3-181
3.34-5. Determination of the Activity Indicator for Miscellaneous Surface Coating Operations: Solvent
Use in Three Processes 3-182
3.34-6. Determination of Activity Indicator for Miscellaneous Surface Coatings Operations:
Solvent Consumptions for Determination of Solvent "Slop" 3-182
3.34-7. Determination of Activity Indicator for Miscellaneous Surface Coatings Operations:
Solvent Consumptions for All Surface Coating Operations for the Determination of Solvent
"Slop" 3-183
3.35-1. Determination of Activity Indicator for Miscellaneous Organic Solvent Uses: Solvents,
Weighting Factors, and References 3-185
3.35-2. Determination of Activity Indicator for Solvent Extraction Processes: Solvents, Weighting
Factors, and References 3-186
3.35-3. Determination of Activity Indicator for Plastics Fabrication Processes: Solvents, Weighting
Factors, and References 3-186
3.35-4. VOC Emission Factor SCCs for Waste Solvent Recovery Processes 3-186
3.36-1. Determination of Activity Indicator for Pesticides: Solvents, Weighting Factors, and
References 3-189
3.36-2. Determination of Activity Indicator for Other Solvent Uses of Miscellaneous Organic Solvents:
Solvents, Weighting Factors, and References 3-189
3.42-1. VOC Emission Factor SCCs for Waste Solvent Recovery 3-201
3.46-1. 1940 VMT by Road Type 3-214
3.46-2. 1950 VMT by Road Type 3-215
3.46-3. 1960 VMT by Road Type 3-215
3.46-4. National Vehicle Registration Distribution used in Determining Emission Factors for the
Years 1940, 1950, and 1960 3-216
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XX111 Tables and Figures
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TABLES AND FIGURES (continued)
Tables Page
3.46-5. PM-10, TSP, and SO2 On-road Vehicles Emission Factors for 1940, 1950, and 1960 . . . 3-217
3.47-1. Emission Factor Equipment Types and Weighting Factors for Gasoline Construction
Equipment 3-223
3.47-2. Emission Factor Equipment Types and Weighting Factors for Gasoline Small Utility
Gasoline Engines 3-223
3.47-3. MOBILE 2 (1978 version) Parameters for Calculation of Emission Factors for
Motorcycles 3-223
3.48-1. Emission Factor Equipment Types and Weighting Factors for Diesel Construction
Equipment 3-226
3.49-1. Emission Factors for Commercial Aircraft using FAA Facilities 3-230
3.49-2. Emission Factors for Air Taxis using FAA Facilities 3-231
3.49-3. Emission Factors for General Aviation Aircraft using FAA Facilities 3-231
3.49-4. Emission Factors for Military Aircraft using FAA Facilities 3-231
3.52-1. States Comprising Regions for Wild Fires Acreage Burned Information 3-240
3.52-2. Land Area Burned on Unprotected Lands 3-240
4.1-1. Section 4.0 Structure 4-3
4.1-2. Major Source Categories 4-4
4.1-3. Tier I and Tier II Match-up with Source Classification Codes 4-6
4.2-1. Boiler Emissions Data Sources for NOX and SO2 by Year 4-31
4.2-2. Steam Electric Utility Unit Source Classification Code Relationships 4-32
4.2-3. Algorithms Used to Estimate Emissions from Electric Utility Boilers 4-34
4.2-4. Algorithms Used to Disaggregate ETS/CEM Boiler Data to the Boiler-SCC Level 4-35
4.3-1. SCCs With 100 Percent CO Rule Effectiveness 4-63
4.3-2. July RVPs Used to Model Motor Vehicle Emission Factors 4-64
4.3-3. 1990 Seasonal RVP (psi) by State 4-65
4.3-4. Seasonal Maximum and Minimum Temperatures (°F) by State 4-66
4.3-5. Average Annual Service Station Stage II VOC Emission Factors 4-67
4.3-6. TSDF Area Source Emissions Removed from the Inventory (1985-1996) 4-67
4.3-7. Bureau of Economic Analysis's SA-5 National Changes in Earnings by Industry 4-68
4.3-8. Area Source Growth Indicators 4-69
4.3-9. SEDS National Fuel Consumption 4-70
4.3-10. AMS to NAPAP Source Category Correspondence 4-71
4.3-11. Point Source Data Submitted 4-73
4.3-12. Area Source Data Submitted 4-75
4.3-13. Ad Hoc Report 4-76
4.3-14. SEDS National Fuel Consumption, 1990-1996 (trillion Btu) 4-77
4.3-15. BEA SA-5 National Earnings by Industry, 1990-1996 4-78
4.3-16. Area Source Listing by SCC and Growth Basis 4-80
4.3-17. Emission Estimates Available from AIRS/FS by State, Year, and Pollutant 4-83
4.3-18. NOX and VOC Major Stationary Source Definition 4-84
4.3-19. Summary of Revised NOX Control Efficiencies 4-84
4.3-20. Cotton Ginning Emission Factors 4-85
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XXIV Tables and Figures
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TABLES AND FIGURES (continued)
Tables Page
4.3-21. Estimated Percentage of Crop By Emission Control Method 4-85
4.3-22. Cotton Ginnings: Running Bales Ginned By County, District, State, and United States . . 4-86
4.3-23. Point Source Controls by Pod and Measure 4-87
4.3-24. Point Source SCC to Pod Match-up 4-89
4.3-25. Area Source VOC Controls by SCC and Pod 4-96
4.3-26. Counties in the United States with Stage II Programs that use Reformulated Gasoline . . . 4-97
4.3-27. VOC Area Source RACT 4-98
4.4-1. Bureau of Economic Analysis's SA-5 National Changes in Earnings by Industry 4-124
4.4-2. Area Source Growth Indicators 4-125
4.4-3. SEDS National Fuel Consumption 4-126
4.4-4. AMS to NAPAP Source Category Correspondence 4-127
4.4-5. Point Source Data Submitted 4-128
4.4-6. Area Source Data Submitted 4-130
4.4-7. Ad Hoc Report 4-131
4.4-8. SEDS National Fuel Consumption, 1990-1996 (trillion Btu) 4-132
4.4-9. BEA SA-5 National Earnings by Industry, 1990-1996 4-133
4.4-10. Area Source Listing by SCC and Growth Basis 4-135
4.4-11. Emission Estimates Available from AIRS/FS by State, Year, and Pollutant 4-136
4.4-12. NOX and VOC Major Stationary Source Definition 4-137
4.4-13. Summary of Revised NOX Control Efficiencies 4-137
4.4-14. Wildfires 4-138
4.4-15. Emission Factors for Residential Wood Combustion by Pollutant 4-139
4.4-16. PM Control Efficiencies for 1991 through 1996 4-139
4.5-1. National Material Balance for Solvent Emissions 4-159
4.5-2. Data Bases Used for County Allocation 4-160
4.5-3. Bureau of Economic Analysis's SA-5 National Changes in Earnings by Industry 4-161
4.5-4. Point Source Data Submitted 4-162
4.5-5. Area Source Data Submitted 4-164
4.5-6. Ad Hoc Report 4-165
4.5-7. SEDS National Fuel Consumption, 1990-1996 (trillion Btu) 4-166
4.5-8. BEA SA-5 National Earnings by Industry, 1990-1996 4-167
4.5-9. Area Source Listing by SCC and Growth Basis 4-169
4.5-10. Emission Estimates Available from AIRS/FS by State, Year, and Pollutant 4-170
4.5-11. Point Source Controls by Pod and Measure 4-171
4.5-12. Point Source SCC to Pod Match-up 4-172
4.5-13. Area Source VOC Controls by SCC and Pod 4-174
4.6-1. Data Components of HPMS 4-202
4.6-2. Apportionment Percentages for Conversion of HPMS Vehicle Type Categories to
MOBILE5a Categories 4-203
4.6-3. VMT Seasonal and Monthly Temporal Allocation Factors 4-204
4.6-4. 1995 to 1996 VMT Growth Factors by State and Roadway Type 4-205
4.6-5. State-level Daily VMT Totals in the OTAG Inventory 4-212
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XXV Tables and Figures
-------
TABLES AND FIGURES (continued)
Tables Page
4.6-6. Cities Used for Temperature Data Modeling from 1970 through 1996 4-213
4.6-7. Surrogate City Assignment 4-214
4.6-8. Substitute Survey City Assignment 4-218
4.6-9. Monthly RVP Values Modeled in 1995 4-219
4.6-10. Monthly RVP Values Modeled in 1996 4-221
4.6-11. HPMS Average Overall Travel Speeds for 1990 4-223
4.6-12. Average Speeds by Road Type and Vehicle Type 4-224
4.6-13. State-Supplied Operating Mode Inputs 4-225
4.6-14. I/M Program Documentation (1995 and 1996) 4-226
4.6-15. Counties Included in 1995 and 1996 I/M Programs 4-228
4.6-16. Oxygenated Fuel Modeling Parameters 4-231
4.6-17. State-Supplied Trip Length Distribution Inputs 4-232
4.6-18. State-Supplied Alcohol Fuels Data 4-232
4.6.19. State-Provided Diesel Sales Inputs 4-233
4.6-20. Counties Modeled with Federal Reformulated Gasoline 4-235
4.6-21. PART5 Vehicle Classes 4-238
4.6-22. Average Speeds by Road Type and Vehicle Type 4-238
4.6-23. PM-10 Emission Factors used in the Emission Trends Inventory 4-239
4.6-24. Fuel Economy Values Used in Calculation of SO2 Emission Factors for the Emission
Trends Inventory 4-239
4.6-25. SO2 Emission Factors used in the Emission Trends Inventory 4-240
4.6-26. Fractions of Vehicles Equipped with 3-Way Catalysts by Vehicle Type and Model Year . 4-241
4.6-27. Ammonia Emission Factors by Year and Vehicle Type 4-242
4.7-1. Ozone Nonattainment Areas with QMS-Prepared Non-road Emissions 4-257
4.7-2. Source Categories Used for Nonroad Emissions 4-258
4.7-3. Railroad Locomotives Diesel Fuel Consumption, 1985 to 1990 4-259
4.7-4. Railroad Emission Factors 4-259
4.7-5. Civil Aircraft SO2 Emission Factors 4-260
4.7-6. Area Source Growth Indicators 4-261
4.7-7. Bureau of Economic Analysis's SA-5 National Changes in Earnings by Industry 4-261
4.7-8. AMS to NAPAP Source Category Correspondence 4-262
4.7-9. Non-road Data Submitted for OTAG Inventory 4-263
4.7-10. Area Source Listing by SCC and Growth Basis 4-264
4.7-11. SEDS National Fuel Consumption, 1990-1996 (trillion Btu) 4-265
4.7-12. BEA SA-5 National Earnings by Industry, 1990-1996 4-265
4.7-13. Counties in the United States with Stage II Programs that use Reformulated Gasoline . . 4-266
4.7-14. NOX Nonroad Control Efficiencies by SCC 4-267
4.7-15. National Nonroad Diesel Emissions 4-268
4.7-16. National Spark Ignition Marine Engine Emissions 4-269
4.7-17. National Locomotive Emissions 4-269
4.8-1. Particle Size Ratios 4-300
4.8-2. Silt Content by Soil Type, 1985 to 1989 4-300
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XXVI Tables and Figures
-------
TABLES AND FIGURES (continued)
Tables Page
4.8-3. Silt Content by Soil Type, 1990 to 1996 4-300
4.8-4. Number of Tillings by Crop Type 4-301
4.8-5. Livestock Operations Ammonia Emission Factors 4-301
4.8-6. Speeds Modeled for Unpaved Roads 4-301
4.8-7. Assumed Values for Average Daily Traffic Volume by Volume Group 4-302
4.8-8. PM-2.5 to PM-10 Ratios for Paved and Unpaved Roads 4-302
4.8-9. List of Grown Sources 4-303
4.8-10. Point Source Data Submitted 4-304
4.8-11. Area Source Data Submitted 4-306
4.8-12. Ad Hoc Report 4-307
4.8-13. Bureau of Economic Analysis's SA-5 National Changes in Earnings by Industry 4-308
4.8-14. Emission Estimates Available from AIRS/FS by State, Year, and Pollutant 4-309
4.8-15. SEDS National Fuel Consumption, 1990-1996 (trillion Btu) 4-310
4.8-16. BEA SA-5 National Earnings by Industry, 1990-1996 4-310
4.8-17. Area Source Listing by SCC and Growth Basis 4-310
5.1-1. Correspondence Between Tier II Categories and Lead Emissions Methodology
Categories 5-4
5.1-2. Method Used for Estimating 1996 Activity Data 5-6
5.8-1. Annual Percentage Lead Content 5-21
5.17-1. Number of Grams of Lead/Gasoline (Y) 5-45
5.17-2. Relative VMT Fractions for Each Tier II Category 5-46
6.2-1. Compliance Dates for Promulgated 2-Year and 4-Year MACT Standards 6-5
6.2-2. Point Source VOC Controls 6-6
6.2-3. NOX Nonutility Point Source RACT Controls 6-9
6.2-4. EAFs for Industrial Sector 6-10
6.2-5. EAFs for Commercial and Residential Sector 6-10
6.3-1. Profile Types and Maximum Change in Capacity Factors 6-16
6.3-2. Utility Projections by NERC Region and Fuel Type 6-17
6.3-3. Title IV or RACT NOX Emission Rate Limits 6-18
6.4-1. Area Source VOC Control Measures 6-20
6.4-2. Area Source Industrial Fuel Combustion NOX RACT Penetration Rates 6-21
6.4-3. Area Source PM-10 Control Measures 6-21
6.5-1. National Annual Highway Vehicle VMT Projections by Vehicle Type 6-30
6.5-2. Annual State VMT Totals by Year 6-31
6.5-3. Monthly RVP Values Modeled in Projection Years 6-32
6.5-4. Projection Year Monthly Temperature Inputs (°F) 6-34
6.5-5. Average Speeds by Road Type and Vehicle Type 6-38
6.5-6. State-Supplied Trip Length Distribution Inputs 6-38
6.5-7. State-Specific I/M Program Inputs - Projection Years 6-39
6.5-8. Counties Included in State-Specific I/M Projection Year Programs 6-40
6.5-9. I/M Performance Standard Program Inputs 6-43
6.5-10. States Modeled with I/M Performance Standard Inputs in 2005, 2007, 2008, and 2010 . . . 6-45
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XXV11 Tables and Figures
-------
TABLES AND FIGURES (continued)
Tables Page
6.5-11. Counties Modeled with Federal Reformulated Gasoline 6-47
6.6-1. SCC-SIC Crosswalk 6-53
6.6-2. 1999 - 2010 Growth Factors 6-54
Figures
4.3-1. OTAG Inventory Data Source - Area Sources 4-99
4.3-2. OTAG Inventory Data Source - Point Sources 4-100
4.6-1. State-Provided Registration Distributions 4-243
4.6-2. OTAG Inventory Source of Data - VMT 4-244
4.7-1. Assignment of Surrogate Nonattainment Areas 4-257
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XXV111 Tables and Figures
-------
ACRONYMS AND ABBREVIATIONS
AADT
AAMA
AAR
ACT
ADTV
AIRS
AIRS/AMS
AIRS/FS
ARD
ASTM
BEA
BLS
CAAA
CEM
CNOI
CO
CTG
CTIC
DOE
DOT
DVMT
EIA
EFIG
EG
EPA
ERCAM/VOC
BSD
ETS/CEM
FAA
FCC
FGD
FHWA
FID
FREDS
FTP
GCVTC
GT
HC
HCPREP
HDV
hp
HPMS
1C
I/M
annual average daily traffic
American Automotive Manufacturer's Association
Association of American Railroads
Alternative Control Technology
average daily traffic volume
Aerometric Information Retrieval System
AIRS Area and Mobile Source Subsystem
AIRS Facility Subsystem
Acid Rain Division
American Society for Testing and Materials
U.S. Department of Commerce, Bureau of Economic Analysis
U.S. Bureau of Labor Statistics
Clean Air Act Amendments of 1990
continuous emissions monitor(ing)
Census number of inhabitants
carbon monoxide
Control Techniques Guidelines
Conservation Information Technology Center
U.S. Department of Energy
Department of Transportation
daily vehicle miles traveled
U.S. DOE, Energy Information Administration
EPA, OAQPS, Emission Factors and Inventory Group
earnings growth
U.S. Environmental Protection Agency
Emission Reductions and Cost Analysis Model for VOC
EPA, OAQPS, Emission Standards Division
Emissions Tracking System/Continuous Emissions Monitoring
Federal Aviation Adminstration
fluid catalytic cracking unit
flue gas desulfurization
U.S. Federal Highway Adminstration
Flame lonization Detector
Flexible Regional Emissions Data System
Federal Test Procedure
Grand Canyon Visibility Transport Commission
gas turbines
hydrocarbon
FREDS Hydrocarbon Preprocessor
heavy duty vehicle
horsepower
Highway Performance Monitoring System
internal combustion (engine)
inspection and maintenance
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
XXIX
Acronyms and Abbreviations
-------
ACRONYMS AND ABBREVIATIONS (continued)
LDT light duty truck
LDV light duty vehicle
LTO landing and takeoff
MACT maximum available control technology
MRI Midwest Research Institute
MW megawatts
NAA nonattainment area
NADB National Allowance Data Base
NAPAP National Acid Precipitation Assessment Program
NEDS National Emission Data System
NESHAP National Emission Standards for Hazardous Air Pollutants
NET National Emissions Trends (inventory)
NH3 ammonia
NOX oxides of nitrogen
NPI National Particulates Inventory
NSPS New Source Performance Standards
OAQPS EPA, Office of Air Quality Standards and Planning
QMS EPA, Office of Mobile Sources
OSD ozone season daily
OTAG Ozone Transport Assessment Group
OTR ozone transport region
Pb lead
PCE personal consumption expenditures
PM particulate matter
PM-2.5 particulate matter less than 2.5 microns in diameter
PM-10 particulate matter less than 10 microns in diameter
ppm parts per million
QA quality assurance
QC quality control
RACT Reasonably Available Control Technology
RCRA Resource Conservation and Recovery Act
ROM Regional Oxidant Model
RVP Reid vapor pressure
SCC source classification code
SEDS State Energy Data System
SIC Standard Industrial Classification (code)
SIP State Implementation Plan
S02 sulfur dioxide
SO4 sulfates
SUPROXA Super Regional Oxidant A
TOG total organics
tpy tons per year
TSDF hazardous waste treatment, storage, and disposal facility
TSP total suspended particulate matter
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
XXX
Acronyms and Abbreviations
-------
ACRONYMS AND ABBREVIATIONS (continued)
USD A U.S. Department of Agriculture
USFS USDA Forest Service
VMT vehicle miles traveled
VOC volatile organic compound(s)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 xxxi
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SECTION 1.0
INTRODUCTION
The Emission Factors and Inventory Group (EFIG) of the U.S. Environmental Protection Agency
(EPA) is responsible for compiling and maintaining national emission data for the criteria pollutants. To
that end, EFIG produces estimates of the annual national air pollutant emissions for six major pollutants:
carbon monoxide (CO), nitrogen oxides (NOX), lead (Pb), particulate matter less than 10 microns
(PM-10), sulfur dioxide (SO2), and volatile organic compounds (VOC). In addition, total particulate
matter (TSP) has been estimated in the past. For the years 1990-1996, particulate matter less than
2.5 microns (PM-2.5) and ammonia (NH3) have also been estimated. These estimates are published
annually in two EPA reports and are entitled for 1997, "National Air Pollutant Emission Trends, 1900-
1996,"1 and "National Air Quality and Emission Trends Report, 1996."2 Collectively, these are known as
the Trends Reports.
The 1997 Trends Procedures Document is an accompanying document designed to describe the
methodology and procedures used to create the emission estimates presented in the 1997 Trends Reports.
The emission estimating methodologies fall into five major categories: 1900-1939 Methodology, 1940-
1984 Methodology, 1985-1989 Methodology, 1990-1996 Methodology, and 1997-2010 Methodology.
The methodology used to make specific estimates depends on the pollutant and the time period.
Table 1-1 presents a detailed characterization of the emission estimates created using each of these five
methodologies and the section of this report that describes the methodology.
In general, the SO2, NOX, and VOC emissions for the time period before 1940 were using the 1900-
1939 methodology. The emissions of no other pollutants were estimated for these years.
The 1940-1984 methodology was originally developed specifically to make the emission estimates
for all years and pollutants presented in the Trends Reports. For the 1997 Trends report, this
methodology was generally used to estimate the emissions for the years from 1940 to 1984. In addition
to SO2, NOX, and VOC emissions, the emissions of CO, Pb, PM-10, and TSP are estimated by this
methodology.
The emissions for the years from 1985 to 1989 were estimated by the methodology underlying a
new emission inventory, the Interim Inventory.3 This methodology was applied to the emission estimates
for all pollutants, except Pb and TSP. The emissions of these pollutants are estimated using the 1940-
1984 methodology. (TSP estimates were last developed for the 1992 emissions. Currently there is no
plan to estimate TSP emissions in the future since the current National Air Quality Standards for
particulate matter are for the size 10 microns or less.)
The emissions for the year 1990 are based on State-submitted data. The 1991-1996 emissions for
non-utility point and area sources are based on economic growth [Bureau of Economic Analysis (BEA)
or State Energy Data System (SEDS)] data and the Clean Air Act Amendments of 1990 (CAAA)
controls. The remaining sources were estimated using modifications/updates to the Interim Inventory
Methodology.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 1-1 Introduction
-------
For each methodology, the procedures used to estimate the emissions are described by the source
category divisions most appropriate for that methodology. For a given source category, the estimating
procedure is described for all pollutants collectively, unless differences exist in the methods used for
different pollutants. In this case, the methods used for each pollutant are described separately. Because
of the unique nature of the methodology used to estimate the lead emissions, this methodology is
described in section 5. This allows each section of the manual to be used independently.
Section 6 presents the methodology used to develop the emission projections for the years 1999,
2000, 2002, 2005, 2007, 2008, and 2010.
Emission estimates presented in the 1997 Trends Reports are categorized using the Tier structure.
Emissions derived by the 1900-1939 methodology are presented by the Tier I categories. All other
emissions appear by the Tier III categories. Because the methodologies are not necessarily described by
these Tier categories, a description of the correspondence between the source categories used to describe
the estimating methodology and the Tier structure is included in each section of this document.
This document is best used as a reference for those personnel who already have some familiarity
with the trends report production process or for a technical person inquiring about the origins of the
estimates. Some details of procedures are vaguely or inadequately defined, since getting such details
down on paper and keeping the document current, is a real challenge. A new person who takes over
responsibility for this work will in general need help from an experienced person.
In the past, the emission estimates presented in the Trends reports would change from one year to
the next based on the development of new information, data, or methodologies used to estimate the
emissions. These changes were applied not only to the most recent year, but to all or some of the
preceding years. As of 1997, no such changes are planned to be made to the emissions for the years prior
to 1985. Therefore, the methodologies and reference presented in this document for the determination of
the emission for these years will not change. Updates may be made, however, to the emissions for the
years 1985 to the current year of the report. Any changes in the data or methodologies used to estimate
the emissions for this time period will be documented in yearly addenda to this procedures document.
1.1 REFERENCES
1. National Air Pollutant Emission Trends, 1900-1996. EPA-454/R-97-011. U.S. Environmental
Protection Agency, Research Triangle Park, NC. December 1997.
2. National Air Quality Emissions Trends Report, 1996. U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1997.
3. Regional Interim Emission Inventories (1987-1991), Volume I: Development Methodologies.
EPA-454/R-93-021a. Source Receptor Analysis Branch, U.S. Environmental Protection Agency,
Research Triangle Park, NC. May 1993.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 1-2 Introduction
-------
Table 1-1. Estimating Methods Used in the 1997 Trends Report
Tier Category
Fuel Combustion - Electric Utilities
Fuel Combustion - Industrial
Fuel Combustion - Other
Chemical & Allied Product Mfg.
Metals Processing
Petroleum & Related Industries
Other Industrial Processes
Solvent Utilization
Storage & Transport
Waste Disposal & Recycling
Natural Sources
Miscellaneous
On-road Vehicles
Non-road Sources
Time Period
1900-1969, excluding
1940, 1950, and 1960
1940, 1950, and 1960
and 1970 through 1984
1985 through 1989 and
1990 through 1996
1999,2000,2002,2005,
2007,2008,2010
1900-1939
1940 through 1969
1970 through 1993
1999,2000,2002,2005,
2007,2008,2010
Pollutant(s)
VOC, SO2, and NOX
VOC, SO2, NOX, CO,
andPM-10
Pb
VOC, SO2, NOX, CO,
andPM-10
VOC, SO2, NOX, CO,
PM-10, PM-2.5, and
NH3
Pb
VOC, SO2, NOX, CO,
and PM-10
VOC, SO2, NOX
VOC, SO2, NOX, CO,
and PM-10
Pb
VOC, SO2, NOX, CO,
and PM-10
PM-2.5 and NH3
Pb
VOC, SO2, NOX, CO,
and PM-10
Methodology
1900-1939
Methodology
1940-1984
Methodology
Lead
Methodology
1985-1989
Methodology
1990-1996
Methodology
Lead
Methodology
Projection
Methodology
1900-1939
Methodology
1940-1984
Methodology
Lead
Methodology
1985-1993
Methodology
1990-1996
Methodology
Lead
Methodology
Projection
Methodology
Section
2
3
5
4
4
5
6
2
3
5
4
4
5
6
NOTE(S): S02, VOC, and NOXestimated 1900-1996.
CO, PM-10 estimated 1940-1996.
Lead estimated 1970-1996.
PM-10 fugitive Dust estimated 1985-1996.
PM-2.5 and NH3 estimated 1990-1996.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
1-3
Introduction
-------
SECTION 2.0
1900 -1939 METHODOLOGY
The SO2, NOX, and VOC emission estimates presented in the 1997 Trends report for the years 1900
through 1969, with the exception of the years 1940, 1950, and I960,1 were taken from two reports on
historic emissions. The first contained SO2 and NOX emissions for the years between 1900 and 1980.l
The VOC emissions for the years between 1900 and 1985 were contained in the second.2 A summary of
the methodologies used to estimate these emissions is presented in this document. This summary includes
the basic assumptions, categorization, and calculations used to estimate these emissions. The two
reports1'2 provide a more detailed discussion of the methodologies used to estimate these emissions.
2.1 DESCRIPTION OF EMISSION ESTIMATION METHODOLOGIES FOR SO2 AND NOX
A methodology for estimating historic SO2 and NOX emissions was developed prior to the 1940 -
1984 methodology and served as the predecessor to that methodology. These historic emissions were
prepared for the years 1900 to 1980. Of these historic estimates, the 1997 Trends report presented the
emissions for the years 1900 through 1969, except for the years 1940, 1950, and I960.3 The general
methodologies for producing these emissions are described in this document along with specific
information concerning the emissions for the years from 1900 through 1970.
The emissions were categorized based on the sources of the emissions. Each source category
included specific processes which generate emissions such as the combustion of coal by railroad
locomotives. The general methodology for estimating emissions was based on two factors: (1) the
activity indicator which represents the activity of each process (e.g. the quantity of coal consumed by
railroad locomotives) and (2) the emission factor which represents the quantity of emissions produced by
the process per unit of process activity (e.g. the pounds of SO2 produced for every ton of coal burned by
a locomotive). Table 2-1 lists the source categories, along with the activity indicators and a description
of the processes included in each category.
2.1.1 State-Level Estimates
The state-level SO2 and NOX emissions were produced for every fifth year beginning in 1900 and
ending in 1970. The methodologies used to estimate the state-level emissions fall into three general
groups. These groups are: (1) emissions from the combustion of fuels for heat and power, except by on-
road vehicles, (2) emissions from the combustion of fuel for transportation by on-road vehicles, and
(3) emissions from material processing, manufacturing, miscellaneous combustion, and miscellaneous
burning. The three general methodologies used to estimate the emissions are described individually in the
following sections.
1 The emissions for the years 1940, 1950, and 1960 were estimated using the 1940-1984 methodology. This methodology
is described in section 3.0 of this document.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-1 1900-1939 Methodology
-------
2.1.2 Emissions from Fuel Combustion, Excluding On-road Vehicles
The source categories representing emissions produced by burning a fuel to generate heat or power
are: electric utilities, industrial boilers, commercial and residential fuel uses, all uses of anthracite coal (as
a fuel), all uses of wood (as a fuel), railroads, vessels, and non-road diesel engines. The emissions from
each source category were further categorized by the fuel type (e.g., emissions from railroad were
estimated for each of the two fuels burned by locomotives: coal and oil). The emissions from each source
category and fuel type were determined using three pieces of information: (1) a fuel use indicator, (2) a
fuel sulfur content (necessary to estimate SO2 emissions only), and (3) an emission factor expressing the
amount of SO2 or NOX produced by a given amount of fuel burned.
The primary fuel use indicator used was the state-level fuel consumption for a specific source and
fuel type. If such data were unavailable, then a state-level fuel use indicator such as fuel demand,
distribution, sales, or deliveries was used. Prior to 1940, state-level data were often unavailable; in these
cases, a national fuel use indicator was used, if available. The national indicator was apportioned to the
states using the same state/national ratios established for the earliest year having available state-level data.
There were combinations of fuel types and source categories for which no fuel use indicators were
available over specific time periods. For those cases listed in Table 2-2, emission estimates at the state
level were not estimated.
The emission factor provided the ratio between the quantity of fuel consumed and the uncontrolled
amount of SO2 or NOX emitted. The emission factors used to estimate the historic emissions were
derived from those contained in AP-42, up to and including Supplement 14.3 Emission factors
representing a given source category, fuel type, and pollutant were weighted averages of the AP-42
emission factors representing specific processes. The weighting factors were the quantities of the specific
fuel type consumed by each of the processes. These national emission factors were applied to all state-
level fuel use data for all years.
In order to estimate SO2 emissions, the sulfur content of the fuel burned was required. In 1970, the
sulfur content was based on reports from individual plants. State average sulfur content was used for
coal in 1965 and for other fuels in 1955. For the 1955 estimates, sulfur contents for coal were estimated
for each state based on coal quality, quantity, and distribution. The emissions for all years prior to 1955
were estimated using the 1955 sulfur content data for all fuels.
The state-level emissions for SO2 and NOX were calculated for every fifth year between 1900 and
1970 using the general equations given below. Equations 2.1-1 and 2.1-2 were used for all fuel
combustion sources.
S02 emissions ijt k = FCiJ>k * (^}, So2 x Sij,k) (Eq. 2.1-1)
NOx emissions tj k = FCik x EFJt ^ (Eq.2.1-2)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-2 1900-1939 Methodology
-------
where: FC = fuel consumption i = year
EF = emission factor j = source category /fuel type
S = sulfur content k = state
2.1.3 Emissions from Fuel Combustion by On-road Vehicles
Emissions produced by on-road vehicles were divided into two subcategories: emissions from
gasoline-powered vehicles and emissions from diesel-powered vehicles. Emissions were made estimated
based on three pieces of information: gasoline or diesel fuel consumption, fuel efficiency (for gasoline
only), and emission factor. In 1970, vehicle miles traveled (VMT) data became available and was used in
place of the state-level fuel consumption and fuel efficiency. The fuel efficiency factor was needed to
correlate the amount of gasoline consumed to the average number of miles traveled. A national average
miles per gallon was estimated for every fifth year between 1965 and 1935. A constant fuel efficiency
was used for all years prior to 1935.
The emission factors for estimating controlled emissions from gasoline-powered vehicles were
expressed in terms of the amount of SO2 or NOX emitted for every mile traveled. State-specific emission
factors were obtained from the MOBILE2 emission factor model4 for the years 1950 though 1970. The
factors calculated for 1950 were used for all preceding years. The factors for NOX emissions were
derived to represent two distinct road types: urban and rural.
The emission factors for estimating controlled emissions from diesel-powered vehicles were
expressed in term of the amount of SO2 and NOX emitted for every gallon of diesel fuel consumed.
Unlike the emission factors for gasoline-powered vehicles, those used for diesel-powered vehicles were
national and not year-specific. No fuel efficiency was required to estimate the emissions from this vehicle
type.
The SO2 and NOX emission estimates from on-road vehicles for the years prior to 1970 were
produced using Equation 2.1-3. Equation 2.1-4 was used to produce the emission estimates for 1970.
On-road Vehicle Emissions . j k = (FC. k * FE{ ) x EFi j k (Eq. 2.1-3)
On-road Vehicle Emissions 191() j k = VMT1970Jik * EFig70Jik (Eq. 2.1-4)
where: FC = fuel consumption
FE = fuel efficiency (gasoline-powered vehicles only)
EF = emission factor
i = year
j = SO2 or NOX
k = state
VMT = vehicle miles traveled (1970 estimates only)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-3 1900-1939 Methodology
-------
2.1.4 Emissions from Material Processing, Manufacturing, Miscellaneous Combustion, and
Miscellaneous Burning
The source categories producing emissions as the result of material processing, manufacturing,
miscellaneous combustion, and miscellaneous burning were: coke plants (combustion stacks), smelters,
cement plants, wildfires, miscellaneous industrial processes, and miscellaneous other processes. With the
exception of the two miscellaneous categories, the emissions were generally estimated from an activity
indicator and an emission factor. The activity indicator specified the industrial output of the process or,
in the case of the wildfire category, the area burned. The emission factors were derived from AP-42.3
The general equation used to calculate the emissions for both pollutants is shown in Equation 2.1-5
Ei,j,k,i = Ai,j,k,i x EFij,k,i (Eq. 2.1-5)
where: E = emission estimate i = year
A = activity indicator j = SO2 or NOX
EF = emission factor k = state
1 = source category
Because of the diverse nature of this group, specific details of the methodologies used to calculate the
emissions will be discussed for each category individually.
2.1.4.1 Coke Plants
The methodology used to estimate the uncontrolled emissions produced from the combustion stacks
of coke plants was similar that used for coal combustion. In place of the amount of coal burned, these
estimates were based on the amount of coal charged into the coke ovens. The SO2 and NOX emissions
were estimated using Equations 2.1-1 and 2.1-2, respectively, with the emission factors, the state-level
coal sulfur contents, and the state-level quantities of coal charged. This methodology accounts for only
about 67 percent of the total SO2 emitted by coke plants. The remaining 33 percent of the emissions
were passed to the coke oven gas and were emitted latter in the steel manufacturing process and were
categorized with miscellaneous industrial processes.
2.1.4.2 Smelters
The primary smelters category consisted of copper, lead, and zinc smelters. The copper smelters
predominantly emitted SO2 and only small amounts of NOX, while the lead and zinc smelters emitted only
SO2. The methodology used to estimate the emissions from smelters varied according to the availability
of pertinent data.
For the years between 1950 and 1970, the emissions from copper smelters from all but the major
producing states were estimated using the state-level amounts of copper ore concentrate produced and a
national emission factor. Emissions from the major copper smelter states were obtained from a visibility
study.5 After 1960, SO2 emissions from lead and zinc smelters were based on information obtained from
a study of individual smelters.6
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-4 1900-1939 Methodology
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For copper smelters before 1955 and for lead and zinc smelters before 1965, a different
methodology was employed. The state-level quantity of ore smelted was estimated using the amount of
recoverable metal produced by the mines in a given state. It was assumed that any ore mined in a given
state was smelted in the same state. If the given state was known to have no smelters, then it was
assumed that the ore was smelted in the nearest state having a smelter. A national SO2 emission factor
was used to convert the quantity of recoverable metal to the uncontrolled quantity of SO2 produced. A
national NOX emission factor was used to calculate the NOX produced by the copper smelters.
The controlled SO2 emissions were determined by subtracting the amount of SO2 recovered during
the production of sulfuric acid. Because only national by-product sulfuric acid production data was
available, it was assumed that the amount of SO2 recovered for each state was proportional to the smelter
output for that state.
2.1.4.3 Cement Plants
SO2 and NOX emissions from cement plants were produced by both the minerals processed in the kiln
and the combustion of fuels to heat the kiln. The industrial activity indicator used to estimates the
emissions was the total annual production of portland cement by state. State-level SO2 emission factors
were the sum of the emission factors for the mineral sources, the combustion of coal, and the combustion
of oil. The NOX emission factors were average national factors. The emission factors calculated for 1955
were used to determine the emission estimates for all preceding years.
2.1.4.4 Wildfires
Wildfire emissions were defined as emissions from the combustion of vegetation in any uncontrolled
fire. The activity indicator for this category was the total area burned annually in each state. This
information was available for most states by 1925 and for all states by 1940. Prior to 1925, the acreage
burned was assumed to be equal to the acreage burned in 1925. State-level emission factors reflected
variations in vegetation (e.g. woodlands as compared to grasslands).
2.1.4.5 Miscellaneous Industrial Processes
A list of the industrial processes included in this category is given in Table 2-3. The SO2 and NOX
emissions for this source category were determined by backcasting 1980 state-level emissions obtained
from the National Emission Data System (NEDS)7 using national growth factors. The yearly national
growth factors for the years after 1940 were defined as the ratio between the national emissions for the
specific year and the 1980 national emissions. Growth factors for the earlier years were based on national
population. Equation 2.1-6 was used to estimate the emissions for this category.
NE.
SEt = SE19W x ^_L_ (Eq. 2.1-6)
7VjCr 1980
where: SE = SO2 or NOX state emission estimate
NE = SO2 or NOX national emission estimate
i = year
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-5 1900-1939 Methodology
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2.1.4.6 Miscellaneous Other Processes
Table 2-3 contains a list of the processes included in this category. The methodology used to
estimate the emissions for this category is similar to that used above for the industrial processes. For this
category, national emissions were available from the 1980 NEDS7 and the emissions were apportioned to
the states based on 1980 population data. State-level growth factors for a given year were applied to the
1980 state-level emissions to backcast the emissions for that given year. The growth factors for each
state were calculated as the ratio between the estimated state population for that year and the 1980 state
population. Equation 2.1-7 was used to calculate the SO2 and NOX emissions for this source category.
x -^- (Eq. 2.1-7)
^1980
where: SE = SO2 or NOX state emissions
S = state population
i = year
State population data for every tenth year was obtained from population census data. For the intervening
years, the state populations were estimated using Equation 2.1-8.
(Eq. 2.1-8)
where: S = state population
N = national population
i = census year (1900, 1910, ..., 1970)
j = integer 5 representing every fifth year
2.1.5 Yearly State-Level Emissions
The SO2 and NOX emissions were calculated every fifth year from 1900 to 1970 as described in the
preceding section. For the source categories representing emissions produced by the combustion of fuels,
the emissions for each intervening year were estimated by equating the changes in national fuel
consumption to the changes in the state-level emissions. Consumption data for the following fuels were
used: bituminous coal, anthracite coal, distillate and residual oils (combined), natural gas, wood, and
gasoline and diesel fuel (combined). The interpolated state-level emissions for each pollutant were
calculated using Equation 2.1-9.
SEi+j (Eq. 2.1.9)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-6 1900-1939 Methodology
-------
where: SE = SO2 or NOX state emissions by source category and fuel type
NF = national fuel consumption data corresponding to source category and fuel type
i = study year (i.e., 1900, 1905, ..., 1970)
j = integer representing the intervening year (0, 1, 2, or 3)
For the following fuel types and years, the national fuel consumption changed radically and,
therefore, was not used to estimate the yearly emissions: bituminous coal for the years 1912 and 1913
and natural gas for the years 1931, 1932, and 1933. In these cases, the yearly SO2 and NOX emissions
were determined by a linear interpolation according to Equation 2.1-10.
SE.+j = SEi + ((SE.+5 - SE.) x ;75) (Eq. 2.1-10)
where: SE = SO2 or NOX state emissions by source category
i = study year (i.e., 1900, 1905, ..., 1970)
j = integer representing the intervening year (1, 2, 3, or 4)
For the source categories in which the emissions were not based on fuel consumption (i.e., smelters,
cement plants, wildfire, miscellaneous industrial processes, and miscellaneous other sources), the yearly
emissions were also calculated by a linear interpolation as given in Equation 2.1-10.
2.1.6 Allocation of Emission Estimates to Tier I Categories
The emission estimates for the years 1900 through 1969 (excluding 1940, 1950, and 1960) were
presented graphically in the 1997 Trends report by Tier I categories. These categories were not the same
as those used in the original calculation of the emissions as described in the preceding sections. A
correspondence was developed between the original historic emission categories and the Tier I
categories.
The historic emissions were summed into five general categories as shown in Table 2-4. These
categories were then mapped to the Tier I categories as shown in Table 2-5. There was a one-to-one
correspondence between the major historic categories and the Tier I categories for three Tier I
categories: (1) Fuel Combustion - Electric Utilities, (2) Fuel Combustion - Other, and (3) On-road
Vehicles. The historic emissions were assumed to be zero for two Tier I categories: (1) Solvent
Utilization and (2) Storage and Transport.
The emissions from the other two historic categories were allocated to the corresponding Tier I
categories based on the distribution of emissions for a specific base year. The Industrial historic category
was correlated to five Tier I categories: Fuel Combustion - Industrial (02), Chemical and Allied Products
Manufacturing (04), Metals Processing (05), Petroleum and Related Industries (06), and Other Industrial
Processes (07). To distribute the emissions from the Industrial historic category to a specific Tier I
category, a ratio between the base year emissions for the specific Tier I category and the sum of the base
year emissions for all five of the Tier I categories correlated to the Industrial historic category was used.
The same procedure was used to distribute the emissions from the Other historic category which
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-7 1900-1939 Methodology
-------
correlates to three Tier I categories: Waste Disposal and Recycling (10), Non-road Sources (12), and
Miscellaneous (14). The base year was 1940, 1950, or 1960, depending on the year for which the
emissions were being distributed. The emissions for these base years were developed using the 1940-
1984 methodology (see section 3.0) and were distributed to the Tier I categories. The method for
distributing emissions to Tier I categories is summarized in Equation 2.1-11.
E = E
Tierl, i Historic, i
Tierl
'Tierl categories corresponding to Historic category
(Eq. 2.1-11)
where: E = SO2 or NOX emissions
i = historic emissions year (1900, 1905, ..., 1935, 1945, 1955, 1965)
B = base year: 1940 (for historic years 1900 to 1935 and 1945)
1950 (for historic year 1955)
1960 (for historic year 1965)
Historic = Industrial historic category or Other historic category
Tier I = categories 02, 04, 05, 06, or 07 or categories 10, 12, or 14
Tier I categories corresponding to Historic category
= 02 + 04 + 05 + 06 + 07 (for Industrial historic category)
10+ 12+ 14 (for Other historic category)
For the intervening years, the distribution of the emissions to the Tier I categories was made from
the historic emission estimates totaled over all categories. The average percentage distribution of the
total emissions to a specific Tier I category was calculated for every 6-year period (e.g., 1900 to 1905,
1925 to 1930). The percentage distribution was applied to each intervening year within the 6-year
period. Equation 2.1-12 illustrates this method.
F = F
Tierl, i+j Total, i+j
F + F
Tierl, i Tierl, i + 5
Total, i + Total, i + 5
(Eq. 2.1-12)
where: E
i
j
Tierl
Total
SO2 or NOX emissions
every fifth year between 1900 and 1965
integer representing the intervening year (1, 2, 3, or 4)
Tier I category
totaled over all historic categories
2.2 DESCRIPTION OF EMISSION ESTIMATION METHODOLOGY FOR VOC
The basic methodology for estimating the VOC emissions was a top-down method using national
activity indicators and national emission factors. This was substantially different from the methodology
used to produce the SO2 and NOX emission estimates where more detailed state-level data was used
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-8
1900-1939 Methodology
-------
wherever possible. The VOC emissions were divided into five broad source categories, each of which is
subdivided into more refined subcategories. These categories and corresponding subcategories are
presented in Table 2-6. For these emission estimates, the term national referred to the contiguous United
States.
2.2.1 National VOC Emission Estimates (every 5 years between 1900 and 1970)
National emissions for the years 1940, 1950, 1960, 1965 and 1970 were obtained directly from the
1985 Trends report.8 These data, along with that for 1975, 1980, and 1985, were used to estimates the
emissions for every fifth year between 1900 and 1935 and the years 1945 and 1955. The methodology
described below pertains to these years.
The two data values required to estimate the national annual VOC emissions for each source
subcategory were: (1) national annual activity indicators and (2) national annual emission factors. The
national activity indicators for each source subcategory for the years 1955, 1945 and every fifth year
between 1900 and 1935 were obtained from a variety of sources. In cases where the activity indicators
contained data from Alaska, Hawaii, or the U.S. territories, the activity indicators for areas outside the
contiguous United States were subtracted from the total activity indicators. This resulted in the national
(i.e., contiguous United States) activity indicator.
The development of the national annual emission factors required two steps: (1) back-calculation of
the emission factors for the years 1940, 1950, and every fifth year between 1960 and 1985 and
(2) extrapolation of these national emission factors to the years under study. In order to back-calculate
emission factors, activity indicators and emissions were required. National emissions were obtained for
the years 1940, 1950, and every fifth year between 1960 and 1985 from the 1985 Trends report.8 These
emissions were disaggregated into the source subcategories given in Table 2-6. The Trends report was
also the source of the national activity indicators for all subcategories for the same years. For each year
and source subcategory, a national emission factor was calculated using Equation 2.2-1.
NE. .
NEF,J = ^ (Eq-2.2-1)
where: NEF = national emission factor i = year
NE = national emissions j = source subcategory
NA = national activity indicator
For some source subcategories, these national emission factors were unchanged over time. In those
cases, the constant emission factor was used in calculating the emissions for all years. For source
categories where the national emission factors changed between the years 1940 through 1985, the
emission factors for the years before 1940 and for the years 1945 and 1955 were extrapolated from the
back-calculated data.
The national VOC emissions for the years 1945 and 1955, and for every fifth year between 1900 and
1935, were calculated for each subcategory using Equation 2.2-2.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-9 1900-1939 Methodology
-------
NE.t. = NEFt . x NAfi . (Eq. 2.2-2)
where: NEF = national emission factor i = year
NE = national emission estimate j = source subcategory
NA = national activity indicator
2.2.2 Yearly National Emissions
The national emissions for every fifth year between 1900 and 1970 were used to interpolate the
national emissions for the intervening years. The activity indicators used to the interpolate the emissions
for each subcategory or group of subcategories are presented in Table 2-6. The national activity data for
each year were obtained from the report of historic SO2 and NOX emissions.1 The national emissions for
each of the intervening years were calculated by equating the yearly change in the national activity
indicators to the yearly change in the national emissions. The national emissions were calculated
according to Equation 2.2-3 when using fuel consumption indicators. For source categories where
population was used as the activity indicators, the yearly emissions were calculated using a linear
interpolation as shown in Equation 2.2-4.
NA.. - NA..
-
NEi+j - (NEt+5 - NEt+J_J x w '*;- + NE^ (Eq. 2.2.3)
7V 7V -
NE.+J = NEi + (NE.+5 - NE.) x j/5 (Eq. 2.2-4)
where: NE = national emissions by source subcategory
NA = national activity by source category
i = study year (1900, 1905,...,1970)
j = integer representing intervening years (1, 2, 3, or 4)
2.2.3 Changes in Emissions
The emission factors for the source category External Fuel Combustion, subcategory Wood have
been changed since the time the original report2 was published. This adjustment of the erroneously high
emission factors was based on more current information. The updated emission factors for the years
1900 through 1970 are presented in Table 2-7. No changes were made to the activity indicators for this
subcategory. The emissions presented in the 1993 through the 1997 Trends reports for the years 1900
through 1969, excluding 1940, 1950, and 1960, were based on recalculated emissions for this
subcategory using the adjusted emission factors. Therefore the values published in the original report
differ from those presented in the most recent Trends reports.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-10 1900-1939 Methodology
-------
2.2.4 Allocation of Emission Estimates to Tier I Categories
The emissions for the years 1900 through 1969 (excluding 1940, 1950, and 1960) were presented
graphically in the 1997 Trends report by Tier I categories. These categories were not the same as those
used in the original calculation of the emissions as described in the preceding sections. A correspondence
was developed between the original historic emission categories and the Tier I categories.
The historic emissions determined by source subcategories were summed to the five major source
categories described previously in Table 2-6. These categories were then mapped to the Tier I categories
as shown in Table 2-8. There was only one major historic source category (Solid Waste) which
corresponds directly to a Tier I category (Waste Disposal and Recycling). For all other Tier I categories,
the distribution of the historic major source categories to the Tier I categories was accomplished by the
same method described in section 2.1.6 for the SO2 and NOX emissions and summarized in Equations 2.1-
11 and 2.1-12.
2.3 REFERENCES
1. Historic Emission of Sulfur and Nitrogen Oxides in the United States from 1900 to 1980. EPA-
600/7-85-009a and b. U.S. Environmental Protection Agency, Cincinnati, OH. April 1985.
2. Historic Emission of Volatile Organic Compounds in the United States from 1900 to 1985. EPA-
600/7-88-008a. U.S. Environmental Protection Agency, Cincinnati, OH. May 1988.
3. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
4. Mobile Source Emission Factors. EPA-400/9-78-005 (NITS PB295672/A17). U.S. Environmental
Protection Agency, Washington, DC. March 1978.
5. M. Marians, J. Trijonis. Empirical Studies of the Relationship Between Emissions and Visibility in
the Southeast. EPA-405/5-79-009 (NITS PB80-156136/A06). U.S. Environmental Protection
Agency, Research Triangle Park, NC. 1979.
6. Background Information for New Source Performance Standards: Primary Copper, Zinc and Lead
Smelters, Volume 1: Proposed Standards. EPA-450/2-74-002a (NITS PB237832). U.S.
Environmental Protection Agency, Research Triangle Park, NC. October 1974.
7. National Emissions Report, National Emissions Data System (NEDS). EPA-450/4-83-022 (NITS
PB84-121375/MF). U.S. Environmental Protection Agency, Research Triangle Park, NC. 1984.
8. National Air Pollutant Emission Estimates, 1940-1985. EPA-450/4-86-018. U.S. Environmental
Protection Agency, Research Triangle Park, NC. January 1987.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 2-11 1900-1939 Methodology
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Table 2-1. Historic NOX and SO2 Emission Source Categories, Fuel Types, and Descriptions"
Source Category
Electric Utilities
Industrial Boilers
Commercial/Residential
Anthracite Coal - all uses
Wood - all uses
(1900 through 1945)
Pipelines
On-road Vehicles
Railroads
Coke Plants
Smelters
Vessels
Non-road Diesel Engines
Cement Plants
Wildfire
Miscellaneous
Activity Indicator
Consumption or Production
Bituminous Coal, Residual and
Distillate Oil, Natural Gas, and
Wood (after 1945)
Bituminous Coal, Residual and
Distillate Oil, Natural Gas and
Wood (after 1945)
Bituminous Coal, Residual and
Distillate Oil, Natural Gas, and
Wood (after 1945)
Anthracite Coal
Wood
Natural Gas
Gasoline and Diesel fuel
Bituminous Coal and Distillate
Oil
Bituminous Coal
Ore
Residual and Distillate Oil
Diesel Fuel
Portland Cement
Area
Other
Description
Power plants using coal, oil or gas to provide electricity for public consumption
Manufacturing and mining facilities using fuel for heat, power and chemical
feedstocks, and natural gas lease and plant operations
Nonmanufacturing enterprises using fuel for heat or power and agricultural,
forestry, and fisheries facilities using natural gas. Private dwellings using fuel
for heating, cooking, and other household uses
All facilities using anthracite coal as a fuel
All facilities using wood as a fuel
Internal combustion engines and turbines used to compress gas
Automobiles, trucks, buses, and motorcycles using gasoline or diesel fuel for
transportation
Trains, operated railroad equipment and other related operations
Furnace and merchant plants which produce coke
Primary copper, lead, and zinc smelting facilities
Commercial and private boats, including ocean going vessels
engines used in construction, logging, and road building
Portland cement manufacturing plants
Projected and unprotected forest land burned
Industrial processes not included about and other miscellaneous anthropogenic
sources
' Taken from Reference 1, Table 1 and Table 2.
-------
Table 2-2. Historic NOX and SO2 Emission Source Categories Not Estimated"
Source Categories
Range of Years
All Fuel Oil Burning
Natural Gas-fired Electric Utilities
Natural Gas-fired Industrial and Commercial/Residential Uses
Pipelines
1900 to 1920
1900 to 1915
1900 to 1920
1900 to 1945
' Taken from Reference 1, page 31.
Table 2-3. Processes Included in the Miscellaneous Source Category"
Miscellaneous Subcategory
Industrial Processes
Other Sources
Processes
Pulp and paper
Petroleum Refineries
Iron and Steel Manufacture
Primary Aluminum
Secondary Lead
Glass Manufacture
Chemical Manufacture
Aircraft
Vessels
Miscellaneous off-highway gasoline-powered vehicles
Fuel combustion
Solid Waste Disposal
Agricultural Burning
Coal Refuse Burning
Prescribed Burning
Subprocesses
sulfuric acid
carbon black
petrochemicals
ammonia
nitric acid
TNT
gasoline-powered
coal-powered
LPG
coke-oven gas
bagasse
1 Taken from Reference 1, Tables 10 and 11, page 31.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-13
1900-1939 Methodology
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Table 2-4. Major Source Categories for SO2 and NOX Historic Emissions
Major Source Categories
Electric Utilities
Source Categories
(used in determination of emission estimates)
Electric Utilities: bituminous coal, residual oil, distillate oil,
wood (after 1 945)
natural gas, and
Industrial
Other
Industrial boilers: bituminous coal, residual oil, distillate oil, natural gas, and
wood (after 1945)
Pipelines
Coke Plants
Cement Plants
Commercial/Residential
On-road Vehicles
Commercial/Residential: bituminous coal,
gas, and wood (after 1945)
residual oil, distillate oil, natural
On-road Vehicles: gasoline and diesel
Anthracite coal (all uses)
Wood (all uses from 1900 to 1940)
Railroads
Smelters
Vessels
Wildfires
Non-road diesel
Miscellaneous
Table 2-5. Correlation between Tier I Categories and Historic Major Source
Categories for SO2 and NOX Emission Estimates
Tier I Categories
Code
01
02
03
04
05
06
07
08
09
10
11
12
13
Name
Fuel Combustion - Electric Utilities
Fuel Combustion - Industrial
Fuel Combustion - Other
Chemical and Allied Product Manufacturing
Metals Processing
Petroleum and Related Industries
Other Industrial Processes
Solvent Utilization
Storage and Transport
Waste disposal and Recycling
On-road Vehicles
Non-road Engines and Vehicles
Miscellaneous
Historic Major Source Categories
Electric Utilities
Industrial
Commercial/Residential
Industrial
Industrial
Industrial
Industrial
assumed zero
assumed zero
Other
On-road Vehicles
Other
Other
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-14
1900-1939 Methodology
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Table 2-6. Source Categories and Activity Indicators for Historic VOC Emission Estimates"
Source
Category
Estimates for Every Fifth Year from 1900 to 1970
Source Subcategory
Activity Indicators
Estimates for Intervening Years
Source Subcategories
Activity Indicators
7R/IA/SPOR7V47YOA/
On-road Vehicles
Aircraft
Railroads
oil-fired
coal-fired
Vessels
oil-fired
coal-fired
Other Non-road Source Use
On-road Vehicle Gasoline plus
Diesel Consumption
Population
Railroad Oil Consumption
Railroad Oil Consumption
Vessel Oil Consumption
Vessel Coal Consumption
Non-road Fuel Use
On-road Vehicles
All Other Subcategories
Gasoline and Diesel
Consumption
Population
EXTERNAL FUEL COMBUSTION
Anthracite Coal
Bituminous Coal
Residual Oil
Distillate Oil
Natural Gas
Wood
Coke and Other Fuels
Anthracite Consumption
Bituminous Consumption
Residual Oil Consumption
Distillate Oil Consumption
Natural Gas Consumption
Wood Consumption
Coke Production
Anthracite Coal
Bituminous Coal
Residual and
Distillate Oil
Natural Gas
Wood
Coke and Other Fuels
Anthracite Consumption
Bituminous Consumption
Fuel Oil Consumption
Natural Gas Consumption
Wood Consumption
Population
INDUSTRIAL PROCESSES
Petrochemical Manufacture
Petroleum Marketing
gasoline
other
Population
On-road Vehicle Gasoline
Consumption
Diesel plus Distillate Oil
Consumption
Petrochemical
Manufacture
Petroleum Marketing
Population
Gasoline and Diesel
Consumption
-------
Table 2-6 (continued)
Source
Category
Estimates for Every Fifth Year from 1900 to 1970
Source Subcategory
Activity Indicators
Estimates for Intervening Years
Source Subcategories
Activity Indicators
INDUSTRIAL PROCESSES (continued)
Surface Coating Operations
Petroleum Refinery Process
Operations
Petroleum Production
crude oil
natural gas liquids
Miscellaneous Industrial
Processes
Carbon Black Mfg.
Population and Cement
Production
Crude Oil Run
Crude Oil Run
Crude Oil Run
Population
VMT
Surface Coating
Operations
All Other Subcategories
Population
Crude Oil Consumption
SOLID WASTE DISPOSAL
Incineration
Open Burning
Population
Population
All Subcategories
Population
MISCELLANEOUS OTHER SOURCES
Wildfire
Prescribed Fires
Other Burning
Other Solvent Evaporation
Area Burned
State Land Area minus
Wildfire Area
State Land Area minus
Wildfire Area
Population
All Subcategories
Population
' Taken from Reference 2, Tables 1 and 2, pages 5 and 9, respectively.
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Table 2-7. Adjusted VOC Emission Factors for External Fuel Combustion, Wood
Year
1900
1905
1910
1915
1920
1925
1930
1935
1940
1945
1950
1955
1960
1965
1970
1975
1980
1985
1990
Emission Factors
(tons/1 000 tons)
15.28
14.65
14.01
13.38
12.74
12.11
11.47
10.84
10.21
9.57
8.94
7.79
6.65
5.37
4.10
4.14
5.24
4.81
5.15
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-17
1900-1939 Methodology
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Table 2-8. Correlation between Tier I Categories and Historic Major Source Categories
for VOC Emission Estimates
Tier 1 Categories
Code
01
02
03
04
05
06
07
08
09
10
11
12
13
Name
Fuel Combustion - Electric Utilities
Fuel Combustion - Industrial
Fuel Combustion - Other
Chemical and Allied Product Manufacturing
Metals Processing
Petroleum and Related Industries
Other Industrial Processes
Solvent Utilization
Storage and Transport
Waste disposal and Recycling
On-road Vehicles
Non-road Engines and Vehicles
Miscellaneous
Historic Major Source Categories
External Combustion
External Combustion
External Combustion
Industrial Processes
Industrial Processes
Industrial Processes
Industrial Processes
Miscellaneous
Industrial Processes
Solid waste
Transportation
Transportation
Miscellaneous
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-18
1900-1939 Methodology
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SECTION 3.0
1940 -1984 METHODOLOGY
This methodology was used to estimate emissions for the majority of pollutants presented in the
Trends report for the years 1940, 1950, 1960, and 1970 to 1984. For all source categories, excluding on-
road vehicles and non-road engines and vehicles, this methodology was used to estimate the CO, NOX,
PM-10, SO2, and VOC for these years. The TSP emissions for the years 1940, 1950, 1960, and 1970 to
1992 were estimated using this methodology. The lead emissions are explained in section 5.0. The
emissions originating from on-road vehicles and non-road sources were estimated for the years 1940,
1950 and 1960 using this methodology. This section describes, in detail, the procedures used to estimate
these emissions.
3.1 INTRODUCTION
The 1940-1984 methodology was based on a "top-down" approach where national information was
used to create a national emission estimate. Emissions were estimated based on the source of the
emissions and, in the case of combustion sources, the fuel type. National activity of a process producing
emissions of interest was measured by the consumption of fuel, the throughput of raw materials, or some
other production indicator. The emission factor was used to determine the amount of an individual
pollutant emitted based on the activity of the process. In the case of PM-10, TSP, and SO2 emissions,
average fuel property values of ash and sulfur content were incorporated into the estimating procedure as
part of the emission factor. The final element used to estimate emissions was the control efficiency which
quantifies the amount of a pollutant not emitted due to the presence of control devices.
The overall procedure is outlined below:
INPUT DATA
Activity Indicators
Emission Factors
Fuel Property Values
Control Efficiency
ESTIMATION ALGORITHM
(Uncontrolled Emissions - Controlled Emissions) / (Actual Emissions)
I
OUTPUT DATA
National Emissions of Criteria Pollutants
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-1
1940-1984 Methodology
-------
The emissions were presented in the 1997 Trends report by Tier categories, but in the 1940-1984
methodology, the emissions were estimated by a different set of source categories. In most cases, these
source categories or subcategories were regrouped into the Tier categories. For several categories or
subcategories, the emissions were apportioned to more than one Tier II category. The estimation
procedures are presented in this section by the Tier II categories. Correspondence between these Tier II
categories and the 1940-1984 methodology source categories are presented in Table 3.1-1. This
correspondence between the categories is reiterated within the description of the procedures for each Tier
II category.
3.1.1 General Procedure
Since it is impossible to measure the emissions of every historic source individually, a top-down
estimating procedure is used. The emissions are calculated either for individual sources or for many
sources combined, using indicators of emissions. Depending on the source category, these indicators may
include fuel consumption or deliveries, VMT, tons of refuse burned, or raw material processed. When
indicators are used, emission factors which relate quantity of emissions to the activity indicator are also
used.
Emission factors are not necessarily precise indicators of emissions. They are quantitative estimates
of the average rate of emissions from many sources combined. These factors are most valid when applied
to a large number of sources. If their limitations are recognized, emission factors can be extremely useful
tools for estimating national emissions. The calculations of the emissions were made according to the
following general equation:
Emissions^ k = A{J x EF.>y. k x [1 -CE. . J (Eq. 3.1-1)
where: A = activity
EF = emission factor
CE = control efficiency (fraction)
i = year
j = source category
k = pollutant
The SO2 emission factor for sources where the emissions were based on fuel combustion included the
sulfur content of the fuel. Emission factors for PM-10 and TSP included the ash content of the fuel for
combustion sources. The VOC emission factors included a factor representing the reactive portion for a
variety of source categories.
As an aid in the calculation of the emissions by the 1940-1984 Methodology, two Excel
spreadsheets, collectively referred to as the Trends spreadsheets, were created for each year. An example
is provided in Table 3.1-2. These spreadsheets were entitled TRENDSxx.XLS and MGTMPxx.XLS,
where xx represents the year. The required data was entered into the TRENDSxx.XLS spreadsheet, after
which the MGTMPxx.XLS spreadsheet was opened and the necessary calculations (those shown above)
were made to estimate the national emissions. This procedure was designed to simplify the process of
estimating emissions for a new year. By using the TRENDSxx.XLS spreadsheet from the previous year
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 3-2 1940-1984 Methodology
-------
as a template, the spreadsheet for the new year was created by editing only the data requiring updating.
These spreadsheets now serve as a record of the calculations used to estimate the national emissions for
CO, NOX, PM-10, SO2, TSP, and VOC for the years 1940, 1950, 1960 and the years 1970 through 1984.
The calculations employed within the TRENDSxx.XLS spreadsheets required the use of specific
units for the activity indicators and the emission factors. These required units are specified in the
descriptions of the procedures for each of the Tier II categories. In general, the units for activity
indicators were short tons for solids, gallons for liquids, and cubic feet for gases. Emission factors were
expressed in units of metric pounds of pollutant per unit consumption or throughput. Control efficiency
was expressed as a dimensionless decimal fraction. By using these units, emissions calculated within the
spreadsheets are expressed in metric tons. The units of the raw data used as the basis for the activity
indicator or the emission factors often required conversion to the units specified above. The following
conversion factors were employed in many cases.
1 ton (metric) = 1.1023 tons (short)
1 ton (long) = 1.12 tons (short)
1 ton (short) = 0.9072 tons (metric)
lib (metric) = 1.1023 Ib
1 bbl = 42 gal
Emission factors were based on the most recent information available as of 1992. For many
categories, this most recent emission factor was used to estimate emissions for all years. For some
categories, the emission factor was the weighted average of emission factors for more specific
subprocesses, equipment types, or other subcategories. Weighting factors used to calculate an average
emission factor were often based on the relative activity of contributing subprocesses. In cases where the
activities of the subprocesses changed from one year to the next, the emission factors also varied over
time. Sulfur content or ash content of some fuels varied over time producing yearly variations in the SO2,
TSP, or PM-10 emission factors.
The PM-10 emission factors for some emission sources are not provided in the published documents
referenced within this section. In these cases, the emission factors may be found in the supplemental list
presented in Table 3.1-3. Therefore, the references given throughout this section are the possible sources
of PM-10 emission factors, including published documents and Table 3.1-3.
Control efficiencies were calculated from information provided in the latest AIRS/AFS extraction
utilizing the standard report number AFP650. This standard report contains emissions, annual
throughput (when available), and number of facilities by Source Classification Codes (SCC). If a
AIRS/AFS snapshot is not available for the current year, the current year's control efficiency was
estimated by projecting the previous years' results. Also one should use a projection of previous years'
results if the calculated control efficiency is nonsense. This could easily result if the operating rates (a
confidential field in AIRS/AFS) of several SCCs are not extracted and the calculated control efficiency
would be very low compare to previous year.
Calculation of the control efficiency involves three steps.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 3-3 1940-1984 Methodology
-------
1. Calculate uncontrolled emissions for the SCC or SCCs that incorporate a source category. This is
done by multiplying the operating rate by the latest emissions factor and converting to appropriate
units.
2. Add all uncontrolled and then all controlled emissions separately.
3. Calculate a percentage control efficiency as follows:
( Uncontrolled _ Actual \
Control _ \ emissions emissions)
efficiency / Uncontrolled}
\ emissions }
(Eq. 3.1-2)
The following information used in the next two equations, can be obtained from the AFP650 Report or
AP-42.
SCC
Operating rate (1000 gallons)
PM-10 Emission Factor (Ibs per 1000 gallons)
PM-10 Actual Emissions (tons)
The following information was calculated.
PM-10 Uncontrolled Emissions (tons)
For SCC = 1-01-005-04
1-01-005-04
419,478
5.19
723
1,089
1-01-005-01
72,889
1.0
11
36
Uncontrolled 410470 1000 ,
emissions gallons
For SCC = 1-01-005-01
Uncontrolled 79000 1000 ,
emissions gallons
Jn [ Ibs
1000
gallons
o f lbs
1000
gallons
' v l[to/i]
2000[/fc]
v l[to»]
2000M
The control efficiency for this source category was calculated as follows:
0/ Control _ ((1089 + 36) - (723 +
11)) [tons]
'"efficiency (1089 + 36) [tons]
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-4
1940-1984 Methodology
-------
NOTE: Since the estimates are based on input data which may be updated or revised from time to
time, the estimating procedure may change. For example, the emission factors published in AP-42 may
be revised. If this occurs, it is necessary to revise all previous estimates where the original emission
factor was used. Similarly, fuel consumption data may change from one year to the next as the statistics
produced by various trade associations and government agencies are revised. Therefore, it is necessary
to revise previous annual estimates when revised data are available. During the estimation procedure, it
will become known which previous estimates require updating. In addition, all information for the last
calendar year may not be available. Therefore, the best available information is used with the intent to
amend the estimates as necessary in the following year.
3.1.2 Organization of Procedures
The 1940-1984 Methodology used to estimate emissions is described by Tier II category. For each
category the procedure is divided into four sections: (1) technical approach, (2) activity indicator, (3)
emission factor, and (4) control efficiency. The procedures for obtaining the activity indicators, emission
factors or control efficiencies are arranged in a variety of different ways, depending on the specific
requirements of the category (e.g., by pollutant, process, or fuel type).
References are provided at the end of the description of procedures for each Tier II category. Many
of these references are published annually as part of a series. In some cases, several references are
provided for the same information reflecting a change or discontinuation of one source and its
replacement by another. The specific source used would depend on the specific year for which
information was needed. All tables and supporting data immediately follow the description of the
procedures for each Tier II category.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 3-5 1940-1984 Methodology
-------
Table 3.1-1. Correspondence Between Tier II Categories and 1940-1984 Methodology Emission Source Categories
Tier I Category
Fuel Combustion -
Electric Utility
Fuel Combustion -
Industrial
Tier II Category
Coal
Oil
Gas
Coal
Oil
Tier I/Tier II
Code
01-01
01-02
01-03
02-01
02-02
1940-1984 Methodology
Emission Source Categories
Bituminous Coal and Lignite
Anthracite Coal
Residual Oil
Distillate Oil
Natural Gas
Bituminous Coal and Lignite
Anthracite Coal
Residual Oil
Distillate Oil
Industrial Processes - CO
Emissions
Industrial Processes - NOX
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - SO2
Emissions
Industrial Processes - VOC
Emissions
1940-1984 Methodology Emission Source
Subcategories
Electric Utility
Electric Utility
Electric Utility
Electric Utility
Electric Utility
Industrial
Industrial
Industrial
Industrial
Process Heaters (oil)
Petroleum Refineries (process heaters - oil)
Miscellaneous Process Sources (process heaters -
oil)
Other Industrial Processes (petroleum refineries -
process heaters (oil))
Petroleum Refinery Process Operation (process
heaters - oil)
-------
Table 3.1-1 (continued)
Tier I Category
Fuel Combustion -
Electric Utility
Fuel Combustion -
Industrial, con't.
Tier II Category
Coal
Gas
Other
Tier I/Tier II
Code
01-01
02-03
03-04
1940-1984 Methodology
Emission Source Categories
Bituminous Coal and Lignite
Anthracite Coal
Natural Gas
Miscellaneous Fuels
Industrial Processes - CO
Emissions
Industrial Processes - NOX
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - SO2
Emissions
Industrial Processes - VOC
Emissions
Miscellaneous Fuels
1940-1984 Methodology Emission Source
Subcategories
Electric Utility
Electric Utility
Industrial (boilers and gas pipelines and plants)
Industrial (coke-oven gas)
Process Heaters (gas)
Petroleum Refineries (process heaters - gas)
Miscellaneous Process Sources (process heaters -
gas)
Other Industrial Processes (petroleum refineries -
process heaters (gas))
Petroleum Refinery Process Operation (process
heaters - gas)
Industrial (coke, bagasse, kerosene, LPG, and
wood)
-------
Table 3.1-1 (continued)
Tier I Category
Fuel Combustion -
Electric Utility
Fuel Combustion -
Other
Tier II Category
Coal
Commercial and
Institutional Coal
Commercial and
Institutional Oil
Commercial and
Institutional Gas
Residential Wood
Residential Other
Tier I/Tier II
Code
01-01
03-01
03-02
03-03
03-05
03-06
1940-1984 Methodology
Emission Source Categories
Bituminous Coal and Lignite
Anthracite Coal
Bituminous Coal and Lignite
Anthracite Coal
Residual Oil
Distillate Oil
Natural Gas
Miscellaneous Fuels
Bituminous Coal and Lignite
Anthracite Coal
Residual Oil
Distillate Oil
Natural Gas
Miscellaneous Fuels
1940-1984 Methodology Emission Source
Subcategories
Electric Utility
Electric Utility
Commercial and Institutional
Commercial and Institutional
Commercial and Institutional
Commercial and Institutional
Commercial and Institutional
Residential (wood)
Residential
Residential
Residential
Residential
Residential
Residential (kerosene and LPG)
-------
Table 3.1-1 (continued)
Tier I Category
Fuel Combustion -
Electric Utility
Chemical and Allied
Product Manufacture
Tier II Category
Coal
Organic Chemical
Manufacturing
Inorganic Chemical
Manufacturing
Tier I/Tier II
Code
01-01
04-01
04-02
1940-1984 Methodology
Emission Source Categories
Bituminous Coal and Lignite
Anthracite Coal
Industrial Processes - CO
Emissions
Industrial Processes - NOX
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - CO
Emissions
Industrial Processes - NOX
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - SO2
Emissions
Industrial Processes - VOC
Emissions
1940-1984 Methodology Emission Source
Subcategories
Electric Utility
Electric Utility
Charcoal
Petrochemicals
Petrochemicals
Charcoal
Chemical Industry (petrochemicals)
Manufacture of Petrochemicals (all subcategories,
excluding storage and handling and waste disposal)
Miscellaneous Industrial Processes [miscellaneous
chemical products (charcoal)]
Ammonia
Titanium Dioxide - chloride process
Ammonia
Nitric Acid
Chemical Industry (sulfuric acid and calcium
carbide)
Other Industrial Processes (sulfuric acid)
Miscellaneous Industrial Processes [miscellaneous
chemical products (ammonia)l
-------
Table 3.1-1 (continued)
Tier I Category
Tier II Category
Tier I/Tier I
Code
1940-1984 Methodology
Emission Source Categories
1940-1984 Methodology Emission Source
Subcategories
Fuel Combustion -
Electric Utility
Coal
01-01
Bituminous Coal and Lignite
Anthracite Coal
Electric Utility
Electric Utility
Chemical and Allied
Product Manufacture,
cont.
Polymer and Resin
Manufacturing
04-03
Agricultural Chemical
Manufacturing
04-04
Pain, Varnish,
Lacquer, and Enamel
Manufacturing
04-05
Pharmaceutical
Manufacturing
04-06
Other Chemical
Manufacturing
04-07
Industrial Processes - VOC
Emissions
Miscellaneous Industrial Processes [plastics
manufacture (all subcategories, excluding
fabrication) and miscellaneous chemical products
(synthetic fibers and synthetic rubber)]
Industrial Processes - PM-10
Emissions
Chemical Industry [fertilizers (ammonium nitrate,
diammonium phosphate, and urea)]
Industrial Processes - VOC
Emissions
Miscellaneous Industrial Processes [miscellaneous
chemical products (paint)]
Industrial Processes - VOC
Emissions
Miscellaneous Industrial Processes [miscellaneous
chemical products (Pharmaceuticals)]
Industrial Processes - CO
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - SO2
Emissions
Industrial Processes - VOC
Emissions
Carbon Black Production (oil process, gas process,
and channel process)
Chemical Industry [carbon black production (oil
process, gas process, and channel process),
charcoal, and soap and detergent]
Other Industrial Processes (carbon black)
Miscellaneous Industrial Processes [miscellaneous
chemical products (carbon black - oil process and
gas process)]
-------
Table 3.1-1 (continued)
Tier I Category
Tier II Category
Tier I/Tier I
Code
1940-1984 Methodology
Emission Source Categories
1940-1984 Methodology Emission Source
Subcategories
Fuel Combustion -
Electric Utility
Coal
01-01
Bituminous Coal and Lignite
Anthracite Coal
Electric Utility
Electric Utility
Metals Processing
Nonferrous
05-01
Ferrous
05-02
Not Elsewhere
Classified
05-03
Industrial Processes - CO
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - SO2
Emissions
Primary Aluminum
Primary Metals Industry (aluminum, copper, zinc,
and lead)
Secondary Metal Industry (aluminum, copper, and
lead)
Nonferrous Smelters
Other Industrial Processes (primary aluminum and
secondary lead)
Industrial Processes - CO
Emissions
Industrial Processes - NOX
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - SO2
Emissions
Industrial Processes - VOC
Emissions
Iron Foundries
Steel Manufacturing
Iron and Steel
Iron and Steel Industry
Primary Metals Industry (ferroalloys)
Secondary Metals Industry ( grey iron foundries and
steel foundries)
Other Industrial Processes (iron and steel)
Miscellaneous Industrial Processes [other
processes (by-product coke and sintering)]
Industrial Processes - PM-10
Emissions
Mining Operations
-------
Table 3.1-1 (continued)
Tier I Category
Fuel Combustion -
Electric Utility
Petroleum and
Related Industries
Tier II Category
Coal
Oil and Gas
Production
Petroleum Refineries
and Related Industries
Asphalt Manufacturing
Tier I/Tier II
Code
01-01
06-01
06-02
06-03
1940-1984 Methodology
Emission Source Categories
Bituminous Coal and Lignite
Anthracite Coal
Industrial Processes - SO2
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - CO
Emissions
Industrial Processes - NOX
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - SO2
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - VOC
Emissions
1940-1984 Methodology Emission Source
Subcategories
Electric Utility
Electric Utility
Other Industrial Processes [sulfur recovery plants
(natural gas fields)]
Petroleum Marketing and Production (crude oil
production and natural gas liquids)
Petroleum Refineries
Petroleum Refineries (FCC, TCC, and flares)
Miscellaneous Process Sources (petroleum
refining)
Other Industrial Processes [sulfur recovery plants
(refineries) and petroleum refineries (FCC,
TCC, and flares)]
Petroleum Refinery Process Operation (refinery
operations, compressors, blow down systems,
process drains, vacuum jets, cooling towers, and
miscellaneous)
Mineral Products Industry (asphalt batching and
asphalt roofing)
Petroleum Refinery Process Operation (asphalt
blowinq)
-------
Table 3.1-1 (continued)
Tier I Category
Tier II Category
Tier I/Tier I
Code
1940-1984 Methodology
Emission Source Categories
1940-1984 Methodology Emission Source
Subcategories
Fuel Combustion
Electric Utility
Coal
01-01
Bituminous Coal and Lignite
Anthracite Coal
Electric Utility
Electric Utility
Other Industrial
Processes
Agriculture, Food, and
Kindred Products
07-01
Wood, Pulp and
Paper, and Publishing
Products
07-03
Rubber and
Miscellaneous Plastic
Products
07-04
Industrial Processes - PM-10
Emissions
Industrial Processes - VOC
Emissions
Agricultural Industries
Miscellaneous Industrial Processes [other
processes (bakeries, fermentation, and vegetable
oil)]
Industrial Processes - CO
Emissions
Industrial Processes - NOX
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - SO2
Emissions
Kraft Pulp and Paper
Kraft Pulp
Miscellaneous Process Sources (pulp and paper,
semi-chemical, plywood, and lumber)
Other Industrial Processes (kraft pulp production
and sulfite)
Industrial Processes - VOC
Emissions
Miscellaneous Industrial Processes [other
processes (tires)]
-------
Table 3.1-1 (continued)
Tier I Category
Tier II Category
Tier I/Tier I
Code
1940-1984 Methodology
Emission Source Categories
1940-1984 Methodology Emission Source
Subcategories
Fuel Combustion
Electric Utility
Coal
01-01
Bituminous Coal and Lignite
Anthracite Coal
Electric Utility
Electric Utility
Other Industrial
Processes, con't.
Mineral Products
07-05
Industrial Processes - CO
Emissions
Industrial Processes - NOX
Emissions
Industrial Processes - PM-10
Emissions
Industrial Processes - SO2
Emissions
Industrial Processes - VOC
Emissions
Asphalt Roofing
Lime
Cement Manufacturing
Glass Manufacturing
Lime
Mineral Products Industry (cement manufacturing,
bricks, clay sintering, concrete batching, fiberglass,
glass, gypsum manufacturing, and lime
manufacturing)
Mining Operations (coal mining, sand and gravel,
stone and rock crushing, phosphate rock, clays, and
potash)
Chemical Industry [fertilizers (rock pulverization)]
Other Industrial Processes (cement manufacturing,
glass manufacturing, and lime processing)
Miscellaneous Industrial Processes [other
processes (glass manufacturing)]
-------
Table 3.1-1 (continued)
Tier I Category
Fuel Combustion -
Electric Utility
Solvent Utilization
Storage and
Transport
Tier II Category
Coal
Degreasing
Graphic Arts
Dry Cleaning
Surface Coating
Other Industrial
Nonindustrial
Bulk Terminals and
Plants
Petroleum and
Petroleum Product
Storage
Tier I/Tier II
Code
01-01
08-01
08-02
08-03
08-04
08-05
08-06
09-01
09-02
1940-1984 Methodology
Emission Source Categories
Bituminous Coal and Lignite
Anthracite Coal
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
1940-1984 Methodology Emission Source
Subcategories
Electric Utility
Electric Utility
Miscellaneous Industrial Processes [other
processes (degreasing)]
Miscellaneous Industrial Processes [other
processes (graphic arts)]
Miscellaneous Industrial Processes [other
processes (dry cleaning)]
Miscellaneous Industrial Processes [other
processes (adhesives)]
Surface Coating Operations
Miscellaneous Organic Solvent Evaporation
(architectural coating, auto refinishing, and other
solvent use)
Miscellaneous Industrial Processes [plastics
manufacture (fabrication) and other processes
(waste solvent recovery, organic solvent, and
solvent extraction)]
Miscellaneous Industrial Processes [other
processes (fabric scouring)]
Miscellaneous Organic Solvent Evaporation
(cutback asphalt paving, pesticides, and other
solvent use)
Petroleum Marketing and Production (bulk gasoline
terminals and gasoline bulk plants)
Petroleum Marketing and Production (gasoline
storage at refineries, crude oil storage, and other
products)
-------
Table 3.1-1 (continued)
Tier I Category
Fuel Combustion -
Electric Utility
Storage and
Transport, cont.
Waste Disposal and
Recycling
On-road Vehicles
Tier II Category
Coal
Petroleum and
Petroleum Product
Transport
Service Stations:
Stage I
Service Stations:
Stage II
Organic Chemical
Storage
Incineration
Open Burning
Other
(All Categories) Light-
Duty Gas Vehicles
and Motorcycles,
Light-Duty Gas
Trucks, and
Heavy-Duty Gas
Vehicles
Tier I/Tier II
Code
01-01
09-03
09-04
09-05
09-07
10-01
10-02
10-07
11
1940-1984 Methodology
Emission Source Categories
Bituminous Coal and Lignite
Anthracite Coal
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
Industrial Processes - VOC
Emissions
Solid Waste Disposal
Solid Waste Disposal
Industrial Processes - VOC
Emissions
On-road Vehicles
1940-1984 Methodology Emission Source
Subcategories
Electric Utility
Electric Utility
Petroleum Marketing and Production (refinery
product loading and crude oil loading)
Petroleum Marketing and Production [gasoline
service stations (loading or stage 1)]
Petroleum Marketing and Production [gasoline
service stations (unloading or stage 2)]
Miscellaneous Industrial Processes [other
processes (waste solvent recovery)]
Manufacture of Petrochemicals (storage and
handling)
Incineration
Open Burning
Manufacture of Petrochemicals (waste disposal)
Gasoline (leaded and unleaded)
-------
Table 3.1-1 (continued)
Tier I Category
Fuel Combustion -
Electric Utility
Non-road Engines
and Vehicles
Miscellaneous
Tier II Category
Coal
Nonroad Gasoline
Engines
Nonroad Diesel
Aircraft
Marine Vessels
Railroads
Other Combustion
(forest fires)
Tier I/Tier II
Code
01-01
12-01
12-02
12-03
12-04
12-05
14-02
1940-1984 Methodology
Emission Source Categories
Bituminous Coal and Lignite
Anthracite Coal
Other Non-road Engines
Vessels
Other Non-road Engines
Aircraft
Vessels
Railroads
Forest fires and Prescribed
Burning
Other Miscellaneous Sources
1940-1984 Methodology Emission Source
Subcategories
Electric Utility
Electric Utility
Gasoline
Gasoline
Diesel
all subcategories
Residual Fuel Oil
Diesel Oil
Coal
all subcategories
all subcategories
all subcategories
-------
Table 3.1-2. Example Spreadsheet - Distillate Oil Combustion and Emission Factors for Year 19xx
Source Category
Electric Utility
Industrial
Commercial-
Institutional
Residential
Total
Consumption
106gal
733.6
3378.1
3555.2
6152.5
13819.4
TSP Factors
MLB/103 gal
4.7
2.6
1.8
2.3
SO2 Factors
MLB/103 gal
36.0
35.6
39.9
31.6
NOX Factors
MLB/103 gal
61.8
29.5
18.1
16.3
VOC Factors
MLB/103 gal
3.5
1.0
0.3
0.6
CO Factors
MLB/103 gal
13.2
7.0
4.5
4.5
Pb Factors PM-10 Factors
MLB/106 gal MLB/103 gal
0.38 4.1
0.38 1.73
0.38 0.98
0.38 2.23
PM-10 Control Efficiencies for Distillate Oil
Electric Utility
Industrial
Commercial-
Institutional
Residential
0.565
0.096
0.123
0
Nationwide Emissions from Distillate Oil
Source Category
Electric Utility
Industrial
Commercial-
Institutional
Residential
Total
NOTES:
aal -
TSP Emissions
1000MT
1.7
4.4
3.2
7.1
16.4
oallmv MTR - t
Combustion
SO2 Emissions
1000MT
8.7
60.2
70.9
97.3
237.0
ton ,
NOX Emissions
1000MT
2.8
49.8
32.2
50.1
135.0
MT - mptrir ton
VOC Emissions
1000MT
0.0
1.7
0.5
1.8
4.1
CO Emissions
1000MT
4.8
11.8
8.0
13.8
38.5
Pb Emissions
Megagrams
0.1
0.6
0.7
1.2
2.6
PM-10 Emissions
1000MT
0.7
2.6
1.5
6.9
11.7
ton 1.1023 metric ton
-------
Table 3.1-3. Supplemental PM-10 Emission Factors
1940 - 1984 Methodology
Emission Sources
External Combustion, Boilers
Industrial
coke, petroleum
Residential
Distillate oil
Kerosene
Wood
Stoves
Fireplaces
Chemical Industry
Plastics Production
Polyethylene
Primary Metals
Copper
Fugitives
Ferroalloys
Other Ferroalloys
Ferroalloy Handling
Lead
Fugitives
Zinc
Fugitives
Mining Operations
Copper Ore
Crushing
Open pit overburden removal
Drill/blasting
Loading
Truck dumping
Transfer/conveying
Ore crushing
Storage
Iron Ore Mining
Lead Ore Crushing
Zinc Ore Crushing
Coal
Surface Mining
Coal Handling
Pneumatic Dryer
Sand and Gravel
Secondary Metals
Aluminum
Fugitives
Copper
Fugitives
Grey Iron
Fugitives
Steel Foundry
Fugitives
Lead
Fugitives
TSP
Ib/unit
1.5
2.5
2.5
40.2
28.0
1.0
26.5
300.0
28.0
25.8
7.5
8.6
0.0008
0.001
0.05
0.04
0.15
6.4
2.0
0.44
6.0
6.0
0.5
0.5
3.0
0.1
3.7
10.7
8.6
13.0
14.3
PM-10
Ib/unit
1.2
2.46
2.46
40.2
28.0
0.66
17.5
234.0
18.5
22.0
6.4
3.9
0.0003
0.0008
0.022
0.032
0.08
2.9
0.7
0.18
5.1
2.3
0.2
0.17
1.5
0.029
3.4
6.4
5.2
7.8
12.0
PM-10
Mlb/unit
1.09
2.23
2.23
36.5
25.4
.599
14.42
212.29
16.78
19.95
5.81
3.54
0.00027
0.00073
0.019958
0.0290
0.0726
2.631
0.635
0.16
4.63
2.09
1.81
0.15
1.36
.026
3.08
5.81
4.72
7.08
10.89
Units
tons burned
103 gallons
103 gallons
tons burned
tons burned
tons product
tons of ore concentrate
tons produced
tons processed
tons of ore concentrate
tons of ore concentrate
tons of ore processed
tons of ore processed
tons of ore processed
tons of ore processed
tons of ore processed
tons of ore processed
tons of ore processed
tons of ore processed
tons of ore processed
tons of ore processed
tons of ore processed
tons of coal mined
tons of coal shipped
tons of coal dried
tons of product
tons of metal produced
tons of charge
tons of metal charged
tons of metal charged
tons of metal charged
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-19
1940-1984 Methodology
-------
Table 3.1-3 (continued)
1940 -1984 Methodology
Emission Sources
Mineral Products
Asphalt concrete
Fugitives
Brick Manufacture
Material Handling
Cement Manufacture
Fugitives
Lime Manufacture
Fugitives
Miscellaneous Process Sources
Pulp and Paper
Sulfite
Semichemical, recovery furnace
Wood Products
Plywood
Lumber
Solid Waste Disposal
Incinerators
Residential Single Chamber
w/o Primary Burner
w/ Primary Burner
Forest Fires and Prescribed Burning
Forest Wild Fires
Prescribed Burning
Other Miscellaneous Sources
Agricultural Burning
Structural Fires
Coal Refuse Fires
Non-road Vehicles
Aircraft
Commercial Aviation
Air Taxi
General Aviation
Military
Railroads
Diesel
Residual
Coal
Vessels
Residual
Diesel
Gasoline
TSP
Ib/unit
0.3
4.5
18.0
4.7
14.0
24.0
2.5
3.6
35.0
7.0
17.0
20.0
14.1
16.0
17.0
1.0
.5
.2
16.2
25.0
25.0
60.0
19.3
24.0
0.0
PM-10
Ib/unit
0.15
1.4
10.4
1.75
12.6
22.3
1.3
1.4
13.0
4.7
13.3
15.6
13.5
6.0
17.0
1.0
0.45
0.18
16.2
25.0
23.0
31.0
17.8
24.0
—
PM-10
Mlb/unit
0.14
1.27
9.44
1.59
11.4
20.2
1.2
1.0
11.8
4.3
12.1
14.2
12.3
5.4
15.4
0.9072
0.408
0.163
14.70
22.68
20.87
28.12
16.15
21.77
Units
tons of concrete produced
tons of raw material
tons of cement produced
tons of lime produced
ton air dry unbleached pulp
ton air dry unbleached pulp
tons of plywood produced
tons of lumber produced
tons of waste
tons of waste
tons of vegetation burned
tons of vegetation burned
tons of vegetation burned
tons of vegetation burned
tons of vegetation burned
LTD
LTD
LTD
LTD
103 Gallons
103 Gallons
Tons burned
103 Gallons
103 Gallons
—
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-20
1940-1984 Methodology
-------
3.2 FUEL COMBUSTION ELECTRIC UTILITY - COAL: 01-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(01) FUEL COMBUSTION-
ELECTRIC UTILITY
Tier II Category
(01) Coal
Tier II Subcategory
Bituminous, Subbituminous, and
Lignite Coal
Anthracite Coal
3.2.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, the activity indicator for bituminous coal was expressed in million short tons and the
emission factors were expressed in metric pounds/short ton. The activity indicator for anthracite coal
was expressed in thousand short tons and the emission factors were expressed in metric pounds/short ton.
All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.2-1.
PM-10 Emissionsyear = PM-10 Emissions 1975
TSP Emissionsyear
TSP Emissions
(Eq. 3.2-1)
1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
The NOX emissions produced by the combustion of bituminous coal by electric utilities were
calculated with an applied 80 percent EPA-specified rule effectiveness for post-1977 years.
Equation 3.2-2 summarizes this calculation.
Emissions^ _ m coal = AIm coal x EF^ _ m coal x 11 -
CE
v --/ j
RE
NOX , bit. coal
Too
(Eq. 3.2-2)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-21
1940-1984 Methodology
Category: 01-01
-------
where: AI = activity indicator
EF = emission factor
RE = rule effectiveness of 0.80
CE = control efficiency (expressed as a percentage)
3.2.2 Activity Indicator
The activity indicator for the combustion of anthracite coal by electric utilities was the anthracite
coal receipts at electric utilities obtained from Reference la.
The activity indicator for bituminous, subbituminous, and lignite coal combustion was calculated as
the difference between the total national consumption of coal by electric utilities and the anthracite coal
consumption at electric utilities as determined above. The total national consumption of coal was
obtained from Reference 2 or Reference 3.
3.2.3 Emission Factor
For the combustion of anthracite coal (SCC 1-01-001-xx), the emission factors for all pollutants
except PM-10 were obtained from Reference 4a. The PM-10 emission factor was obtained from
Reference 5. Emission factors for PM-10 and TSP were multiplied by an ash content value of 11 percent.
The SO2 emission factor was multiplied by the national average sulfur content value obtained from
Reference 1.
For the combustion of bituminous, subbituminous, and lignitecoal (SCC 1-01-002-xx), the emission
factors were the weighted averages of the emission factors for different firing configurations. The CO,
NOX, TSP, and VOC emission factors for each firing configuration were obtained from References 4b and
4c. The PM-10 emissions factors were obtained from Reference 5. The CO and VOC emission factors
were weighted by the 1980 quantity of bituminous coal and lignite burned by industry in each firing
configuration as reported in Reference 3. For the years 1977 through 1984, the NOX, PM-10, and TSP
emission factors were weighted by the national capacity of each boiler types determined annually. Boiler
capacity data was based on 1976 data obtained from Reference 6. To update the capacity data after
1976, additional capacities of all coal-fired plants that came on line during each year between 1976 and
the year under study were obtained from Reference 7. All new boilers added since 1977 were assumed to
be pulverized dry bottom tangentially-fired boilers and were subject to New Source Performance
Standards. These weighting factors were used to determine the bituminous coal and the lignite emission
factors for NOX, PM-10, and TSP. The weighted averages of these two emission factors for each of the
three pollutants were calculated using the total fuel receipts obtained from Reference la as weighting
factors. Ash contents of 13 percent for bituminous coal and 11 percent for lignite were applied to the
PM-10 and TSP emission factors.
No specific information concerning the procedures for determining the NOX and TSP emission
factors for the years prior to 1977 or the PM-10 emission factor for 1975 through 1977 is currently
available. Emission factors were not used in the estimations of PM-10 emissions prior to 1975.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-22 Category: 01-01
-------
The uncontrolled SO2 emission factor was the weighted average of the bituminous, subbituminous
and lignite SO2 emission factors obtained from Reference 4. Weighting factors were the quantity of fuel
receipts at electric utilities for steam plants with a capacity greater than 50 MW as reported in
Reference 1. Each emission factor was multiplied by the sulfur content value obtained from Reference 8.
The calculation is summarized in Equation 3.2-3.
(QSBx EFSBx SSB) + (QL>< EFL
><
uncontrolled ODD ^ ^' 3-2-3)
*ZB "SB "L
where: EF = uncontrolled emission factor
Q = quantity of fuel receipts
S = sulfur content value
B = bituminous coal
SB = subbituminous coal
L = lignite coal
This uncontrolled emission factor was adjusted for emission controls using the control efficiency,
resulting in a controlled emission factor. The procedure for determining the control efficiency is
presented in the next section.
3.2.4 Control Efficiency
3.2.4.1 Anthracite Coal
The TSP control efficiency was obtained from Reference 9. When this source was unavailable, a
control efficiency of 99 percent was used.
The PM-10 control efficiencies for the years 1975 through 1984 were based on the 1988 PM-10
control efficiency obtained from Reference 10. During these years, any changes in the TSP control
efficiencies from the 1985 TSP control efficiency value were reflected in the PM-10 control efficiencies.
For the years 1940 through 1974, no control efficiencies were use to estimate PM-10 emissions.
No control efficiencies were applied to the activity data to estimate the CO, NOX, SO2, or VOC
emissions from this source.
3.2.4.2 Bituminous, Subbituminous, and Lignite Coal
The TSP control efficiencies were derived from the uncontrolled and controlled emissions.
Uncontrolled TSP emissions were calculated for all point sources with SCCs 101002xx and 101003xx by
multiplying the operating rates as obtained from NEDS or AIRS (References 6 and 11) by the
appropriate emission factors (see preceding section). These products were summed to obtain the total
uncontrolled TSP emissions. The controlled TSP emissions for all point sources with SCCs 101002xx
and 101003xx were obtained from Reference 6 or Reference 11 and summed to obtain the total
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-23 Category: 01-01
-------
controlled TSP emissions. These values were used in Equation 3.2-4 to calculate the TSP control
efficiencies.
where: CE = control efficiency
UE = uncontrolled emissions
AE = controlled emissions
The PM-10 control efficiencies for the years 1975 through 1984 were based on the 1988 PM-10
control efficiency obtained from Reference 10. During these years, any changes in the TSP control
efficiencies from the 1985 TSP control efficiency value were reflected in the PM-10 control efficiencies.
For the years 1940 through 1974, no control efficiencies were used to estimate the PM-10 emissions.
No control efficiencies were applied to the activity data to estimate the CO, NOX, or VOC emissions
from bituminous, subbituminous, and lignite coal combustion.
The SO2 control efficiency was based on plant level information on the amount of SO2 removed by
the control devices. The control efficiency was then applied to the uncontrolled emission factor to obtain
the controlled SO2 emission factor.
The following information was obtained from Reference 12: (1) plant and unit name and number,
(2) percentage of SO2 removed, and (3) commercial start-up date. The amount of SO2 removed at each
plant was calculated using this information along with the amount of coal consumed by the plant obtained
from Reference Ib or Reference 13, the unit and plant capacity obtained from Reference 8, the percent
sulfur content obtained from Reference 1, and the uncontrolled SO2 emission factor for the combustion of
bituminous coal at electric utilities (see preceding section). The amount of SO2 removed at each plant
was calculated according to Equation 3.2-5.
S02>removed = C x x EFuncontrMed xRFxSCxOP (Eq. 3.2-5)
where: C = coal consumed at plant
UC = unit capacity at plant
PC = total plant capacity
EF = SO2 emission factor
RF = fraction of SO2 removed at plant
SC = sulfur content
OP = fraction of year plant in operation (assumed that the month after start-up date was
first full month of operation)
The SO2 removed at each unit was summed to obtain the national total SO2 removed. The SO2
control efficiency was calculated according to Equation 3.2-6 and was then applied to the uncontrolled
emission factor to obtain the controlled emission factor.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-24 Category: 01-01
-------
so
i-n-i 2, removed
CEso2 = - - - (Eq. 3.2-6)
uncontrolled Bituminous Coal
where: CE = control efficiency
EF = emission factor
AI = activity indicator
3.2.5 References
1. Cost and Quality of Fuels for Electric Utility Plants. DOE/EIA-0191(xx). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
(a) Table entitled, "Receipts of Coal by Rank Census Division, and State, [YEAR]"
(b) Appendix A
2. Electric Power Annual. DOE/EIA-0348(xx). Energy Information Administration, U.S. Department
of Energy, Washington, DC. Annual.
3. Quarterly Coal Report: January - March. DOE/EIA-0121 (xx/1Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Quarterly.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency. Research Triangle Park, NC. September 1991.
(a) Volume I, Table 1.2-1, Supplement B, September 1988.
(b) Volume I, Table 1.1-1
(c) Volume I, Table 1.7-1
5. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
6. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual
7. Energy Data System, FPC 67 form run to print boiler capacity sorted by boiler type. 1976.
8. Inventory of Power Plants in the United States 19xx. DOE/EIA-0095(xx). U.S. Department of
Energy, Energy Information Administration. Washington, DC. Annual.
9. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park, NC. February 9, 1980.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-25 Category: 01-01
-------
10. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends," Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990..
11. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
12. Flue Gas Desulfurization Information System, FGDIS.
13. U.S. Department of Energy. Electric Generating Plant List (GURF) Report. Washington, DC.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-26 Category: 01-01
-------
3.3 FUEL COMBUSTION ELECTRIC UTILITY - OIL: 01-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(01) FUEL COMBUSTION - (02) Oil Residual
ELECTRIC UTILITY Distillate
3.3.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in million gallons and emission factors were
expressed in metric pounds/thousand gallons. All control efficiencies were expressed as dimensionless
fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.3-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 33-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.3.2 Activity Indicators
The activity indicators for the combustion of residual and distillate oil were the consumption of these
fuel types by electric utilities. Distillate oil consumption was assumed to be equal to the "adjusted"
distillate fuel oil sales to electric utilities obtained from Reference 1 or Reference 2. Residual fuel oil
consumption was obtained from Reference 1 or, when this reference was unavailable, the residual oil
consumption was calculated as the difference between the total oil consumption and the distillate oil
consumption. The total annual oil consumption was obtained from Reference 3.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-27 Category: 01-02
-------
3.3.3 Emission Factors
The emission factors for residual oil were calculated from the emission factors for the following four
SCCs: 1-01-004-01, 1-01004-04, 1-01-004-05, and 1-01-004-05. For each pollutant, except PM-10,
these emission factors were obtained from Reference 4a. The PM-10 emission factors were obtained
from Reference 5. The SO2 emission factors for these four SCCs were each the sum of the emission
factors for SO2 and SO3. Each SO3 emission factor was converted to an emission factor by weight of SO2
prior to the summing by using the ratio of the molecular weights of SO2 and SO3 (i.e., 64/80). The SO2,
TSP, and PM-10 emission factors for these four SCCs were multiplied by the fuel sulfur content from
Reference 6.
For each pollutant, the overall emission factor for the combustion of residual oil was the arithmetic
average of the emission factors for the four SCCs, with the exception for the NOX emission factor. The
NOX emission factors for the four SCCs were weighted by the residual oil capacity of each boiler type.
Any additional capacity added since 1981 was assumed to be subject to the New Source Performance
Standards. An emission factor of 45 Ib/thousand gallons was assumed for these boilers and was weighted
by the additional capacity. The yearly boiler capacities were obtained from Reference 7.
The emission factors for the combustion of distillate oil were calculated from the emission factors for
the SCCs listed in Table 3.3-1. The emission factors for all pollutants except PM-10 were obtained from
References 4a, 4b, and 4c. The PM-10 emission factors were obtained from Reference 5. Weighted
averages of the boiler emission factors for each pollutant, except SO2, were calculated using the
weighting factors given in Table 3.3-1. Weighted average nonboiler emission factors for each pollutant,
except SO2, were calculated in the same manner.
The SO2 emission factors for the four SCCs were multiplied by the fuel sulfur content for #2 and #4
heating oils obtained yearly from Reference 8. The #2 heating oil sulfur content was applied to the
emission factors for the SCCs 1-01-005-01 and 2-01-001-01. The #4 heating oil sulfur content was
applied to the SCC 1-01-005-04. No sulfur content was applied to the emission factor for reciprocating
engines. Emission factors for the two boiler SCCs were weighted according to the distribution of #2 and
#4 heating oils to electric utilities as reported in Reference 6. Emission factors for the nonboiler SCCs
were weighted in the same manner as described for the other pollutants.
The overall emission factors for the combustion of distillate oil were the weighted average of the
boiler and nonboiler emission factors for each pollutant. Weighting factors were dependent on the year
for which the emission factors were being determined. For the years 1970 through 1980, the boiler
emission factors were weighted 40 percent and the nonboiler emission factors were weighted 60 percent.
After 1980, weighting factors were 50 percent for both boiler and nonboiler emission factors. The
weighting factors used prior to 1970 are currently unavailable.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-28 Category: 01-02
-------
3.3.4 Control Efficiency
The PM-10 control efficiencies for the combustion of residual and distillate oil for the years 1975
through 1984 were equal to the 1988 PM-10 control efficiencies obtained from Reference 9. For the
years 1940 through 1974, no control efficiencies were used to estimate PM-10 emissions.
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, TSP, or VOC
emissions from the combustion of residual and distillate oil.
3.3.5 References
1. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
2. Petroleum Marketing Annual. DOE/EIA-0389(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
3. Electric Power Annual. DOE/EIA-0348(xx). Energy Information Administration, U.S. Department
of Energy, Washington, DC. Annual.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
(a) Volume I, Table 1.3-1
(b) Volume I, Table 3.1-2
(c) Volume I, Table 3.3-1
5. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
6. Cost and Quality of Fuels for Electric Utility Plants. DOE/EIA-0191(xx). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
7. Inventory of Power Plants in the United States I9xx. DOE/EIA-0095(xx). U.S. Department of
Energy, Energy Information Administration. Washington, DC. Annual.
8. Heating Oils. U.S. Department of Energy. Obtainable from the National Institute for Petroleum
and Energy Research, ITT Research Institute, P.O. Box 2128. Bartlesville, OK. Annual.
9. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends," Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-29 Category: 01-02
-------
Table 3.3-1. Emission Factor SCCs for Distillate
Oil Combustion by Electric Utility
Weighting
SCC Description Factors
1-01-005-01 Boiler-#2 oil 0.9
1-01-005-04 Boiler-#4 oil 0.1
2-01-001-01 Nonboiler-gas turbine 0.9
2-01-001-02 Nonboiler- reciprocating 0.1
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-30 Category: 01-02
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3.4 FUEL COMBUSTION ELECTRIC UTILITY - GAS: 01-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(01) FUEL COMBUSTION - (03) Gas Natural Gas
ELECTRIC UTILITY
3.4.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source category listed above. Emissions were estimated from an activity indicator,
emission factor, and control efficiency, where applicable. In order to utilize these values in the Trends
spreadsheets, the activity indicator was expressed in billion cubic feet and the emission factors were
expressed in metric pounds/million cubic feet. All control efficiencies were expressed as dimensionless
fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.4-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 34-1)
y TSP Emissions 1975
This calculation was used in place of estimating PM-10 emissions based on activity indicators, emission
factors, and control efficiencies.
3.4.2 Activity Indicator
The total annual natural gas consumption obtained from Reference 1 was the activity indicator for
this category.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-31 Category: 01-03
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3.4.3 Emission Factor
The emission factors for all pollutants, except NOX, were based on the emission factors for the five
boiler and nonboiler types listed by SCC in Table 3.4-1. These emission factors for all pollutants except
PM-10 were obtained from Reference 2a, 2b, and 2c. The PM-10 emission factors were obtained from
Reference 3. Weighted average of the boiler emission factors were calculated using weighting factors
obtained from Reference 4 or Reference 5. Weighted averages of the nonboiler emission factors were
calculated using the weighting factors presented in Table 3.4-1. The overall weighted emission factors
were calculated by weighting the boiler emission factors 94 percent and the nonboiler emission factors 6
percent.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the source included in this Tier II category.
The NOX emission factors were based on the emission factors for the two nonboiler types listed in
Table 3.4-1 and the following three boiler types listed in Table 3.4-2. The nonboiler emission factors
were obtained from Reference 2b and 2c and were weighted in the same manner as for the other
pollutants. The emission factors for the three boiler types are presented in Table 3.4-2. These emission
factors were weighted by the boiler capacity data which was based on 1976 data obtained from Reference
6. In order to update the capacity data to a year after 1976, the additional capacities of plants that came
on line each year between 1976 and the year under study were obtained from Reference 7. The
procedure for determining the boiler capacities for the years prior to 1976 is currently unavailable. All
new boilers added since 1983 were assumed to be subject to New Source Performance Standards and,
therefore the new boiler capacity was added to this category. The resulting boiler capacities were used as
weighting factors in the calculation of average NOX emission factors for boilers. The overall weighted
emission factors were calculated in the same manner as for the other pollutants.
3.4.4 Control Efficiency
The PM-10 control efficiencies for the combustion of natural gas for the years 1975 through 1984
were equal to the 1988 PM-10 control efficiency obtained from Reference 8. For the years 1940 through
1974, no control efficiencies were used to estimate the PM-10 emissions.
No control efficiencies were applied to the activity data to estimate the CO, NOX, SO2, TSP, or VOC
emissions from the combustion of natural gas.
3.4.5 References
1. Natural Gas Annual. DOE/EIA-0131(xx). Energy Information Administration, U.S. Department of
Energy, Washington, DC. Annual.
2. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
(a) Volume I, Table 1.4-1, Supplement A, October 1986.
(b) Volume I, Table 3.1-2, September 1985.
(c) Volume I, Table 3.2-1, September 1985.
National Air Pollutant Emission Trends 1940-1984 Methodology
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3. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
4. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
5. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
6. Inventory of Power Plants in the United States 19xx. DOE/EIA-0095(xx). U.S. Department of
Energy, Energy Information Administration. Washington, DC. Annual.
7. Energy Data System, FPC 67 form run to print boiler capacity sorted by boiler type. 1976.
8. Barnard, William R. and Patricia M. Carlson. "PM-10 emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
Table 3.4-1. Emission Factor SCCs for the Combustion of Natural Gas by Electric Utility
SCC Description Weighting
Factors
1-01-006-01 Utility/Large Industrial Boiler
1-01-006-02 Small Industrial Boiler
1-01-006-04 Tangentially-Fired Boiler
2-01-002-01 Nonboiler-gas turbine 0.9
2-01-002-02 Nonboiler- reciprocating engine 0.1
Table 3.4-2. NOX Emission Factors by Boiler Types for the Combustion of Natural Gas
by Electric Utility
Boiler Type Emission Factor (lb/106 cu. ft.)
Normal 550
Tangential 275
New Source Performance Standard 200
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3.5 FUEL COMBUSTION INDUSTRIAL - COAL: 02-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(02) FUEL COMBUSTION-
INDUSTRIAL
Tier II Category
(01) Coal
Tier II Subcategory
Anthracite
Bituminous, Subbituminous, and
Lignite Coal
3.5.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order the utilize these values in the
Trends spreadsheets, the activity indicator for bituminous, subbituminous, and lignite coal was expressed
in million short tons and the emission factors were expressed in metric pounds/short ton. The activity
indicator for anthracite coal was expressed in thousand short tons and the emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.5-1.
PM-10 Emissions = PM-10 Emissions
1975
TSP Emissions ear
TSP Emissions 1975
(Eq. 3.5-1)
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.5.2 Activity Indicator
The activity indicator for the combustion of anthracite coal was the distribution of anthracite coal
from Pennsylvania (i.e. District 24) obtained from Reference la under the category "Other Industrial".
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1940-1984 Methodology
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The activity indicator for bituminous, subbituminous, and lignite coal was based on total national
coal consumption obtained from Reference 2 under the category "Other Industrial." This value included
the coal consumption from coke plants which were not appropriate for this activity indicator. Therefore,
the coal consumption of cement plants and lime plants were subtracted from the total coal consumption.
Coal consumption by cement plants was obtained from Reference 3. Coal consumption by lime plants
was estimated by multiplying the lime production value obtained from Reference 4 by the conversion
factor: 0.1 tons coal/ton lime produced.
3.5.3 Emission Factors
The emission factors for the combustion of anthracite coal were the weighted averages of the
emission factors for three different firing configurations. For all pollutants except PM-10, the emission
factors for each firing configuration were obtained from Reference 5a; the PM-10 emission factors were
obtained from Reference 6. These emission factors were weighted by the 1980 quantity of anthracite coal
burned by industry in each firing configuration as reported in Reference 7. An ash content of 11 percent
was applied to selected PM-10 and TSP emission factors. The SO2 emission factors were multiplied by a
sulfur content value of 0.7 percent.
The emission factors for the combustion of bituminous, subbituminous, and lignite coal were the
weighted average of the emission factors for the different firing configurations obtained from Reference
5b and 5c, respectively. These emission factors were weighted by the 1980 quantity of bituminous,
subbituminous, and lignite coal burned by industry in each firing configuration as reported in Reference 7.
The ash content was assumed to be 13 percent for bituminous and subbituminous coal, and 11 percent for
lignite coal.
The SO2 emission factor was multiplied by the average sulfur content for all coal shipped to
industrial plants. The average sulfur content of coal was determined from the sulfur content by coal
producing districts obtained for the category "Other industrial uses and retail dealers" in Reference 8a.
This reference provided the sulfur content values reported in 1977 and it was assumed that these values
remained constant during the years 1940 through 1984. In order to obtain the average sulfur content for
a specific year, the sulfur content by district was weighted by the distribution of coal by district of origin
for the category "Other Industrial" obtained from Reference la or Reference 9.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the source included in this Tier II category.
3.5.4 Control Efficiency
The TSP control efficiency for the combustion of anthracite coal was derived from Reference 10 or
Reference 11 using Equation 3.5-2. When these values were unavailable, a control efficiency of 0.95 was
used.
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where: CE = control efficiency
UE = emissions before control
AE = emissions after control
The TSP control efficiency for the combustion of bituminous, subbituminous, and lignite coal was
calculated based on the uncontrolled and controlled emissions. In order to calculate the uncontrolled
TSP emissions, the operating rates for each type of boiler using bituminous, subbituminous, and lignite
coal (i.e., SCCs within the group 1-02-002-xx) were obtained from Reference 10 or Reference 11. These
rates were multiplied by the corresponding emission factors obtained from Reference 5 and an ash
content of 13 percent. The emissions were summed over all boiler types and converted to tons to obtain
the total uncontrolled TSP emissions. The actual emissions reported in Reference 10 or Reference 11
were summed over the same boiler types to obtain the total actual TSP emissions. The TSP control
efficiency was calculated from these values according to the equation given above.
The PM-10 control efficiencies for anthracite, bituminous, subbituminous, and lignite coal
combustion for the years 1975 through 1984 were based on the 1988 PM-10 control efficiency obtained
from Reference 12. During these years, any changes in the TSP control efficiencies from the 1985 TSP
control efficiency value were reflected in the PM-10 control efficiencies. For the years 1940 through
1974, no control efficiencies were use to estimate PM-10 emissions from the combustion of these fuels.
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, or VOC
emissions from the combustion of anthracite coal and of bituminous coal and lignite.
3.5.5 References:
1. Coal Distribution January-December 19xx. DOE/EIA-0125(xx/4Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
(a) Table entitled, "Domestic Distribution of U.S. Coal by Origin, Destination, and Consumer:
January-December 19xx".
2. Quarterly Coal Report: January - March. DOE/EIA-0121 (xx/1Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Quarterly.
3. Minerals Industry Surveys, Cement. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Monthly.
4. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
5. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
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a. Volume I, Table 1.2-1, Supplement B, September 1988.
b. Volume I, Table 1.1-1
c. Volume I, Table 1.7-1
6. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
7. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park,NC. February 9, 1980.
8. Coal Production. DOE/EIA-0118(xx). Energy Information Administration, U.S. Department of
Energy, Washington, DC. Annual.
(a) Table entitled, "Shipments of Bituminous Coal and Lignite by District, Consumer, Use,
Average Sulfur Content - 1977."
9. Minerals Yearbook, Coal. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
10. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
11. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
12. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.6 FUEL COMBUSTION INDUSTRIAL - OIL: 02-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(02) FUEL COMBUSTION - (02) Oil Residual
INDUSTRIAL Distillate
Process Heaters
3.6.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators for residual and distillate oil were expressed in million gallons and
emission factors were expressed in metric pounds/thousand gallons. For CO, NOX, PM-10, TSP, and SO2
emissions, activity indicators for oil-fired process heaters were expressed in thousand short tons and
emission factors were expressed in metric pounds/short ton. For VOC emissions, the activity indicator
for process heaters was expressed in million barrels and the emission factors was expressed in metric
pounds/thousand barrels. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.6-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 36-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.6.2 Activity Indicator
The activity indicator for residual oil combustion was based on the adjusted quantity of residual oil
sales for industrial and oil company use obtained from Reference 1 or 2. The total of three statistics were
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subtracted from this value to obtain the activity indicator. The first statistic was two-thirds of the
quantity of oil consumed by cement plants reported in Reference 3 converted to gallons. The second
statistic was the quantity of residual oil consumed by petroleum refineries reported in Reference 4a,
converted to gallons. The third statistic was the quantity of residual oil consumed by steel mills. This
value was calculated by multiplying the quantity of raw steel production obtained from Reference 5, by
0.00738 x 106 gal/103 ton steel. The conversion factor between the gallons of oil and the tons of steel
was updated in 1982 based on Reference 6.
The activity indicator for distillate oil combustion was based on the adjusted quantity of distillate oil
sales to industrial and oil companies obtained from Reference 1 or 2. The total of two statistics were
subtracted from this value to obtain the activity indicator for distillate oil. The first statistic was one-
thirds of the quantity of oil consumed by cement plants, expressed in gallons, reported in Reference 3.
The second statistic was the quantity of distillate oil consumed by petroleum refineries, expressed in
gallons, reported in Reference 4a.
The activity indicator for oil-fired process heaters was the total quantity of oil consumed at
petroleum refineries. This value was the sum of the distillate, residual and crude oil consumptions at
petroleum refineries as reported in Reference 4a.
3.6.3 Emission Factor
The emission factors for each pollutant for the combustion of residual oil (SCC 1-02-004-01) were
obtained from Reference 7 under the classification industrial boilers - residual oil for all pollutants except
PM-10. The PM-10 emission factors were obtained from Reference 8. The SO2, PM-10, and TSP
emission factors were multiplied by the sulfur content obtained for No. 6 fuel oil from Reference 9.
The emission factors for each pollutant for the combustion of distillate oil were the weighted average
of the emission factors for two SCCs (1-02-005-01 and 1-02-005-04). These emission factors were
obtained from Reference 7 for all pollutants except PM-10. The PM-10 emission factors were obtained
from Reference 8. Weighting factors were obtained from Reference 10.
The SO2 emission factors were multiplied by a weighted average sulfur content. Sulfur content
values for No. 1, No. 2, and No. 4 oils were obtained from Reference 9. These values were weighted by
the corresponding distribution of fuel oil sales to the industrial sector as reported in Reference 1 or 2.
For oil-fired process heaters, the emission factors for all pollutants, except PM-10, were obtained
from Reference 7 under the classification for industrial boiler - residual oil. The PM-10 emission factor
was obtained from Reference 8.
The TSP emission factor, as specified in Reference 7, was a function of sulfur content (10(S)
+ 3 lb/1,000 gal). The sulfur content was obtained for SCC 30600103 from Reference 10. The SO2 and
PM-10 emission factors were multiplied by the sulfur content. The VOC emission factor was converted
to a reactive basis using the VOC species profile SDM 101004 from Reference 11.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
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3.6.4 Control Efficiency
The PM-10 control efficiencies for all emission sources included in this Tier II category for the years
1975 through 1984 were equal to the 1988 PM-10 control efficiencies obtained from Reference 12. For
the years 1940 through 1974, no control efficiencies were used to estimate the PM-10 emissions.
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, TSP, or VOC
emissions from the source included in this Tier II category.
3.6.5 References
1. Petroleum Marketing Monthly. DOE/EIA-0380(xx/01). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
2. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
3. Minerals Industry Surveys, Cement. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Monthly.
4. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Fuel Consumed at Refineries by PAD District."
5. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC.
a. Table containing information on Metals and Manufacturers
6. Census of Manufactures (Fuels and Electric Energy Consumed). Bureau of the Census, U.S.
Department of Commerce, Washington, DC. 1982.
7. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
Volume I, Table 1.3-1
8. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
9. Heating Oils. U.S. Department of Energy. Obtainable from the National Institute for Petroleum
and Energy Research, ITT Research Institute, P.O. Box 2128. Bartlesville, OK. Annual.
10. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park,NC. February 9, 1980.
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11. Volatile Organic Compound (VOC) Species Data Manual. EPA-450/4-80-015. U.S.
Environmental Protection Agency, Research Triangle Park, NC. July 1980.
12. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.7 FUEL COMBUSTION INDUSTRIAL - GAS: 02-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(02) FUEL COMBUSTION - (03) Gas Natural Gas - boilers and gas
INDUSTRIAL pipelines and plants
Coke - oven gas
Process Heaters
3.7.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators for natural and coke-oven gas were expressed in billion cubic feet
and emission factors were expressed in metric pounds/million cubic feet. For CO, NOX, PM-10, TSP, and
SO2 emissions, the activity indicator for gas-fired process heaters was expressed in thousand short tons
and the emission factors were expressed in metric pounds/short ton. For VOC emissions, the activity
indicator for gas-fired process heaters was expressed in million barrels and the emission factor was
expressed in metric pounds/thousand barrels. All control efficiencies were expressed as dimensionless
fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.7-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1915 x _____2_ (Eq. 3;M)
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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3.7.2 Activity Indicator
The activity indicator for the combustion of natural gas in industrial boilers was based on the total
industrial consumption of natural gas obtained from Reference 1. From this value was subtracted the sum
of the total natural gas consumption by cement plants, petroleum refineries, iron and steel industries, and
glass manufacturers. Total natural gas consumption by cement plants obtained from Reference 2. Total
natural gas consumption by petroleum refineries was obtained from Reference 3. The total natural gas
consumption by iron and steel industries was calculated by multiplying the raw steel production obtained
from Reference 4 by 4.25 x 106 cu. ft. natural gas/1000 tons steel. The conversion factor relating steel
production to natural gas consumption was updated in 1982 based on data from Reference 5. Total
natural gas consumption by glass manufacturers was determined from the total glass production. This
total was calculated by summing the total production of flat glass from Reference 6 and the net packed
weight of glass containers from Reference 7 and multiplying the resulting sum by 1.1 to account for
miscellaneous glass products. The total glass production was multiplied by 10.8 x 106 cu. ft. natural
gas/1000 tons glass produced to obtain the total natural gas consumption. The conversion factor relating
glass production to natural gas consumption was updated in 1982 based on data from Reference 5.
The activity indicator for the combustion of natural gas by gas pipelines and plants was the total
natural gas consumption for lease and plant fuel plus pipeline fuel obtained from Reference 1.
The activity indicator for coke-oven gas combustion represented the amount of coke-oven gas
consumed outside of the iron and steel industry which was assumed to be 18.8 percent of the total coke-
oven gas produced. The total coke-oven gas production, in cubic feet, as reported in Reference 8, was
multiplied by 0.188 to obtain the activity indicator for this subcategory.
The activity indicator for gas-fired process heaters was the total of natural gas and still (process) gas
consumed at petroleum refineries obtained from Reference 3.
3.7.3 Emission Factor
The emission factors for all pollutants except PM-10 for the combustion of natural gas in industrial
boilers (SCC 1-02-006-02) were obtained from Reference 9a. The PM-10 emission factor was obtained
from Reference 10.
The emission factors for the combustion of natural gas by gas pipeline and plants were the weighted
averages of the emission factors for SCCs 2-02-002-01 and 2-02-002-02. Reference 9b was the source
of the emission factors for all pollutants except PM-10; Reference 10 was the source for the PM-10
emission factors. The weighting factors were based on data from Reference 11.
The emission factors for all pollutants for the combustion of coke-oven gas were obtained from
Reference 10. The SO2 emission factor was multiplied by the constant sulfur content value of 1.605
percent.
The CO and NOX emission factors for all types of gas-fired process heaters were obtained from
Reference 9c. The PM-10 emission factor was obtained from Reference 10, the PM-10 and TSP
emission factors were obtained from Reference 9a, and the VOC emission factor from Reference 9d. In
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each case, the emission factors were listed as the uncontrolled emission factors for small industrial boilers.
The VOC emission factor was converted to a reactive basis using the VOC species profile SDM 101007
from Reference 12.
The SO2 emission factor was the weighted average of the emission factors for natural gas obtained
from Reference 9c and for refinery gas (given as 356.25 lb/106 cu.ft.). The weighting factors were the
natural gas and refinery gas consumption obtained from Reference 3.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.7.4 Control Efficiency
The PM-10 control efficiencies for all emission sources included in this Tier II category for the years
1975 through 1984 were equal to the 1988 PM-10 control efficiencies obtained from Reference 13. For
the years 1940 through 1974, no control efficiencies were used to estimate PM-10 emissions.
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, TSP, or VOC
emissions from these sources.
3.7.5 References
1. Natural Gas Annual. DOE/EIA-0131(xx). Energy Information Administration, U.S. Department of
Energy, Washington, DC. Annual.
2. Minerals Industry Surveys, Cement. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Monthly.
3. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
4. Minerals Industry Surveys, Iron Ore. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Monthly.
5. Census of Manufactures (Fuels and Electric Energy Consumed). Bureau of the Census, U.S.
Department of Commerce, Washington, DC. 1982.
6. Current Industrial Reports, Glass Containers. Bureau of the Census, U.S. Department of
Commerce, Washington, DC. Annual.
7. Current Industrial Reports, Flat Glass. Bureau of the Census, U.S. Department of Commerce,
Washington, DC. Annual.
8. Quarterly Coal Report: January - March. DOE/EIA-0121(xx/lQ). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Quarterly.
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9. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
(a) Volume I, Table 1.4-1
(b) Volume I, Table 3.2-1
(c) Volume I, Table 1.4-2
(d) Volume I, Table 1.4-3
10. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
11. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park, NC. February 9, 1980.
12. U.S. Environmental Protection Agency. Volatile Organic Compound (VOC) Species Data Manual.
EPA-450/4-80-015. Research Triangle Park, NC. July 1980.
13. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.8 FUEL COMBUSTION INDUSTRIAL - OTHER: 02-04
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(02) FUEL COMBUSTION -
INDUSTRIAL
Tier II Category
(04) Other External
Combustion
Tier II Subcategory
Coke, Bagasse, Kerosene, Liquid
Petroleum Gas, and Wood
3.8.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators for coke, bagasse, and wood were expressed in thousand short
tons and emission factors were expressed in metric pounds/short ton. For kerosene and LPG, activity
indicators were expressed in million barrels and emission factors was expressed in metric
pounds/thousand barrels. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.8-1.
PM-10 Emissions year = PM-10 Emissions 1975 x
TSP Emissions
(Eq. 3.8-1)
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.8.2 Activity Indicator
The activity indicator for the combustion of coke was the consumption of coke outside the iron and
steel industry. This quantity was calculated by summing the total coke production from coal and the total
petroleum coke receipts. The total quantity of petroleum coke consumed or received by power plants
was obtained from Reference 1 or Reference 2.
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In order to obtain the total coke produced from coal, the following data were obtained from
Reference 3: (1) total breeze production at coke plants and (2) coke sales to "other industrial plants."
Because it was assumed that 24 percent of the total breeze production was sold for use as boiler fuel, the
total breeze production at coke plants was multiplied 0.24 to obtain the total breeze consumed as fuel. If
data for foundries and other industrial plants were combined, it was assumed that 49 percent of the total
was for other industrial plants. Total coke production from coal was the sum of the total breeze
production used for fuel and the total coke sales to other industrial plants. Alternatively, if data from
Reference 3 were not available, it was assumed that 5.75 percent of total coke production obtained from
Reference 3 represented the coke consumption outside the iron and steel industry.
The activity indicator for the combustion of bagasse was the consumption of bagasse obtained from
Reference 4.
The activity indicator for the combustion of kerosene was the quantity of kerosene sales. This value
was obtained by summing the sales figures reported for the industrial and the all other end use categories
as reported in Reference 5 or Reference 6.
The activity indicator for the combustion of liquid petroleum gas was the LPG supplied for industrial
use. This quantity was derived from the 1982 consumption figures (5,397 x 106 gal) using the ratio
between the quantity of products supplied in 1982 (1,499 x 103 bbl/day) and in the year under study. The
quantity of products supplied for a given year and for 1982 was obtained from Reference 7. The
Equation 3.8-2 summarizes the calculation of the LPG supplied for industrial use:
Products „ ,. , .
~^ — T ~Df~^ N/ Supplied , I
Industrial, i ~ LF(j 'industrial, 1982 X , - (Eq. 3.8-2)
Supplied, 1982
where: i = year under study
The activity indicator for the industrial combustion of wood was based on the consumption of wood
for industrial combustion obtained from Reference 8. It was assume that 15 percent of the heating value
was lost to moisture on a typical basis. Therefore, the reported consumption figure was multiplied by
0.85 to obtain the activity indicator.
3.8.3 Emission Factor
The emission factors for industrial coke combustion were the weighted averages of the emission
factors for petroleum coke and coal coke. These emission factors for which the references are currently
unavailable are presented in Table 3.8-1. Weighting factors were the total petroleum coke receipts and
the total coke produced from coal as determined for the activity indicator for the coke category. A sulfur
content value of 3.25 percent was used for the petroleum coke SO2 emission factor.
The emission factors for bagasse combustion (SCC 1-02-001-01) were obtained from Reference 9a
for all pollutants except PM-10. The PM-10 emission factor was obtained from Reference 10. The TSP
control efficiency was applied directly to the TSP emission factor, resulting in the controlled emission
factor. The TSP control efficiency was obtained from Reference 10.
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The emission factors used for kerosene combustion (SCC 1-02-005-01) were those for the
combustion of distillate oil in industrial boilers obtained from Reference 9b for all pollutants except
PM-10. The PM-10 emission factor was obtained from Reference 10. The SO2 emission factors was
multiplied by a sulfur content value of 0.075 percent.
The emission factors for all pollutants for LPG combustion (SCC 1-02-010-01) were obtained from
Reference 9c. The PM-10 emission factor was obtained from Reference 10. The SO2 emission factor
was multiplied by a sulfur content value of 0.0013 percent.
For industrial wood combustion the emission factors were the weighted averages of the emission
factors for three SCCs (1-02-009-01, 1-02-009-02, and 1-02-009-03). These emission factors were
obtained from Reference 9d for all pollutants except PM-10 which was obtained from Reference 10. For
the years 1975 through 1984, the weighting factors were derived from throughput data obtained from
Reference 11. Prior to 1975, the procedure for determining the weighting factors is currently unavailable.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.8.4 Control Efficiency
The PM-10 control efficiencies for all emission sources included in this Tier II category for the years
1975 through 1984 were equal to the 1988 PM-10 control efficiencies obtained from Reference 12. For
the years 1940 through 1974, no control efficiencies were used to estimate PM-10 emissions.
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, TSP, or VOC
emissions from the source included in this Tier II category.
3.8.5 References
1. Cost and Quality of Fuels for Electric Utility Plants. DOE/EIA-0191(xx). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
2. Electric Power Annual. DOE/EIA-0348(xx). Energy Information Administration, U.S. Department
of Energy, Washington, DC. Annual.
3. Quarterly Coal Report: January - March. DOE/EIA-0121 (xx/1Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Quarterly.
4. Standard Computer Retrievals, NE213 report (duel use summary), from the National Emissions
Data System (NEDS). Unpublished computer reports. National Air Data Branch, Office of Air
Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle Park,
NC. Annual.
5. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
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6. Petroleum Marketing Monthly. DOE/EIA-0380(xx/01). Energy Information Administration, U.S.
Department of Energy, Washington, DC. January issue.
7. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
8. Estimates of U.S. Biofuels Consumption. SR/CNEAF/91-02. U.S. Department of Energy,
Washington, DC. Annual.
9. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
(a) Volume I, Table 1.8-1
(b) Volume I, Table 1.3-1
(c) Volume I, Table 1.5-1
(d) Volume I, Table 1.6-1, Supplement A, October 1986
10. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
11. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
12. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
Table 3.8-1. Emission Factors for Miscellaneous Fuels - Industrial (coke)
Emission Factors (Ib/ton)
Coke Type
TSP SO,
NO,
VOC CO
PM-10
Petroleum Coke 1.5 38.8* 20.9 0.64 0.54 1.2
Coal Coke 4.6 30.3 14.0 0.64 0.54 3.6
* Multiply by sulfur content
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3.9 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL COAL: 03-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(03) FUEL COMBUSTION - (01) Commercial/Institutional Anthracite Coal
OTHER Coal Bituminous, Subbituminous, and
Lignite Coal
3.9.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, the activity indicator for bituminous, subbituminous, and lignite coal was expressed
in million short tons and the emission factors were expressed in metric pounds/short ton. The activity
indicator for anthracite coal was expressed in thousand short tons and the emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.9-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: — (Eq. 3.9-1)
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.9.2 Activity Indicator
The activity indicators for the combustion of these two fuels were the consumption of the specific
coal type by commercial and institutional users. Determination of these activity indicators required the
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activity indicators for both anthracite, bituminous, subbituminous, and lignite residential coal combustion.
The latter activity indicators are described both here and in section 3.13.2.
The commercial/institutional consumption of anthracite coal was obtained by subtracting residential
anthracite consumption from residential and commercial/institutional anthracite consumption. Residential
and commercial/institutional consumption of anthracite coal was obtained from Reference la for District
24 only.
Anthracite Coalcll = Anthracite CoalR and CII - Anthracite CoalR (Eq. 3.9-2)
where: C/I = commercial/institutional consumption
R = residential consumption
Residential consumption of anthracite coal was determined by extrapolating the consumption of the
previous year based on the change in the number of dwelling units in the Northeastern United States
having coal as the main fuel for space heating. Data concerning the number of dwelling units was
obtained from Reference 2. The calculation of the residential anthracite coal consumption is summarized
in Equation 3.9-3.
Dwelling Units.
Anthracite CoaL . = Anthracite Coal,, . , x (En 3 9-3)
1 Dwelling Unitsi_l \ ^- • >
where: R = residential consumption
i = year under study
Commercial/institutional consumption of bituminous, subbituminous, and lignite coal was obtained
by subtracting residential bituminous, subbituminous, and lignite consumption from residential and
commercial/institutional bituminous, subbituminous, and lignite consumption. Residential and
commercial/institutional consumption of bituminous coal was calculated by subtracting the residential and
commercial/institutional consumption of anthracite coal from residential and commercial/institutional
consumption of all types of coal. These two consumption values were obtained from Reference la and
excluded coal from District 24 which represents anthracite coal consumption. This calculation is
summarized in Equation 3.9-4.
Bituminous CoalCII = (All CoalR md C/I - Anthracite CoalR md C/I) - Bituminous CoalR (Eq 3 9-4)
where: C/I = commercial/institutional consumption
R = residential consumption
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Residential consumption of bituminous, subbituminous, and lignite coal was determined by
estimating the quantity of all coal consumed by all dwelling units using coal as the main fuel and
subtracting from this value the residential consumption of anthracite coal calculated above. The quantity
of all coal consumed was calculated using the number of dwelling units using coal as the main fuel for
space heating obtained from Reference 2 and a factor estimating the average annual consumption of coal
per dwelling unit. This calculation is summarized in Equation 3.9-5.
Bituminous CoalR = (Dwelling Units x 6.73 tons burned/dwelling/year) - Anthracite CoalR (Eq. 3.9-5)
3.9.3 Emission Factors
The emission factors for anthracite coal combustion were the weighted average of the emission
factors for three different firing configurations. The emission factors for each firing configuration were
obtained from Reference 3a for all pollutants except PM-10. The PM-10 emission factors were obtained
from Reference 4. These CO, SO2, and VOC emission factors were weighted by the 1980 quantity of
anthracite coal burned by industry in each firing configuration as reported in Reference 5. The procedure
for determining the weighting factors for the NOX, PM-10 and TSP emission factors is currently
unavailable, although it is known that the same factors were applied for the years 1940 through 1984. An
ash content of 11 percent was applied to selected PM-10 and TSP emission factors. The SO2 emission
factors were multiplied by a sulfur content value of 0.7 percent.
The emission factors for the combustion of bituminous, subbituminous, and lignite coal were the
weighted average of the emission factors for different firing configurations. For all pollutants except
PM-10, these emission factors were obtained from Reference 3b and 3c. The PM-10 emission factors
were obtained from Reference 4. These emission factors were weighted by the 1980 quantity of
bituminous, subbituminous, and lignite coal burned by industry in each firing configuration as reported in
Reference 5. The ash content was assumed to be 13 percent for bituminous coal and 11 percent for
lignite.
The SO2 emission factor was multiplied by the average sulfur content for all coal shipped to
industrial plants. The average sulfur content of coal was determined from the sulfur content by coal
producing districts obtained for the category "All other uses" in Reference 6a. This reference provided
the sulfur content values reported in 1977 and it was assumed that these values remained constant during
the years 1940 through 1984. In order to obtain the average sulfur content for a specific year, the sulfur
content by district was weighted by the distribution of coal by district of origin for the category
"Residential and Commercial" obtained from Reference la or Reference 7.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
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3.9.4 Control Efficiency
The TSP control efficiency for the combustion of anthracite coal was obtained from Reference 8 or
Reference 9. When this value was unavailable, a control efficiency of 33 percent was used.
For bituminous, subbituminous, and lignite coal, the TSP control efficiency was calculated based on
the uncontrolled and controlled emissions. In order to calculate the uncontrolled TSP emissions, the
operating rates for each type of boiler using bituminous and subbituminous coal and lignite (i.e. SCCs
within the group 1-02-002-xx) were obtained from Reference 8 or Reference 9. These rates were
multiplied by the corresponding emission factors obtained from Reference 3a and an ash content of 13
percent. The emissions were summed over all boiler types and converted to tons to obtain the total
uncontrolled TSP emissions. The actual emissions reported in Reference 8 or Reference 9 were summed
over the same boiler types to obtain the total actual TSP emissions. The TSP control efficiency was
calculated from these values according to Equation 3.9-6.
CE =
UE
(UE-AE]
(Eq. 3.9-6)
where: CE = control efficiency
UE = uncontrolled emissions
AE = controlled emissions
The PM-10 control efficiencies for anthracite coal and bituminous, subbituminous, and lignite coal
combustion for the years 1975 through 1984 were based on the 1988 PM-10 control efficiencies obtained
from Reference 10. During these years, any changes in the TSP control efficiencies from the 1985 TSP
control efficiency values were reflected in the PM-10 control efficiencies. For the years 1940 through
1974, no control efficiencies were use to estimate PM-10 emissions.
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, or VOC
emissions from the combustion of anthracite coal and bituminous coal and lignite.
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3.9.5 References
1. Coal Distribution January-December 19xx. DOE/EIA-0125(xx/4Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
(a) table entitled "Domestic Distribution of U.S. Coal to the Residential and Commercial Sector by
Origin."
2. American Housing Survey, Current Housing Reports, Series H-l50-83. Bureau of the Census, U.S.
Department of Commerce, Washington DC. Biennial.
3. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
(a) Volume I, Table 1.2-1, Supplement B, September 1988.
(b) Volume I, Table 1.1-2
(c) Volume I, Table 1.7-1
4. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
5. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park,NC. February 9, 1980.
6. Coal Production. DOE/EIA-0118(xx). Energy Information Administration, U.S. Department of
Energy, Washington, DC. Annual.
(a) table entitled "Shipments of bituminous coal and lignite by district, consumer, use, and average
sulfur content - 1977."
7. Minerals Yearbook, Coal. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
8. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
9. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
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10. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
National Air Pollutant Emission Trends 1940-1984 Methodology
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3.10 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL OIL: 03-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(03) FUEL COMBUSTION - (02) Commercial/Institutional Residual
OTHER Oil Distillate
3.10.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in million gallons and emission factors were
expressed in metric pounds/thousand gallons. All control efficiencies were expressed as dimensionless
fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.10-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 3 10-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.10.2 Activity Indicator
The activity indicator for residual oil combustion was the "adjusted" total quantity of residual oil
sales for commercial and military use obtained from Reference 1 or Reference 2.
The activity indicator for distillate oil combustion was the "adjusted" total quantity of distillate oil
sales for commercial and military use (not including military diesel fuel) obtained from Reference 1 or
Reference 2.
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3.10.3 Emission Factor
The emission factors for the combustion of residual oil were the weighted average of the emission
factors for the combustion of Grade 6 and Grade 5 fuel oils (SCCs 1-03-004-01 and 1-03-004-04). For
all pollutants except PM-10, these emission factors were obtained from Reference 3a. The PM-10
emission factors were obtained from Reference 4. The TSP, SO2, and PM-10 emission factors for Grade
6 fuel oil and the SO2 emission factor for Grade 5 fuel oil were multiplied by the average sulfur content.
The weighted average emission factors were determined using the relative consumption of Grade 5 and
Grade 6 fuel oils obtained from Reference 5 or Reference 6.
The average sulfur content for residual oil was calculated from sulfur content values obtained from
Reference 7 for No. 5 light, No. 5 heavy and No. 6 oils. The sulfur content values for the two No. 5 oils
were averaged. Weighting factors for the averaged No. 5 oils and the No. 6 oil were 0.13 and 0.87,
respectively. Equation 3.10-2 summarizes this calculation.
5 6 x °'87) (Eq- 3-10-2)
where: S = sulfur content
The emission factors for distillate oil combustion were the weighted averages of the emission factors
for the SCCs 1-03-005-01 and 1-03-005-04. The emission factors were obtained from Reference 3b for
all pollutants except PM-10. The PM-10 emission factors were obtained from Reference 4. The SO2
emission factors for both SCCs were multiplied by a weighted average sulfur content. Sulfur content
values for No. 1, No. 2, and No. 4 oils were obtained from Reference 7. These values were weighted by
the corresponding commercial deliveries of each oil type reported in Reference 1 or Reference 2 to obtain
the weighted average sulfur content. To determine the weighted average emission factors, throughput
values for the corresponding SCCs obtained from Reference 5 or Reference 6 were used as weighting
factors.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.10.4 Control Efficiency
The PM-10 control efficiencies for all emission sources included in this Tier II category for the years
1975 through 1984 were equal to the 1988 PM-10 control efficiencies obtained from Reference 7. For
the years 1940 through 1974, no control efficiencies were used to estimate PM-10 emissions.
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, TSP, or VOC
emissions from the source included in this Tier II category.
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3.10.5 References
1. Petroleum Marketing Monthly. DOE/EIA-0380(xx/01). Energy Information Administration, U.S.
Department of Energy, Washington, DC. January issue.
2. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
3. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 1.3-1
b. Volume I, Table 1.3-1
4. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
5. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
6. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
7. Heating Oils. U.S. Department of Energy. Obtainable from the National Institute for Petroleum
and Energy Research, ITT Research Institute, P.O. Box 2128, Bartlesville, OK. Annual.
8. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.11 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL GAS: 03-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(03) FUEL COMBUSTION - (03) Commercial/Institutional Natural Gas
OTHER Gas
3.11.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the
emissions from the source category listed above. Emissions were estimated from an activity indicator,
emission factor, and control efficiency, where applicable. In order to utilize these values in the Trends
spreadsheets, the activity indicator was expressed in billion cubic feet and the emission factors were
expressed in metric pounds/million cubic feet. All control efficiencies were expressed as dimensionless
fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to the following equation:
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 3 11-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.11.2 Activity Indicator
The activity indicator for natural gas combustion was the total natural gas consumption for
commercial uses as reported in Reference 1.
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3.11.3 Emission Factor
The emission factors for all pollutants except PM-10 for the combustion of natural gas (SCC 1-03-
006-03) were obtained from Reference 2a. The PM-10 emission factor was obtained from Reference 3.
3.11.4 Control Efficiency
The PM-10 control efficiencies for the years 1975 through 1984 were equal to the 1988 PM-10
control efficiency obtained from Reference 4. For the years 1940 through 1974, no control efficiencies
were used to estimate PM-10 emissions from natural gas combustion.
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, TSP, or VOC
emissions from this source.
3.11.5 References
1. Natural Gas Annual. DOE/EIA-0131(xx). Energy Information Administration, U.S. Department of
Energy, Washington, DC. Annual.
2. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 1.4-1
3. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
4. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.12 FUEL COMBUSTION OTHER - RESIDENTIAL WOOD: 03-05
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category
(03) FUEL COMBUSTION - (05) Residential Wood
OTHER
3.12.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the
emissions from the source category listed above. Emissions were estimated from an activity indicator and
emission factor. In order to utilize these values in the Trends spreadsheets, the activity indicator was
expressed in thousand short tons and the emission factors were expressed in metric pounds/short ton.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984 for all pollutants except TSP, for which the procedures were
used for the years through 1992, and PM-10, for which the procedures were used for the years 1975
through 1984. For some source categories, the PM-10 emissions exceeded the TSP emissions as
calculated by the procedures presented in this section. Because this represents a physical impossibility, a
more realistic estimate of the PM-10 emissions was assumed to be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to the following equation:
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.12-1)
This calculation was used in place of estimating the emissions based on activity indicators and emission
factors.
3.12.2 Activity Indicator
The activity indicator for the residential combustion of wood was based on the consumption of
wood for residential combustion as reported in Reference 1. It was assumed that 15 percent of the
heating value is lost to moisture on a typical basis. Therefore, the reported consumption figure was
multiplied by 0.85 to obtain the activity indicator. Alternatively, the procedure used to determine the
emission factors for this category was used to estimate residential wood consumption as described below
in section 3.12.3. The wood consumption calculated by this method was normalized to the total wood
consumption reported by the Department of Energy (no reference for this value is currently available).
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3.12.3 Emission Factor
The emission factors for the residential burning of wood were the weighted average of the emission
factors for wood burned in wood stoves and in fireplaces. These emission factors for all pollutants
except PM-10 and TSP obtained from References 2a and 2b for wood stoves and fireplaces, respectively.
The PM-10 and TSP emission factors were obtained from Table 3.1-3 of this report. Weighting factors
were based on the relative quantity of wood burned in wood stoves and in fireplaces. Weighting factors
of 0.755 for wood stoves and 0.245 for fireplaces were used when the factors were not determined as
described below.
The quantity of wood consumed in fireplaces was determined from the number of fireplaces obtained
from Reference 3a and the assumption that on average one-half cord of wood is burned in each fireplace
per year. The calculation, including the necessary conversion factors is shown in Equation 3.12-2.
„, , „ ,r Q.5cord 4m3 0.028317//13 351b I ton
Wood Consumption,- , = Nr , x - x - x - J. — x - x — _ — ma 3 19-9)
f fireplaces fireplaces , ^ 2,000^ qJ
The quantity of wood burned in wood stoves was determined from the number of wood stoves and
the stove heat input rates. The number of wood stoves being used in a given year was calculated as the
number of stoves being used in the previous year, the number of new shipments of stoves, and the
number of obsolete stoves as summarized in Equation 3.12-3.
^Wood Stoves, i ~ ^ Wood Stoves, i-l + ^ New Wood Stoves, i ~ ^ New Wood Stoves, i-6 (Eq. 3.12-3)
where i = year under study
The total shipments and imports of stoves was obtained from Reference 4. It was assumed that for the
years 1981 through 1984, the number of shipments remained constant at the 1981 value. The number of
obsolete stoves was assumed to be the number of stove shipments from the sixth previous year.
The total number of wood stoves in use was divided into two categories: primary and secondary.
The number of primary stoves was extrapolated from the previous year's number based on the relative
change in the number of dwelling units using wood as the primary house heating fuel obtained from
Reference 3. The number of secondary stoves was calculated as the difference between the total number
of wood stoves and the number of primary stoves.
The stove heat input rate for each stove type was used to calculate the total energy consumed by
each stove type. The 1984 stove heat input rates for primary and secondary stoves were 1 12,453 x 106
Btu and 42.37 x 106 Btu, respectively. No reference is currently available for this value and it is not
known at this time if year-specific heat input rates were used for the year prior to 1984. The total energy
consumed by the primary and secondary wood stoves were summed and converted to the quantity of
wood consumed using the factor 17.2 x 106 Btu/ton.
The total quantity of wood consumed by residential combustion was calculated as the sum of the
quantity of wood consumed in fireplaces and in wood stoves. The relative quantities of wood consumed
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by fireplaces and wood stoves were calculated and used as the weighting factors for determining the
emission factors for this source category.
3.12.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate the emissions from the residential
combustion of wood.
3.12.5 References
1. Estimates of U.S. Biofuels Consumption. SR/CNEAF/91-02. Energy Information Administration,
U.S. Department of Energy, Washington, DC. Annual.
2. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
(a) Volume I, Table 1.10-1, Supplement D, September 1991, Supplement C, September 1990, or
Supplement B, September 1988.
(b) Volume I, Table 1.9-1, Supplement D, September 1991
3. American Housing Survey, Current Housing Reports, Series H-l50-83. Bureau of the Census, U.S.
Department of Commerce, Washington DC. Biennial.
(a) Table 2-4, Selected Equipment and Plumbing - Occupied Units
4. Estimates of U.S. Wood Energy Consumption from 1949 to 1981. DOE/EIA-0341. Energy
Information Administration, U.S. Department of Energy, Washington, DC. August 1982.
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3.13 FUEL COMBUSTION OTHER - RESIDENTIAL OTHER: 03-06
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(03) FUEL COMBUSTION - (06) Residential Other Anthracite Coal
OTHER Bituminous, Subbituminous, and
Lignite Coal
Residual Oil
Distillate Oil
Natural Gas
Liquid Petroleum Gas
Kerosene
3.13.1 Technical Approach:
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, the activity indicator for bituminous, subbituminous, and lignite coal was expressed
in million short tons and the emission factors were expressed in metric pounds/short ton. The activity
indicator for anthracite coal was expressed in thousand short tons and the emission factors were
expressed in metric pounds/short ton. For residual and distillate oil, kerosene, and LPG, activity
indicators were expressed in million gallons and emission factors were expressed in metric
pounds/thousand gallons. The activity indicator for natural gas was expressed in billion cubic feet and the
emission factors were expressed in metric pounds/million cubic feet. All control efficiencies were
expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.13-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.13-1)
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This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.13.2 Activity Indicator:
The activity indicator for anthracite coal combustion was the residential consumption of anthracite
coal. This value was determined by extrapolating residential consumption of anthracite coal for the
previous year based on the change in the number of dwelling units in the Northeastern United States
having coal as the main fuel for space heating. Data concerning the number of dwelling units was
obtained from Reference 1. The calculation of the residential anthracite coal consumption is summarized
in Equation 3.13-2.
Dwelling Units.
Anthracite CoaL . = Anthracite CoaL . , x (Eq 3 13-2)
Dwelling Units._j
where: R = residential consumption
i = year under study
The activity indicator for bituminous, subbituminous, and lignite coal combustion was the residential
consumption of bituminous, subbituminous, and lignite coal. This value was determined by estimating the
quantity of all coal consumed by all dwelling units using coal as the main fuel and subtracting from this
value the residential consumption of anthracite coal calculated above. The quantity of all coal consumed
was calculated using the number of dwelling units using coal as the main fuel for space heating obtained
from Reference 1 and a factor estimating the average annual consumption of coal per dwelling unit. This
calculation is summarized in Equation 3.13-3.
Bituminous Coal Ri = (Dwelling Unitsi x 6.73 tons burned/dwelling /year) - Anthracite Coal Ri CEq. 3.13-3)
where: R = residential consumption
i = year under study
The activity indicator for the residential combustion of residual oil was assumed to be zero.
The activity indicator for distillate oil combustion was the sum of the "adjusted" sales (or deliveries)
for residential use of distillate oil and for farm use of other distillates as reported in Reference 2 or
Reference 3.
The activity indicator for natural gas combustion was the total natural gas consumption for
residential use obtained from Reference 4.
The activity indicator for kerosene combustion was the quantity of kerosene sales. This value was
obtained by summing sales figures reported for the residential, commercial, and farm use categories as
reported in Reference 2 or Reference 3.
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The activity indicator for LPG combustion was based on the 1982 total residential sales of LPG
(4,047 x 106 gal). This value was extrapolated to the year under study based on the relative change in the
LPG products supplied from the year 1982 (1499 x 103 bbl/day) to the year under study. Quantities of
LPG products supplied for the specific years were obtained from Reference 5. Equation 3.13-4
summarizes this calculation.
Products SuppliedLpG .
Residential Sales,pc . = Residential Sales,pc ]982 x '•— (Eq 3 13-4)
Products SuppliedLpG 1982
where: i = year under study
3.13.3 Emission Factors:
The emission factors for residential anthracite coal combustion (SCC 10300103, hand-fired units)
were obtained from Reference 6a for all pollutants except PM-10. The PM-10 emission factor was
obtained from Reference 7. The PM-10 and TSP factors were multiplied by an ash content of 11 percent.
The SO2 factor was multiplied by a sulfur content value of 0.7 percent.
The emission factors for all pollutants except PM-10 for the combustion of bituminous coal and
lignite (SCC 10300103, hand-fired units) were obtained from Reference 6b. The PM-10 emission factor
was obtained from Reference 7.
The SO2 emission factor was multiplied by the average sulfur content for all coal used by commercial
users. The average sulfur content of coal was determined from the sulfur content by coal producing
districts obtained for the category "All other uses" in Reference 8a. This reference provided the sulfur
content values reported in 1977 and it was assumed that these values remained constant during the years
1940 through 1984. In order to obtain the average sulfur content for a specific year, the sulfur content by
district was weighted by the distribution of coal by district of origin for the category "Commercial and
Residential" obtained from Reference 9a or Reference 10.
No emission factors were required for residential residual oil combustion, because the activity was
assumed to be zero.
The emission factors for the combustion of distillate oil were obtained from Reference 6c under the
classification residential furnaces for all pollutants except PM-10. The PM-10 emission factor was
obtained from Reference 7 or Table 3.1-3 of this report. The SO2 emission factor was multiplied by the
weighted average sulfur content. Sulfur contents for No. 1 and No. 2 oils were obtained from Reference
11. Weighting factors were the corresponding quantity of sales (or deliveries) to residential users as
reported in Reference 2 or Reference 3. The resulting weighted average sulfur content was applied to the
SO2 emission factor.
The emission factors for all pollutants except PM-10 for natural gas combustion (SCC 1-03-006-03)
were obtained from Reference 6d. The PM-10 emission factor was obtained from Reference 7.
The emission factors for residential kerosene combustion were obtained from Reference 6c under the
classification residential furnace for distillate oil for all pollutants except PM-10. The PM-10 emission
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factor was obtained from Reference 7 or Table 3.1-3 of this report. The SO2 emission factor was
multiplied by a sulfur content of 0.075 percent.
The emission factors for LPG combustion were obtained from Reference 6e under the classification
domestic/commercial for all pollutants except PM-10. The PM-10 emission factor was obtained from
Reference 7. The SO2 emission factor was multiplied by a sulfur content of 0.0013 percent.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.13.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, TSP, and VOC
emissions from the sources included in this Tier II category.
For the residential combustion of anthracite coal, bituminous coal and lignite, natural gas, and LPG,
the PM-10 control efficiencies for the years 1975 through 1984 were equal to the 1988 PM-10 control
efficiencies obtained from Reference 12. For the years 1940 through 1974, no control efficiencies were
used to estimate PM-10 emissions from the combustion of these fuels. For the residential combustion of
residual oil, distillate oil, and kerosene, no control efficiencies were applied to the activity data to
estimate PM-10 emissions.
3.13.5 References
1. American Housing Survey, Current Housing Reports, Series H-l50-83. Bureau of the Census, U.S.
Department of Commerce, Washington DC. Biennial.
2. Petroleum Marketing Annual. DOE/EIA-0389(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
3. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
4. Natural Gas Annual. DOE/EIA-0131(xx). Energy Information Administration, U.S. Department of
Energy, Washington, DC. Annual.
5. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
6. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
(a) Volume I, Table 1.2-1, Supplement B, September 1988.
(b) Volume I, Table 1.1-1
(c) Volume I, Table 1.3-1
(d) Volume I, Table 1.4-1
(e) Volume I, Table 1.5-1
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7. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
8. Coal Production. DOE/EIA-0118(xx). Energy Information Administration, U.S. Department of
Energy, Washington, DC. Annual.
(a) Table entitled, "Shipments of bituminous coal and lignite by district, consumer, use, and
average sulfur content - 1977."
9. Coal Distribution January-December 19xx. DOE/EIA-0125 (xx/4Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
(a) Table entitled, "Domestic Distribution of U.S. Coal to the Residential and Commercial Sector
by Origin."
10. Minerals Yearbook, Coal. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
11. Heating Oils. U.S. Department of Energy. Obtainable from the National Institute for Petroleum
and Energy Research, ITT Research Institute, P.O. Box 2128, Bartlesville, OK. Annual.
12. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.14 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - ORGANIC
CHEMICAL MANUFACTURING: 04-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(04) CHEMICAL AND ALLIED (01) Organic Chemical Petrochemicals excluding storage
PRODUCT Manufacturing and handling and waste disposal
MANUFACTURING Charcoal (NOX and VOC)
3.14.1 Technical Approach
The CO, NOX, PM-10, TSP, and VOC emissions included in this Tier category were the sum of the
emissions from the source categories listed above. Emissions were estimated from an activity indicator,
emission factor, and control efficiency, where applicable. In order to utilize these values in the Trends
spreadsheets, activity indicators were expressed in thousand short tons and emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.14-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 3 14-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.14.2 Activity Indicator
3.14.2.1 CO Emissions
The activity indicator for charcoal manufacturing was the production figure for charcoal obtained
from Reference 1.
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The activities indicators for petrochemical manufacturing were the production figures for each
material. Production numbers for acetic acid, dimethyl terephthalate, ethylene dichloride, formaldehyde,
maleic anhydride were obtained from Reference 2 or Reference 3. Total production of acrylonitrile and
phthalic anhydride was obtained from Reference 2. The production level of cyclohexanone was obtained
from Reference 3. The approximate production of cyclohexanol was accounted for by multiplying the
cyclohexanone production level by 2. If Reference 3 was not available, the adipic acid production was
obtained from Reference 2. It was assumed that the cyclohexanol/none production reported in Reference
4 for the previous year changed in direct proportion to adipic acid production.
3.14.2.2 NOX Emissions
The activity indicator for charcoal manufacturing was the production figure for charcoal obtained
from Reference 1.
The activities indicators for petrochemical manufacturing were the production figures for each
material. Total production levels of acrylonitrile and adipic acid were obtained from Reference 2. In
order to determine the adiponitrile production level, the total nylon production was obtained from
Reference 2. It was assumed that the year-to-year change in nylon production was proportional to year-
to-year change in adiponitrile production.
3.14.2.3 PM-10 and TSP Emissions
The activity indicators for petrochemical manufacturing were the production figure for each
material. Production levels of phthalic anhydride, polyethylene, PVC, and polypropylene were obtained
from Reference 2.
3.14.2.4 VOC Emissions
The activity indicators for petrochemical manufacturing processes, excluding the storage and
handling and waste disposal, were the production figures for each material. Production numbers for the
chemicals listed in Table 3.14-1 were obtained from Reference 2 or Reference 3. Activity indicators for
the other products and fugitive subcategories were based on the industrial organic chemical production
index obtained from Reference 2.
The activity indicator for charcoal manufacturing was the production figure for charcoal obtained
from Reference 1.
3.14.3 Emission Factor
3.14.3.1 CO Emissions
The emission factor for charcoal (SCC 3-01-006-01) was obtained from Reference 5a.
The emission factors for acetic acid, acrylonitrile, cyclohexanol/none and ethylene dichloride,
formaldehyde, and phthalic anhydride were obtained from Reference 6. The emission factor for dimethyl
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terephthalate (SCC 3-01-031-01) was obtained from Reference 5b. The emission factor for maleic
anhydride (SCC 3-01-100-02) was obtained from Reference 5c.
3.14.3.2 NOX Emissions
The emission factor for charcoal (SCC 3-01-006-01) was obtained from Reference 5a.
The emission factors for acrylonitrile and adiponitrile were obtained from Reference 7. The emission
factor for the adipic acid (SCC 3-01-001-01) was obtained from Reference 5d.
3.14.3.3 PM-10 and TSP Emissions
The emission factors for phthalic anhydride were determined from the emission factors for the raw
material inputs of: o-xylene or naphthalene. The emission factors for o-xylene (SCC 3-01-019-02, 3-01-
019-02, and 3-01-019-04) and for naphthalene (SCC 3-01-019-05, 3-01-019-06, and 3-01-019-07) were
obtained from Reference 5f for TSP and from Reference 8 for PM-10. These emission factors were
weighted according to the capacity figures in Reference 9, in which a table showed the capacity of
phthalic anhydride production in the United States by raw material input: o-xylene or naphthalene.
The emission factors for polyethylene were the averages of the emission factors for the SCCs 3-01-
018-07 and 1-01-018-12. The TSP emission factors were obtained from Reference 7 and the PM-10
emission factors were obtained from Reference 8. Emission factors for the PVC (SCC 3-01-018-01) and
polypropylene (SCC 3-01-018-02) were obtained from Reference 5e for TSP and from Reference 8 for
PM-10.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.14.3.4 VOC Emissions
The emission factors for the chemical products listed in Table 3.14-1 were obtained from Reference
10, with the exception of the emission factors for acetic acid, acrylic acid and acrylonitrile which were
obtained from Reference 11. Weighted average emission factors for the chemical products where more
than one SCC was listed were calculated using the weighting factors given in Table 3.14-1. Where no
weighting factors were given, the overall emission factor for the chemical product was the sum of the
emission factors for the SCCs listed.
For the years 1940 through 1976, the VOC emission factors for other products and fugitives were
obtained from Reference 12. The emission factors for the years 1982 through 1984 were obtained from
Reference 6. The emission factors for the intervening years of 1977 through 1983 were derived from a
linear interpolation between the values for the years 1976 and 1982.
The emission factor for charcoal (SCC 3-01-006-01) was obtained from Reference 5a.
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3.14.4 Control Efficiency
3. 14.4.1 CO Emissions
The control efficiency for charcoal manufacturing was derived from Reference 13 or Reference 14
using Equation 3.14-2.
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
No control efficiencies were applied to the activity data to estimate emissions from petrochemical
production.
3. 14.4.2 NOX Emissions
No control efficiencies were applied to the activity data to estimate NOX emissions from charcoal and
petrochemical production.
3.14.4.3 PM-10 and TSP Emissions
The TSP control efficiency for PVC production was derived from Reference 13 or Reference 14
using the same equation given above for the CO control efficiency for charcoal.
The TSP control efficiency for phthalic anhydride production was assumed to have a constant value
of 0.85 for the years 1979 through 1984. The procedure used to determine the control efficiencies for
the years 1940, 1950, 1960, and 1970 through 1978 is currently unavailable.
No control efficiencies were applied to the activity data to estimate TSP emissions from polyethylene
and polypropylene production.
The PM-10 control efficiencies for the petrochemical emission sources for the years 1975 through
1984 were based on the 1988 PM-10 control efficiencies obtained from Reference 15. During these
years, any changes in the corresponding TSP control efficiencies from the 1985 TSP control efficiency
value were reflected in the PM-10 control efficiencies. For the years 1940 through 1974, no control
efficiencies were used to estimate the PM-10 emissions.
3.14.4.4 VOC Emissions
The control efficiency for charcoal manufacturing was derived from Reference 13 or Reference 14
using the same equation given above for the CO control efficiency. No control efficiencies were applied
to the activity data to estimate VOC emissions from the petrochemical manufacturing sources included in
this Tier II category.
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3.14.5 References
1. Census of Manufactures. Bureau of the Census, U.S. Department of Commerce, Washington, DC.
Available every 5 years.
2. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
3. Synthetic Organic Chemicals, United States Production and Sales. USITC Publication 1745. U.S.
International Trade Commission, Washington, DC. Annual.
4. OAQPS Data File on National Emissions. National Air Data Branch, U.S. Environmental
Protection Agency, Research Triangle Park, NC. 1984.
5. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 5.4-1
b. Volume I, Table 5.21-1
c. Volume I, Table 5.24-1
d. Volume I, Table 5.1-1
e. Volume I, Table 5.13-1
f. Volume I, Table 5.12-1
6. Control Techniques for VOC Emissions from Stationary Sources. 450/3-85-008. U.S.
Environmental Protection Agency, Research Triangle Park, NC. September 1985.
7. Survey Reports on Atmospheric Emissions from the Photochemical Industry, Volume IV.
EPA-450/3-73-005-d. U.S. Environmental Protection Agency, Research Triangle Park, NC. April
1974.
8. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
9. Directory of Chemical Producers
10. VOC Emission Factors for the NAPAP Emission Inventory. Draft Document. U.S. Environmental
Protection Agency. Prepared by Radian Corporation for Air and Energy Engineering Research
Laboratory. August 1986.
11. Criteria Pollutant Emission Factors for the 1985 NAPAP Emission Inventory.
12. Organic Chemical Manufacturing, Volume 1: Program Report. EPA-450/3-80-023. U.S.
Environmental Protection Agency, Research Triangle Park, NC. December 1980.
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13. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
14. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
15. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-74 Category: 04-01
-------
Table 3.14-1. Chemical Products, SCCs, and Weighting Factors for
VOC Emission Factors
Chemical Product
Acetic acid* - via Methanol
- via Butane
- via Acetaldehyde
Acrylic acid*
Acrylonitrile*
Adiponitrile via Butadiene
Benzene - Reactor
- Distillation Vent
Butadiene & Butylene Fractions
1,3 Butadiene
Caprolactam
Chlorobenzene
Cyclohexanone
Cumene
Dimethyl Terephthalate
Ethyl Benzene
Ethylene
Ethylene Dichloride - oxychlorination
- Direct chlorination
Ethylene Glycol
Ethylene Oxide
Formaldehyde - Silver Catalyst
- Mixed Oxide Catalyst
Linear Alkylbenzene - Olefin process
- Chlorination Process
sec
3-01-132-01
3-01-132-05
3-01-132-10
3-01-132-21
3-01-245-05
3-01-254-10
3-01-258-02
3-01-258-03
3-01-153-10(20)
3-01-153-10(20)
3-01-210-02
3-01-210-03
3-01-210-05
3-01-210-06
3-01-210-07
3-01-210-08
3-01-210-09
3-01-210-10
3-01-301-10
3-01-158-01
3-01-156-01
3-01-031-01
3-01-169-01
3-01-197-41
3-01-197-43
3-01-197-45
3-01-125-01
3-01-125-02
3-01-251-02
3-01-251-03
3-01-174-01
3-01-120-01
3-01-120-02
3-01-211-02
3-01-211-03
3-01-211-04
3-01-211-22
3-01-211-23
3-01-211-24
3-01-211-25
Weighting Factor
0.43
0.28
0.29
0.996
0.004
0.8
0.2
0.36
0.36
0.36
0.64
0.64
0.64
0.64
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-75
1940-1984 Methodology
Category: 04-01
-------
Table 3.14-1. (continued)
Chemical Product
Maleic Anhydride
Methanol
Methyl Methacrylate
Nitrobenzene
Perchloroethylene
Phenol
Propylene Oxide - Chlorohydrin
- Isobutane
- Ethylbenzene
Styrene
Toluene Diisocyanate
Vinyl Acetate
Vinyl Chloride
sec
3-01-100-02
3-01-100-03
3-01-100-05
3-01-250-02
3-01-250-03
3-01-190-02
3-01-190-03
3-01-190-04
3-01-190-10
3-01-190-11
3-01-190-12
3-01-190-13
3-01-190-14
3-01-195-01
3-01-125-20
3-01-202-01
3-01-205-**
3-01-205-**
3-01-205-**
3-01-206-01
3-01-181-02
3-01-181-03
3-01-181-04
3-01-181-05
3-01-181-06
3-01-181-07
3-01-181-08
3-01-167-02
3-01-167-03
3-01-167-04
3-01-125-40
Weighting Factor
0.53
0.33
0.14
The emission factors for these chemical products were obtained from Reference 10. For all other chemical products, the emission
factors were obtained from Reference 9.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-76
1940-1984 Methodology
Category: 04-01
-------
3.15 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - INORGANIC
CHEMICAL MANUFACTURING: 04-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(04) CHEMICAL AND ALLIED (02) Inorganic Chemical Ammonia
PRODUCT Manufacturing Titanium Dioxide
MANUFACTURING Nitric Acid
Calcium Carbide
Sulfuric Acid
3.15.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in thousand short tons and emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.15-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.15-1)
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
'National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-77 Category: 04-02
-------
3.15.2 Activity Indicator
3.15.2.1 CO Emissions
The activity indicator for ammonia was the total quantity of ammonia production obtained from
Reference 1. The activity indicator for titanium dioxide was based on the total quantity of titanium
dioxide production as reported in Reference 1. It was assumed that 73 percent of total production was
by chloride process. Therefore total production was multiplied by 0.73 to calculate the total titanium
dioxide produced by the chloride process. For a more accurate figure for the percentage of production
by the chloride process, Reference 2 should be consulted.
3.15.2.2 NOX Emissions
The activity indicator for ammonia was the total quantity of ammonia production obtained from
Reference 1. The activity indicator for nitric acid was the total production of nitric acid obtained from
Reference 1.
3.15.2.3 PM-10 and TSP Emissions
The activity indicator for calcium carbide was the total production of calcium carbide obtained from
Reference 3. When data was withheld (i.e., for proprietary reasons), the previous year's data was used.
The activity indicator for sulfuric acid was the total production of sulfuric acid obtained from Reference
3.
3.15.2.4 SO2 Emissions
The activity indicator for sulfuric acid was the total production of sulfuric acid obtained from
Reference 3.
3.15.2.5 VOCEmissions
The activity indicator for ammonia was the total quantity of ammonia production was obtained from
Reference 1.
3.15.3 Emission Factor
3.15.3.1 CO Emissions
The emission factor for ammonia was the sum of emission factors for feedstock desulfurization
(SCC 3-01-003-05), primary reformer, natural gas (SCC 3-01-003-06), and CO regenerator (SCC 3-01-
003-08). These emission factors were obtained from Reference 4a. The emission factor for titanium
dioxide was obtained from Reference 5 for all U.S. plants with actual CO emission source tests (SCC =
3-03-012-01).
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-78 Category: 04-02
-------
3. 15. 3. 2 NOX Emissions
The emission factor for ammonia (SCC 3-01-003-06) was obtained from Reference 4a.
The emission factor for nitric acid was the weighted average of the emission factors for nitric acid
production by old plants (43 Ib/ton) and new plants (3 Ib/ton). The weighting factors used to calculate
the overall emission factor were the percentage of production from old plants and from new plants,
respectively. New plant production was equal to 5 percent of the total 1970 production (380,000 tons)
for each year since 1970. Old plant production was equal to the difference between total production as
reported in Reference 1 and new plant production, as calculated above.
3.15.3.3 PM-10 and TSP Emissions
The PM-10 and TSP emission factors for calcium carbide were the sum of three emission factors:
electric furnace (SCC 3-05-004-01), coke dryer (SCC 3-05-004-02) and furnace room vents (SCC 3-05-
004-03). The TSP emission factors were obtained from Reference 4c and the PM-10 emission factors
were obtained from Reference 9. The emission factors for sulfuric acid (SCC 3-01-023-01) were
obtained from Reference 4b for TSP and from Reference 6 for PM-10.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3. 15. 3. 4 SO 2 Emissions
The emission factors for sulfuric acid were based on the emission factor calculated for the year
previous to the year under study and the NSPS emission factor (4 Ib/ton). The weighted average of these
two emission factors was based on the production levels for the year under study and the previous year as
presented in Equation 3.15-2.
95 x EF x P + (0 05
yJ - - U'UJ - -
where: EF = SO2 emission factor
i = year under study
P = total production
When the production for the year under study was less than the production for the previous year, then the
last term (P; - PM) was set to zero. New capacity for production was only assumed for a production level
above the previous record high production level.
3.15.3.5 VOC Emissions
The emission factor for ammonia was the sum of emission factors for feedstock desulfurization
(SCC 3-01-003-05), primary reformer, natural gas (SCC 3-01-003-06), carbon dioxide regenerator (SCC
3-01-003-08), and condensate stripper (SCC 3-01-003-09). These emission factors were obtained from
Reference 4a.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-79 Category: 04-02
-------
3.15.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, and VOC
emissions from the source included in this Tier II category.
The TSP control efficiencies for sulfuric acid and calcium carbide production were derived from
Reference 7 or Reference 8 using Equation 3.15-3.
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
The PM-10 control efficiencies for sulfuric acid and calcium carbide production for the years 1975
through 1984 were based on the 1988 PM-10 control efficiencies obtained from Reference 9. During
these years, any changes in the corresponding TSP control efficiencies from the 1985 TSP control
efficiency value were reflected in the PM-10 control efficiencies. For the years 1940 through 1974, no
control efficiencies were used to estimate the PM-10 emissions.
3.15.5 References
1 . Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
2. Chemical Economics Handbook. Stanford Research Institute International, Menlo Park, CA.
3. Current Industrial Reports, Inorganic Chemicals. Bureau of the Census, U.S. Department of
Commerce, Washington, DC. Annual.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 5.2-1
b. Volume I, Table 5. 17-2
c. Volume I, Table 8.4-1
5. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park,NC. February 9, 1980.
6. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-45 0/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
National Air Pollutant Emission Trends 1 940-1 984 Methodology
Procedures Document for 1900-1996 3-80 Category: 04-02
-------
7. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
8. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
9. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-81 Category: 04-02
-------
3.16 CHEMICAL AND ALLIED PRODUCTS MANUFACTURING - POLYMER AND
RESIN MANUFACTURING: 04-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(04) CHEMICAL AND ALLIED (03) Polymer and Resin Plastics Manufacturing excluding
PRODUCT Manufacturing fabrication
MANUFACTURING Synthetics Fibers and Rubber
3.16.1 Technical Approach
The VOC emissions included in this category were the sum of the emissions from the source
categories listed above. Emissions were estimated only for VOC from an activity indicator, emission
factor, and control efficiency, where applicable. In order to utilize these values in the Trends
spreadsheets, activity indicators were expressed in thousand short tons and emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984.
3.16.2 Activity Indicator
The activity indicators for plastics manufacture were the total production levels for each material.
The total production levels of high density polyethylene, low density polyethylene, polypropylene, and
polyvinyl chloride were obtained from Reference 1. The production level of polystyrene was obtained
from Reference 1 as the sum of production levels for the following substances: (1) styrene-acrylonitrile,
(2) polystyrene, and (3) acrylonitrile-butadiene-styrene and other styrene polymers. The production level
for other plastics was obtained from Reference 1 as the sum of production levels for the following
substances: (1) thermosetting resins, (2) polyamides, and (3) other vinyl resins.
The activity indicator for synthetic fibers was the quantity of total man-made fiber production
obtained from Reference 1. The activity indicator for the total synthetic rubber subcategory was the
production of synthetic rubber obtained from Reference 1.
3.16.3 Emission Factor
The emission factors for high density polyethylene (SCC 3-01-018-07), low density polyethylene
(SCC 3-01-018-12), and polystyrene (SCC 3-01-01801) were obtained from Reference 2. The emission
factors for polypropylene (SCC 3-01-018-02) and polyvinyl chloride (SCC 3-01-018-01) were obtained
from Reference 3 a.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-82 Category: 04-03
-------
The emission factor for other plastics manufacturing was calculated by dividing the 1979 actual
emissions for this source by the corresponding activity indicator. The calculation of the 1979 actual
emissions for other plastics followed the steps described below.
1. The 1979 total actual emissions for the high density polyethylene, low density polyethylene,
polypropylene and polystyrene subcategories were calculated using the corresponding 1979 activity
indicators and emission factors.
2. The 1979 actual emissions of polyethylene terephthalate were added to the previous sum. Actual
emissions of polyethylene terephthalate were estimated by multiplying the emission factor obtained
from Reference 4 by the production level obtained from Reference 1 for 1979.
3. It was assumed that the sum calculated in step 2 represented 75 percent of the total emissions from
all plastics. Therefore, the total emissions from all plastics in 1979 was calculated by dividing the
total from step 2 by 0.75.
4. The 1979 actual emissions of high density polyethylene, low density polyethylene, polypropylene and
polystyrene were subtracted from the total emission from all plastics calculated in step 3. The result
was the total 1979 emissions from the other plastics category.
The emission factors for synthetic fibers was obtained from Reference 5. The emission factor for
synthetic rubber was the weighted average of emission factors for the following compounds:
polychloroprene, polyisoprene, butyl, nitrile, polybutadiene, ethylene propylene copolymers, styrene
butadiene rubber, and "others." The styrene butadiene rubber emission factor was obtained from
Reference 3a and all other emission factors were obtained from Reference 6. These emission factors
were weighted by the relative quantity of each compound produced in 1979 as obtained from Reference
1.
3.16.4 Control Efficiency
Control efficiencies were applied to the activity data to estimate VOC emissions from high density
polyethylene production processes, but the procedures for determining these control efficiencies are
currently unavailable. No control efficiencies were applied to the activity data to estimate emissions from
all other sources included in this Tier II category.
3.16.5 References
1. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
2. Criteria Pollutant Emission Factors for the 1985 NAPAP Emissions Inventory.
3. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 5.13-1
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-83 Category: 04-03
-------
4. Polymer Manufacturing Industry - Background Information for Proposed Standards; Preliminary
Draft. EPA-450/3-83-012a. U.S. Environmental Protection Agency, Research Triangle Park, NC.
October 1984.
5. OAQPS Data File on National Emissions. National Air Data Branch, U.S. Environmental
Protection Agency, Research Triangle Park, NC. 1984.
6. Control Techniques for VOC Emissions from Stationary Sources. EPA-450/3-85-008. U.S.
Environmental Protection Agency, Research Triangle Park, NC. September 1985.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-84 Category: 04-03
-------
3.17 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - AGRICULTURAL
CHEMICAL MANUFACTURING: 04-04
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(04) CHEMICAL AND ALLIED (04) Agricultural Chemical Fertilizers - ammonia nitrate,
PRODUCT Manufacturing diammonium phosphate and urea
MANUFACTURING
3.17.1 Technical Approach
The PM-10 and TSP emissions included in this Tier category were the sum of the emissions from the
source categories listed above. Emissions were only estimated for particulate matter from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in thousand short tons and emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1992 for TSP and for the years
1975 through 1984 for PM-10. For some source categories, the PM-10 emissions exceeded the TSP
emissions as calculated by the procedures presented in this section. Because this represents a physical
impossibility, a more realistic estimate of the PM-10 emissions was assumed to be the TSP emissions
value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.17-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 3 17-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.17.2 Activity Indicator
The activity indicators for the manufacture of fertilizers were the production levels of the individual
materials. Total production levels for ammonium nitrate and urea were obtained from Reference 1. Total
production of diammonium phosphate was calculated as the sum of production levels of diammonium,
monoammonium, and other ammonium phosphates obtained from Reference 2. Production was
expressed in equivalent tons of phosphoric oxide, P205 content.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-85 Category: 04-04
-------
3.17.3 Emission Factor
The emission factors for ammonium nitrate manufacturing were the weighted averages of the
emission factors for specific processes obtained from Reference 3a for TSP and from Reference 4 for
PM-10. The specific processes and SCCs included in the weighted averages along with the weighting
factors are presented in Table 3.17-1. Each emission factor was multiplied by the corresponding
weighting factor and the products were summed.
The emission factors for diammonium phosphate production were the sum of the emission factors
for following processes: (1) dryer, cooler and (2) ammoniator - granulator. The TSP emission factors
were obtained from Reference 5a; the PM-10 emission factors were obtained from Reference 4.
For urea production, the emission factors were the weighted averages of emission factors for specific
processes obtained from Reference 3b for TSP and from Reference 4 for PM-10. The specific processes
and SCCs included in the weighted averages along with the weighting factors are presented in Table
3.17-2. Each emission factor was multiplied by the corresponding weighting factor and the products
were summed.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.17.4 Control Efficiency
The TSP control efficiency for diammonium phosphate production was derived from Reference 6 or
Reference 7 using Equation 3.17-2.
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
The TSP control efficiencies for ammonium nitrate and urea production were based on the
controlled and uncontrolled emission factors from Reference 1 . For ammonium nitrate production, this
procedure for determining control efficiency was used for the years 1974 through 1984. For urea
production, this procedure was used for the years 1979 through 1984. For the years prior to those stated
above, the procedures for determining the TSP control efficiencies are currently unavailable.
The PM-10 control efficiencies for the production of these three fertilizers for the years 1975
through 1984 were based on the 1988 PM-10 control efficiencies obtained from Reference 8. During
these years, any changes in the corresponding TSP control efficiencies from the 1985 TSP control
efficiency value were reflected in the PM-10 control efficiencies. For the years 1940 through 1974, no
control efficiencies were used to estimate PM-10 emissions.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-86 Category: 04-04
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3.17.5 References
1. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
2. Current Industrial Reports, Fertilizer Materials. Bureau of the Census, U.S. Department of
Commerce, Washington, DC. Annual.
3. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 6.8-1
b. Volume I, Table 6.14-1
4. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
5. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
b. Volume I, Table 6.10-1
6. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
7. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
8. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-87 Category: 04-04
-------
Table 3.17-1. Ammonium Nitrate Emission Factor SCCs and Weighting Factors
Weighting Factor
SCC
Description
3-01-027-04
3-01-027-17(27)
3-01-027-18(28)
3-01-027-12
3-01-027-22
3-01-027-07
3-01-027-08
3-01-027-14
3-01-027-24
3-01-027-25
3-01-027-29
3-01-027-30
Neutralizer (All Plants)
Solids Evap. Concentrator (All Plants)
Coating Operation
High Density Prilling (Solids Form.)
Low Density Prilling (Solids Form.)
Rotary Drum Granulators (Solids Form.)
Pan Granulators (Solids Form.)
High Density Prilling (Coolers/Dryers)
Low Density Prilling (Coolers/Dryers)
Low Density Prilling/Drying (Coolers/Dryers)
Rotary Drum Granulators (Coolers/Dryers)
Pan Granulator Coolers (Coolers/Dryers)
1.0
0.6
0.4
0.36
0.18
0.04
0.01
0.36
0.18
0.18
0.032
0.006
Table 3.17-2. Urea Emission Factor SCCs and Weighting Factors
SCC
Description
Weighting Factor
3-01-040-02
3-01-040-04
3-01-040-08
3-01-040-09
3-01-040-10
3-01-040-11
3-01-040-12
3-01-040-06
Solution Concentration
Drum Granulation
Nonfluid Bed Prilling (Agricultural Grade)
Nonfluid Bed Prilling (Feed Grade)
Fluid Bed Prilling (Agricultural Grade)
Fluid Bed Prilling (Feed Grade)
Rotary Drum Cooler
Bagging
1.0
0.45
0.07
0.005
0.07
0.005
0.045
0.045
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-88
1940-1984 Methodology
Category: 04-04
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3.18 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - PAINT, VARNISH,
LACQUER, AND ENAMEL MANUFACTURING: 04-05
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category
(04) CHEMICAL AND ALLIED (05) Paint, Varnish, Lacquer,
PRODUCT Enamel Manufacturing
MANUFACTURING
3.18.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source category
listed above. Emissions were estimated only for VOC from an activity indicator, emission factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, the
activity indicator was expressed in thousand short tons and the emission factor was expressed in metric
pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984.
3.18.2 Activity Indicator
The activity indicator for paint manufacturing was the total shipments of paint and allied products
obtained from Reference 1.
3.18.3 Emission Factor
The emission factor for paint manufacturing was the sum of the emission factors for general
mixing/handling (SCC 3-01-014-01) and varnish manufacture, oleoresinous (SCC 3-01-015-02) obtained
from Reference 2a.
3.18.4 Control Efficiency
The control efficiency for paint manufacturing was derived from Reference 3 or Reference 4 using
Equation 3.18-1.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-89 Category: 04-05
-------
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
3.18.5 References
1. Current Industrial Reports, Paint and Allied Products. Bureau of the Census, U.S. Department of
Commerce, Washington, DC. Annual.
2. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 5.10-1
3. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
4. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
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3.19 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - PHARMACEUTICAL
MANUFACTURING: 04-06
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category
(04) CHEMICAL AND ALLIED (06) Pharmaceutical
PRODUCT Manufacturing
MANUFACTURING
3.19.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source category
listed above. Emissions were estimated only for VOC from an activity indicator and emission factor. In
order to utilize these values in the Trends spreadsheets, the activity indicator was expressed in thousand
short tons and the emission factor was expressed in metric pounds/short ton.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984.
3.19.2 Activity Indicator
The activity indicator for pharmaceutical manufacturing was the production index for drugs and
medicines obtained from Reference 1. The index was multiplied by 10 to obtain the activity indicator for
Pharmaceuticals.
3.19.3 Emission Factor
The emission factor for pharmaceutical manufacturing was 63.1 Ib VOC/ton and comes from
Reference 2.
3.19.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from the
manufacture of pharmaceuticals.
3.19.5 References
1. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
2. Control Techniques for VOC Emissions from Stationary Sources. EPA-450/3-85-008. U.S.
Environmental Protection Agency, Research Triangle Park, NC. September 1985.
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3.20 CHEMICAL AND ALLIED PRODUCTS MANUFACTURING - OTHER CHEMICAL
MANUFACTURING: 04-07
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(04) CHEMICAL AND ALLIED (07) Other Chemical Carbon Black
PRODUCT Manufacturing Soap and Detergents
MANUFACTURING
3.20.1 Technical Approach
The CO, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of the
emissions from the source categories listed above. Emissions were estimated from an activity indicator,
emission factor, and control efficiency, where applicable. In order to utilize these values in the Trends
spreadsheets, activity indicators was expressed in thousand short tons and emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.20-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x ^p —: y-^- (Eq. 3.20-1)
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.20.2 Activity Indicator
3.20.2.1 CO Emissions
The activity indicators for carbon black production by the oil and gas processes were based on the
total quantity of carbon black produced as reported in Reference 1. It was assumed that 90 percent of
total production was by the oil process and 10 percent of total production was by the gas process. For
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the years 1940 through 1973, the activity of carbon black production by the channel process was obtained
from Reference 2. After 1973, production by this process was assumed to be zero.
3.20.2.2 PM-10 and TSP Emissions
The activity indicators for carbon black production by the oil and gas processes were based on the
total quantity of carbon black produced obtained from Reference 1. It was assumed that 90 percent of
total production was by the oil process and 10 percent of total production was by the gas process. For
the years 1940 through 1973, the activity of carbon black production by the channel process was obtained
from Reference 2. After 1973, production by the channel process was assumed to be zero.
The activity indicators for charcoal and soap and detergent production were based on the
corresponding production figures obtained from Reference 3. Because this reference was only published
every 5 years, the data from the year of publication prior to the year under study was projected to the
year under study. The growth factor was based on the production index reported in Reference 1. It was
calculated as the ratio between the production index for year under study and the production index for
the publication year of Reference 3. The overall calculation is summarized in Equation 3.20-2.
Production indext
Activity Indicator. = Production figure, x (Eq 3 20-2)
Production index.
where: i = year under study
j = year of preceding publication of Reference 2
3.20.2.3 SO2 Emissions
The activity indicator for carbon black production was the total carbon black production obtained
from Reference 1. This activity was not divided by process.
3.20.2.4 VOC Emissions
The activity indicators for carbon black production by the oil and gas processes were based on the
total quantity of carbon black produced obtained from Reference 1. It was assumed that 90 percent of
total production was by the oil process and 10 percent of total production was by the gas process. For
the years 1940 through 1973, the activity of carbon black production by the channel process was obtained
from Reference 2. After 1973, production by the channel process was assumed to be zero.
3.20.3 Emission Factor
3.20.3.1 CO Emissions
The emission factor for carbon black production by the oil process (SCC 3-01-005-04) was obtained
from Reference 4a. The emission factors for carbon black production by the gas process (SCC 3-01-005-
03) and the charcoal process were obtained from Reference 5.
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3.20.3.2 PM-10 and TSP Emissions
The TSP emission factors for carbon black production by the oil process (SCC 3-01-005-04) was
obtained from Reference 4a. The TSP emission factors for carbon black production by the gas process
(SCC 3-01-005-03) and the channel process were obtained from Reference 4c. The PM-10 emission
factors for the three carbon black production processes were obtained from Reference 6.
The emission factors for charcoal were derived from the emission factors for charcoal kiln (SCC 3-
01-006-03) and charcoal briquetting (3-01-006-05) obtained from Reference 4b for TSP and from
Reference 6 for PM-10. The overall charcoal emission factors were the sum of the kiln emission factor
and a specific percentage of the briquetting emission factor. For the years 1980 through 1984, this was
90 percent. For each preceding year through the year 1950, the percentage was decreased by one. The
percentage was held constant from 1940 to 1950.
The emission factors for soap and detergent production (SCC 3-01-009-01) were obtained from
Reference 4c for TSP and from Reference 6 for PM-10.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.20.3.3 SO2 Emissions
The emission factor for carbon black production was based on the emission factor for flared furnace
exhaust, oil process obtained from Reference 4a and the CO control efficiency for carbon black
production by the oil process. The description of this CO control efficiency is presented in the next
section. The SO2 emission factor was calculated according to Equation 3.20-3.
2, carbon black = (^CO, carbon black ' 0.913) X EFFlared Furnace Exhaust (Eq. 3.20-3)
where: EF = emission factor
CE = control efficiency, expressed as a fraction
3.20.3.4 VOCEmissions
The emission factor for carbon black production by the oil process (main vent, SCC 3-01-005-04)
was obtained from Reference 4a. The emission factors for carbon black production by the gas process
(main vent, SCC 3-01-005-03) and the channel process were obtained from Reference 5.
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3.20.4 Control Efficiency
3.20.4.1 CO Emissions
The control efficiencies for carbon black production by both the oil process and gas process were
computed from actual and uncontrolled emissions reported in Reference 7 or Reference 8 using Equation
3.20-4.
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
No control efficiencies were applied to the activity data for carbon black production by the channel
process.
3.20.4.2 PM-10 and TSP Emissions
The TSP control efficiencies for carbon black production by the oil process and gas process and for
soap and detergent production were derived from Reference 7 or Reference 8 using the same equation
given above for the CO control efficiencies. No control efficiencies were applied to the activity data for
carbon black production by the channel process.
The TSP control efficiency for charcoal production was calculated based on the control on kilns (
SCC 301-006-01) for either CO, TSP, or VOC emissions obtained from Reference 7 or Reference 8.
The TSP control efficiency for this process was calculated using Equation 3.20-5.
CE - nriquemngx Q.9XQ.95)
CE charcoal ~ - 7^ - —j^ - ^^ - (Eq. 3.20-5)
y^^kiln ^f Briquetting U'^
where: CE = control efficiency
EF = emission factor
The PM-10 control efficiencies for carbon black, charcoal, and soap and detergent production for
the years 1975 through 1984 were based on the 1988 PM-10 control efficiencies obtained from Reference
9. During these years, any changes in the corresponding TSP control efficiencies from the 1985 TSP
control efficiency value were reflected in the PM-10 control efficiencies. For the years 1940 through
1974, no control efficiencies were used to estimate PM-10 emissions.
3. 20.4.3 SO 2 Emissions
No control efficiencies were applied to the activity data to estimate SO2 emissions from the carbon
black production processes.
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3.20.4.4 VOCEmissions
The VOC control efficiencies for carbon black production processes were 85 percent of the CO
control efficiencies for the corresponding production process.
3.20.5 References
1. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
2. Minerals Yearbook, Carbon Black. Bureau of Mines, U.S. Department of the Interior, Washington,
DC. Annual.
3. Census of Manufactures. Bureau of the Census, U.S. Department of Commerce, Washington, DC.
Available every five years.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 5.3-3
b. Volume I, Table 5.4-1
c. Volume I, Table 5.15-1
5. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
6. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
7. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
8. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
9. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.21 METALS PROCESSING - NONFERROUS: 05-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(05) METALS PROCESSING (01) Nonferrous Primary Metals Industry
(aluminum, copper, zinc, and
lead)
Secondary Metal Industry
(aluminum, lead, and copper)
Nonferrous Smelters (copper,
zinc, and lead)
3.21.1 Technical Approach
The CO, PM-10, TSP, and SO2 emissions included in this Tier category were the sum of the
emissions from the source categories listed above. No estimates were made for VOC. Emissions were
estimated from an activity indicator, emission factor, and control efficiency, where applicable. In order to
utilize these values in the Trends spreadsheets, activity indicators were expressed in thousand short tons
and emission factors were expressed in metric pounds/short ton. All control efficiencies were expressed
as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.21-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 321-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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3.21.2 Activity Indicator
3.21.2.1 CO Emissions
Primary aluminum production was obtained from Reference 1. This production level was used as
the activity indicator for primary aluminum.
3.21.2.2 PM-10 and TSP Emissions
3.21.2.2.1 Primary Metals Industry - Aluminum —
The production of calcined alumina, obtained from Reference 2a, was the activity indicator for
calcining of hydroxide. The primary aluminum production, obtained from Reference 1, was the activity
indicator for material handling.
The Horizontal Stud Soderberg (HSS) stack was assigned an activity equivalent to 18.5 percent of
the total primary aluminum production. Activity of the HSS fugitive was assumed to equal to that for
HSS stack. The Vertical Stud Soderberg (VSS) stacks was assigned an activity equivalent to 10.5
percent of the total primary aluminum production. The activity of VSS fugitives was assumed to equal to
that of VSS stacks.
Stack and fugitive prebake were each assigned an activity equivalent to 71 percent of the total
primary aluminum production. The activity of anode baking was assumed to equal to that of prebake.
3.21.2.2.2 Primary Metals Industry - Copper —
The activity indicator for roasting was based on the primary copper smelter production from
domestic and foreign ores from Reference 3a. This reference provided the units of blister copper
produced. It was assumed that of the 4 tons of copper concentrate/ton of blister, only half was roasted.
Therefore, units of blister copper produced multiplied by 2 resulted in the activity indicator for roasting.
The activity indicators for smelting and converting were assumed to be equivalent. The activities
were calculated in the same manner as for roasting, except it was assumed that all of the blister copper
produced is smelted and converted. Therefore, units of blister copper produced multiplied by 4 resulted
in the activity indicators for smelting and converting.
The total new copper smelter production figure obtained from Reference 3b was used as the activity
indicator for fugitives.
3.21.2.2.3 Primary Metals Industry - Zinc —
The activity indicator for roasting was assigned the total slab zinc production obtained from the
Reference 4. The production figure was converted to short tons and multiplied by 2 to account for the
fact that there are 2 units of concentrate/ton slab zinc.
The activity indicator for sintering was assigned the redistilled slab zinc production obtained from
Reference 4a. The activity indicator for electrolytic processes was estimated by subtracting the redistilled
slab zinc production from total slab zinc production. These data were obtained from Reference 4.
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The activity indicator for horizontal retort process was assume to be zero. The activity indicator for
vertical retort processes was assigned the same value as used for zinc sintering.
Total slab zinc production figure obtained from Reference 4 was used as the activity for fugitive
processes.
3.21.2.2.4 Primary Metals Industry - Lead —
The activities for the sintering process, blast furnaces, reverberatory furnaces, and fugitive processes
were set equal to the primary refined lead production from domestic and foreign ores obtained from
Reference 5.
3.21.2.2.5 Secondary Metals - Aluminum —
The activity indicator for sweating was the total consumption of all scrap by "sweated pig" and
"borings and turnings" was obtained from Reference 1. Total of all scrap consumed, also from Reference
1, was the activity indicator for refining.
The activity indicator for fluxing was based on the quantities of magnesium recovered from new and
old aluminum-based scrap obtained from Reference 6a. The quantities of magnesium were summed and
multiplied by 4.
The activity indicator for fugitive processes was the total quantity of secondary aluminum recovered
obtained from Reference 1.
3.21.2.2.6 Secondary Metals - Lead —
The data used to estimate the activity for the four lead processes were obtained from Reference 5.
The pot furnace activity was estimated as 90 percent of the total consumption of lead scrap by all
consumers obtained from Reference 5 a. The activity indicator for reverberatory furnaces was calculated
by multiplying the total consumption of lead scrap by the ratio between the quantity of lead recovered as
soft lead and the total lead recovered from scrap. The activity indicator for blast furnaces was calculated
by multiplying the total consumption of lead scrap by the ratio between lead recovered as antimonial lead
and the total lead recovered from scrap. The total quantity of secondary lead recovered in the U.S. was
used as the activity indicator for fugitive processes.
3.21.2.2.7 Secondary Metals - Copper —
The data used to estimate the activity for the four copper processes were obtained from Reference 3.
The activity for wire burning was calculated as one-half of the total consumption of No. 2 wire obtained
from Reference 3c. The activity for brass and bronze coating was calculated by multiplying the total
consumption of scrap by the ratio between the copper recovered in alloys and the total secondary copper
production. The activity for smelting was calculated by multiplying the total consumption of scrap by the
ratio between the copper recovered as unalloyed copper and the total secondary copper production. The
total quantity of copper recovered from all scrap was assigned the activity for fugitive processes.
3.21.2.3 SO2 Emissions
The activity indicator for copper roasting was based on the primary copper smelter production from
domestic and foreign ores from Reference 3a. This reference provided the units of blister copper
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produced. It was assumed that of the 4 tons of copper concentrate/ton of blister, only half were roasted.
Therefore, units of blister copper produced multiplied by 2 resulted in the activity indicator for copper
concentrate roasting.
The activity indicators for copper smelting and converting were assumed to be equivalent. The
activities were calculated in the same manner as for the roasting category, except it was assumed that all
of the blister copper produced was smelted and converted. Therefore, units of blister copper produced
multiplied by 4 resulted in the activity indicators for copper smelting and converting.
The activity indicator for zinc ore roasting was assigned the total slab zinc production obtained from
the Reference 4. The production figure was converted to short tons and multiplied by 2 to account for
the fact that there are 2 units of concentrate/ton slab zinc.
The determination for the activity indicator for lead processing required the following steps: (1)
calculation of the quantity of SO2 removed as by-product sulfuric acid by lead plants, (2) calculation of
total SO2 emissions from lead processing, and (3) calculation of lead processing activity indicator. Each
of these steps are described below.
For the first step, the quantity of by-product sulfuric acid produced from lead plants was obtained
from Reference 3. This value was multiplied by the ratio of the molecular weight of SO2 to the molecular
weight of sulfuric acid (64/98), in order to obtain the amount of SO2 removed as sulfuric acid.
The second step required the actual quantity of SO2 emitted from lead production (SCC 3-03-010-
xx) obtained from Reference 7 or 8. The amount of SO2 removed as sulfuric acid was added to the actual
amount of SO2 emitted to calculate the total amount of SO2 emitted by lead processing.
Emissionsvri , , = H~SOA + Emissions,,^ . , mn -2 91 o\
S02 , lead proc. 2 4>SO2jeadproc SO2,actual (Eq. 3.21-2)
The last step in this method calculated the production level for lead processing by using the total
amount of SO2 emitted by lead processing, converted to metric pounds, and the emission factor for lead
processing. The emission factor was determined according to the description presented later in this
section. Equation 3.21-3 was used to complete the calculation of the activity indicator for lead
processing.
„ J EmiSSi0nS02,lead proc. * 200°lbltOH
Production, , = (Eq 3 21-3)
lead proc. 54Qlb SOJtOHS lead PWC. ^ '
The primary aluminum production obtained from Reference 1 was the activity indicator for primary
aluminum processes.
The data used to estimate the activity for the two furnace types used in secondary lead production
were obtained from Reference 5. The activity indicator for reverberatory furnaces was calculated by
multiplying the total consumption of lead scrap by the ratio between the quantity of lead recovered as soft
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lead and the total lead recovered from scrap. The activity indicator for blast furnaces was calculated by
multiplying the total consumption of lead scrap by the ratio between lead recovered as antimonial lead
and the total lead recovered from scrap.
3.21.3 Emission Factor
3.21.3.1 CO Emissions
The emission factor for primary aluminum was obtained from Reference 9.
3.21.3.2 PM-10 and TSP Emissions
3.21.3.2.1 Primary Metals Industry - Aluminum —
The TSP emission factors for all aluminum production processes, with the exception of material
handling, were obtained from Reference lOa. The TSP emission factor for material handling was
obtained from Reference 1 la. The PM-10 emission factors for all aluminum production processes were
obtained from Reference 12. The SCCs corresponding to each of the production processes are presented
in Table 3.21-1.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
3.21.3.2.2 Primary Metals Industry - Copper —
The emission factors for roasting were the weighted averages of the emission factors for two process
types listed in Table 3.21-2. The TSP emission factor was obtained from Reference lOb and the PM-10
emission factors were obtained from Reference 12. Weighting factors were the 1981 capacity for each
process type as presented in Table 3.21-2.
The emission factors for smelting were the weighted averages of the emission factors for four
process types. The emission factors were obtained from Reference lOb for TSP and from Reference 12
for PM-10. These emission factors were weighted using the 1981 capacity for each process. The SCCs
and descriptions of the four processes along with the 1981 capacity data are presented in Table 3.21-3.
The emission factors for converting were obtained from Reference lOc for TSP and from Reference
12 for PM-10. The TSP emission factor for fugitive processes was obtained from Reference 13. The
PM-10 emission factor for fugitive processes was obtained from Reference 12 or Table 3.1-3 of this
report.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
3.21.3.2.3 Primary Metals Industry - Zinc —
The emission factors were obtained from Reference lOc for the following processes: roasters (SCC
3-03-030-02 for multiple hearth roaster), sintering (SCC 3-03-030-03), electrolytic (SCC 3-03-030-06),
and vertical retorts (SCC 3-03-030-05). The emission factor for horizontal retorts (SCC 3-03-030-xx)
was obtained from Reference 1 Ib. The PM-10 emission factors for these processes were obtained from
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Reference 12. The emission factors for fugitive processes were obtained from Reference 13 for TSP and
from Reference 12 or Table 3.1-3 of this report for PM-10.
The emission factors for sintering, electrolytic, horizontal retorts, vertical retorts, and fugitive
processes were multiplied by 2 to account for the fact that there were 2 units of concentrate/ton of slab
zinc.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
3.21.3.2.4 Primary Metals Industry - Lead —
The emission factors were obtained from Reference lOd for the following processes: sintering (SCC
3-03-010-01), blast furnaces (SCC 3-03-010-02), and reverberatory furnaces, dross (SCC 3-03-010-03).
The PM-10 emission factors for these processes were obtained from Reference 12. The emission factors
for fugitive processes were obtained from Reference 13 for TSP and from Reference 12 or Table 3.1-3 of
this report for PM-10.
The emission factors for sintering and blast furnaces were multiplied by 2 to account for the fact
that there were 2 units of concentrate/ton of slab lead.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
3.21.3.2.5 Secondary Metal Industry - Aluminum —
The emission factors for sweating were the weighted averages of the emission factors for sweating
furnaces (SCC 3-04-001-01) and scrap dryers (3-04-002-07). The TSP emission factors for these
processes were obtained from Reference lOe and lOf; the PM-10 emission factors were obtained from
Reference 12. The scrap dryer emission factors were used as surrogates. The sweating furnace emission
factors were weighted by the consumption of sweated pig and the scrap dryer emission factors were
weighted by the consumption of borings and turnings. Consumption data were obtained from Reference
1.
The emission factors for refining were the weighted averages of the emission factors for smelting
furnace/crucible (SCC 3-04-001-02) and smelting furnace/reverberatory (3-04-001-03). The TSP
emission factors were obtained from Reference lOe and the PM-10 emission factors from Reference 12.
These emission factors were weighted based on Reference 7 or Reference 8.
The emission factors for fluxing (SCC 3-04-001-04) were obtained from Reference lOe for TSP and
from Reference 12 for PM-10. The TSP emission factor for fugitive processes was obtained from
Reference 13. The PM-10 emission factor for fugitive processes was obtained from Reference 12 or
Table 3.1-3 of this report.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
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3. 21. 3. 2. 6 Secondary Metal Industry - Lead —
The emission factor for pot furnaces or kettle refining (SCC 3-04-004-01), reverberatory furnaces
(SCC 3-04-004-02), and blast furnaces (SCC 3-04-004-03) was obtained from Reference lie The
PM-10 emission factors for these processes were obtained from Reference 12. The fugitive processes
emission factors were obtained from Reference 13. The PM-10 emission factor for fugitive processes
was obtained from Reference 12 or Table 3.1-2 of this report.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
3. 21. 3. 2. 7 Secondary Metal Industry - Copper —
The emission factors for wiring burning were obtained from Reference 14 for TSP and from
Reference 12 for PM-10.
The emission factors for brass and bronze casting were the weighted averages of the emission
factors for five casting methods added to the emission factor for a sixth method, cupola (SCC 3-04-002-
12). All TSP emission factors were obtained from Reference lOf. The PM-10 emission factors were
obtained from Reference 12. Operating rates obtained from Reference 9 for the five casting methods
were used to calculated the weighted average emission factors. The casting methods, SCCs, and
weighting factors for the five casting methods are presented in Table 3.21-4. The resulting weighted
average emission factors were added to the cupola emission factors to obtain the overall brass and bronze
casting PM-10 and TSP emission factors.
The emission factor for smelting were the weighted sum of the emission factors for the following
four smelter types: (1) cupola, scrap copper (SCC 3-04-002-10), (2) reverberatory, scrap copper (SCC 3-
04-002-14), (3) electric arc, scrap copper (SCC 3-04-002-20), and electric induction, scrap copper (SCC
3-04-002-23). These emission factors were obtained from Reference 1 Of for TSP and from Reference 12
for PM-10. The emission factors were summed according to Equation 3.21-4.
EF = EFC + (2 x EF^} + [(EFEA + EFEI] I 2] (Eq. 3.21-4)
where: EF = emission factor
C = cupola for scrap copper
RF = reverberatory furnace for scrap copper
EA = electric arc for scrap copper
El = electric induction
The TSP emission factor for fugitive processes was obtained from Reference lid. The PM-10
emission factor was obtained from Reference 12 or Table 3.1-3 of this report.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
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3.21.3.3 SO2 Emissions
The emission factor for roasting was the weighted average of the emission factors for two process
types. The emission factors were obtained from Reference lOb and were weighted using the 1981
capacity for each process type. The SCCs and descriptions of the two process types along with the 1981
capacity data are presented in Table 3.21-2. To account for fugitive emissions, 1 Ib/ton was added to the
weighted average emission factor.
The emission factor for copper smelting was the weighted average of the emission factors for six
process types. Emission factors were obtained from Reference lOb and were weighted using the 1981
capacity for each process type. The SCCs and descriptions of the six process types along with the 1981
capacity data are presented in Table 3.21-5. The weighting factors were changed from the 1981 capacity
data when an existing smelter ceased operations, a new smelter began operations, or an existing smelter
was modified. This information was obtained from Reference 3a. To account for fugitive emissions, 4
Ib/ton was added to the weighted average emission factor.
The emission factor for copper converting was the weighted average of the emission factors for six
process types. The emission factors were obtained from Reference lOb, except for the noranda reactor
emission factor which was assumed. The emission factors were weighted using the 1981 capacity for
each process type. The SCCs and descriptions of the six process types along with the 1981 capacity data
are presented in Table 3.21-6. To account for fugitive emissions, 130 Ib/ton was added to the weighted
average emission factor.
The emission factor for zinc roasting (SCC 3-03-030-02) was obtained from Reference lOd.
The emission factor for lead roasting was the sum of the emission factors for sintering (SCC 3-03-
010-01) and blast furnace (SCC 3-03-010-02). These emission factors were obtained from Reference
lOd.
The emission factor for primary aluminum was obtained from Reference 9.
The emission factors for secondary lead processing in reverberatory furnaces (SCCS-04-004-02) and
blast furnaces (SCC 3-04-004-03) were obtained from Reference lOg.
3.21.4 Control Efficiency
3.21.4.1 CO Emissions
No control efficiencies were applied to the activity data to estimate emissions from primary
aluminum production.
3.21.4.2 PM-10 and TSP Emissions
The TSP control efficiencies for all primary metals industry production processes and all secondary
metals industry production processes, except for any fugitive processes were derived from Reference 7 or
Reference 8 using Equation 3.21-5. For those processes where the emission factor was calculated as the
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weighted average of the emission factors of several process types, the control efficiency was calculated as
the weighted average of the individual control efficiencies in the same manner.
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
The TSP control efficiencies for the primary metals industry fugitive processes for aluminum,
copper, lead and zinc production were obtained by engineering judgment. No additional information is
currently available concerning the origin of these TSP control efficiencies. The same is true for the
control efficiencies for the secondary metals industry fugitive processes for aluminum, lead, and copper.
The PM-10 control efficiencies for all primary metals industry and secondary metals industry
production process, excluding the fugitive processes for the years 1975 through 1984 were based on the
1988 PM-10 control efficiencies obtained from Reference 15. During these years, any changes in the
corresponding TSP control efficiencies from the 1985 TSP control efficiency values were reflected in the
PM-10 control efficiencies. For the years 1940 through 1974, no control efficiencies were used to
estimate PM-10 emissions.
No control efficiencies were applied to the activity data to estimate PM-10 emissions from fugitive
processes for either the primary metals industry or the secondary metals industry.
3.21.4.3 SO2 Emissions
No control efficiencies were applied to the activity data to estimate SO2 emissions from the source
included in this Tier II category.
3.21.5 References
1. Minerals Yearbook, Aluminum. Bureau of Mines, U.S. Department of the Interior, Washington,
DC. Annual.
2. Minerals Yearbook, Bauxite and Alumina. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Annual.
a. Table entitled, "Production and Shipments of Alumina in the U.S."
3. Minerals Yearbook, Copper. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
(a) Table entitled, "Copper: World Smelter Production, by country."
(b) Table entitled, "Primary and Secondary Copper Produced by Refineries and Electrowinning
plants in the U.S."
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(c) Table entitled, "Consumption of Copper-base Scrap in the U.S. in 19xx."
4. Minerals Yearbook, Zinc. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
(a) Table entitled, "Production of Zinc Products from Zinc-based Scrap in the U.S.: Redistilled
Slab Zinc."
5. Minerals Yearbook, Lead. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
(a) Table entitled, "Stocks and Consumption of new and old Lead Scrap in the U.S."
(b) Table entitled, "U.S. Consumption of Lead, by Product".
6. Minerals Yearbook, Magnesium. Bureau of Mines, U.S. Department of the Interior, Washington,
DC. Annual.
(a) Table entitled, "Magnesium Recovered from the Scrap Processed in the U.S. by Kind of Scrap
and Form of Recovery"
7. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
8. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
9. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park, NC. February 9, 1980.
10. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 7.1-2
b. Volume I, Table 7.3-2
c. Volume I, Table 7.7-1
d. Volume I, Table 7.6-1
e. Volume I, Table 7.8-1
f. Volume I, Table 7.9-1
g. Volume I, 7.11-1
11. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Volume I, Part B, Table 7.1-2
b. Volume I, Part B, Table 7.7-1
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c. Volume I, Table 7.11-1
d. Volume I, Table 7.9-2
12. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
13. Assessment of Fugitive Paniculate Emission Factors for Industrial Processes. EPA-450/3-78-107.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1978.
14. Internal Memorandum, "OAQPS Data File Emission Estimate from Copper Wire Burning." From
Robert Rosenteel, Standards Support Section, to Chuck Mann, U.S. Environmental Protection
Agency, Research Triangle Park, NC. November 16, 1979.
15. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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Table 3.21-1. PM-10 Emission Factors SCCs for the Primary Metals Industry - Aluminum
SCC Description
3-03-002-01 Calcining of Hydroxide
3-03-001-02 HSS-Stack
3-03-001-09 HSS-Fugitive
3-03-001-03 VSS-Stack
3-03-001-10 VSS-Fugitive
3-03-001-01 Prebake - Stack
3-03-001-08 Prebake - Fugitive
3-03-001-05 Anode Baking
3-03-001-04 Materials Handling
Table 3.21-2. PM-10 and SO2 Emission Factors SCCs and Weighting Factors for the
Primary Metals Industry - Copper Roaster
1981
SCC Description Capacity
3-03-005-02 Multiple Hearth Roaster 430
3-03-005-09 Fluidized Bed Roaster 230
Table 3.21-3. PM-10 Emission Factors SCCs and Weighting Factors for the Primary
Metals Industry - Copper Smelting
1981
SCC Description Capacity
3-03-005-07 Reverb. Furnace w/o Roasting 636
3-03-005-31 Reverb. Furnace + Multi-Hearth Reverb. 430
3-03-005-32 Furnace + Fluid Bed Roaster 212
3-03-005-10 Electric Smelting Furnace 257
Table 3.21-4. PM-10 Emission Factors SCCs and Weighting Factors for the Secondary
Metals Industry - Copper Brass and Bronze Casting
SCC
3-04-002-15
3-04-002-17
3-04-002-19
3-04-002-21
3-04-002-24
Description
Reverberatory - Brass & Bronze
Rotary - Brass & Bronze
Crucible & Pot - Brass & Bronze
Electric Arc - Brass & Bronze
Electric Induction - Brass & Bronze
Weighting
Factors
36
300
21
11
20
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Table 3.21-5. SO2 Emission Factors SCCs and Weighting Factors for the
Primary Metals Industry - Copper Smelting
sec
3-03-005-03
3-03-005-07
3-03-005-10
3-03-005-25
3-03-005-26
3-03-005-
Description
Multi-Hearth + Reverb. Furnace + Converters
Reverb. Furnace + Converters
Electric Furnace + Converters
Fluid Bed Roaster + Reverb. Furn. + Converters
Flash Furnace + Cleaning Furnace + Converter
Fluid Bed + Electric Arc + Converters
1981
Capacity
405
430
212
124
18
115
Table 3.21-6. SO2 Emission Factors SCCs and Weighting Factors for the
Primary Metals Industry - Copper Converting
sec
3-03-005-23
3-03-005-24
3-03-005-25
3-03-005-26
3-03-005-27
3-03-005-28
Description
Reverberatory Furnace + Converter
Multi-Hearth + Reverb. + Converter
Fluid Bed Roaster + Reverb. + Converter
Electric Arc + Converter
Flash Furn. + Cleaning Furn. + Converter
Noranda Reactor + Converter
Weighting
Factor
405
448
212
124
115
231
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3.22
METALS PROCESSING - FERROUS: 05-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(05) METALS PROCESSING
Tier II Category
(02) Ferrous
Tier II Subcategory
Iron and Steel Manufacturing
Primary Metals Industry -
ferroalloys
Secondary Metals Industry - grey
iron and steel foundries
3.22.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators for all processes, except for iron and steel industry processes
were expressed in thousand short tons and emission factors were expressed in metric pounds/short ton.
For iron and steel industrial processes emitting PM-10 and TSP, the activity indicators were expressed in
million short tons and the emission factors were expressed in metric pounds/short ton. All control
efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.22-1.
PM-10 Emissionsyear = PM-10 Emissions 1975
TSP Emissionsyear
TSP Emissions
(Eq. 3.22-1)
1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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3.22.2 Activity Indicator
3.22.2.1 CO Emissions
The activity indicator for cupola furnaces in iron foundries was based on the combined quantity of
scrap and pig iron consumed by cupola furnaces. This value was obtained from Reference la under the
category of iron foundries and miscellaneous users. The final activity was determined by adjusting this
production value to account for the fact that the emission factor used for this subcategory was in terms of
the charged quantity and not the fresh feed quantity. This adjustment required dividing the production
value by 0.78 to account for recycling.
The activity indicator for by-product coke from steel manufacturing was the oven production figure,
expressed in thousand short tons, from Reference 2a.
The activity indicator for steel manufacturing blast furnaces was the total pig iron production
including exports obtained from Reference 2b.
The activity indicator for steel manufacturing sintering was one-third of the total production of pig
iron obtained from Reference 2 or Reference 3.
The activity indicators for steel manufacturing open hearth and electric arc furnace types were based
on the total scrap and pig iron consumption. Reference 1 contained the total scrap and pig iron
consumed by each of three furnace types (including basic oxygen) by manufacturers of pig iron and raw
steel and castings. The fraction of combined quantity of scrap and pig iron consumed by each of the three
furnace types was calculated. The total raw steel production reported in Reference 2b was multiplied by
the fractions for the open hearth and electric arc furnaces to obtain the raw steel production for these two
furnace types.
3.22.2.2 NOX Emissions
The activity indicator for open hearth furnaces used in iron and steel manufacturing was based on the
total scrap and pig iron consumption. Reference 1 contained the total scrap and pig iron consumed by
each of the three furnace types (open hearth, basic oxygen, and electric arc) by manufacturers of pig iron
and raw steel and castings. The fraction of the combined quantity of scrap and pig iron consumed by
each of the three furnace types was calculated. The total raw steel production reported in Reference 2b
was multiplied by the open hearth fraction to obtain the raw steel production for this furnace type.
The activity indicator for roll and finish processes in iron and steel manufacturing was the total raw
steel production obtained from Reference 2a.
3.22.2.3 PM-10 and TSP Emissions
3.22.2.3.1 Iron and Steel Industry —
The activity indicator for by-product coke was the oven or by-product production figure from
Reference 2a. The same activity indicator was used for coal preparation and coke handling.
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The activity indicator for blast furnaces was the total pig iron production obtained from Reference
2b. This value included exports.
The activity indicators for windbox, discharge, and sinter-fugitive processes were based on the total
production of pig iron obtained from Reference 2 or Reference 3. The activity indicator for each process
was one-third of this production value.
The activity indicators for open hearth, basic oxygen, and electric arc furnaces were based on the
total scrap and pig iron consumption. Reference 1 contained the total scrap and pig iron consumed by
each furnace type by manufacturers of pig iron and raw steel and castings. The fraction of the combined
quantity of scrap and pig iron consumed by each furnace type was calculated. The total raw steel
production reported in Reference 2b was multiplied by each fraction to obtain the raw steel production
for each furnace type. These final results were used as the activity indicators for the both "stack" and
"fugitive" subcategories of each furnace type.
The activity indicator for slag blast furnaces was the total quantity of iron blast furnace slag sold
reported in Reference 4. The same reference was used to obtain the total quantity of steel slag sold. This
value was used as the activity indicator for slag steel furnaces.
The activity indicator for scarfing was one-third of the total raw steel production obtained from
Reference 2b.
The activity indicators for teeming, soaking pits, reheat furnaces, and open dust were the total raw
steel production reported in Reference 2b.
The activity indicator for ore screening was the total consumption of iron ore and agglomerates
obtained from Reference 3.
3.22.2.3.2 Primary Metals Industry (ferroalloys) —
The activity indicator for ferrosilicon was the net gross weight production obtained from Reference
5a. The silicon manganese activity indicator was assumed to be 42.1 percent of the net production of
ferrosilicon. The activity indicator for the ferromanganese, electric furnaces was assumed to be 57.9
percent of the net production of ferrosilicon. For the ferromanganese, blast furnace, the activity indicator
was assumed to be zero.
The activity indicator for silicon metal was the production value obtained from Reference 6a. The
activity indicator for other ferroalloys was the sum of the gross weight production figures for chromium
alloys, ferrocolumbium, ferrophosphorus and other ferroalloys as reported in Reference 5a. For
ferroalloy material handling, the total gross weight production of all ferroalloys obtained from Reference
5 a was used as the activity indicator.
3.22.2.3.3 Secondary Metals Industry —
The activity indicator for cupola furnaces at grey iron foundries was based on the combined quantity
of scrap and pig iron consumed by cupola furnaces. This value was obtained from Reference la under
the category of iron foundries and miscellaneous users. The final activity was determined by adjusting
this production value to account for the fact that the emission factor was in terms of the charged quantity
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and not the fresh feed quantity. This adjustment required dividing the production value by 0.78 to
account for recycling.
The activity indicator for electric induction furnaces at grey iron foundries was based on the
combined quantity of iron and steel scrap and pig iron consumed in electric furnaces. This value was
obtained from Reference la under the category of iron foundries and miscellaneous users. The final
activity indicator was adjusted to account for recycling by dividing the consumption value by 0.78 to
account for recycling.
The activity indicator for iron fugitive processes at grey iron foundries was the sum of the activity
indicators for the cupola and electric induction furnaces.
The activity indicators for electric arc and steel-fugitive processes at steel foundries were both based
on the combined quantity of iron and steel scrap and pig iron consumed. This value was obtained from
Reference la under the category of manufacturers of steel casting. The final activity indicators used were
the consumption value divided by 0.78 to account for recycling.
3.22.2.4 SO2 Emissions
The activity indicator for coking in iron and steel manufacturing was the oven production figure
obtained from Reference 2a.
The activity indicators for sintering in iron and steel manufacturing was based on the total
production of pig iron obtained from Reference 2 or Reference 3.
The activity indicator for open hearth furnaces in iron and steel manufacturing was based on the total
scrap and pig iron consumption. Reference 1 contained the total scrap and pig iron consumed by each
furnace type (open hearth, basic oxygen, and electric arc) by manufacturers of pig iron and raw steel and
castings. The fraction of the combined quantity of scrap and pig iron consumed by each of the three
furnace types was calculated. Total raw steel production reported in Reference 2b was multiplied by the
fraction for open hearth furnaces to obtain the raw steel production for this furnace type.
The activity indicator for roll and finish processes was the total raw steel production obtained from
Reference 2b.
3.22.2.5 VOC Emissions
The activity indicator for by-product coke was the oven production figure obtained from Reference
2a. The activity indicator for sintering was based on the total production of pig iron obtained from
Reference 2 or Reference 3.
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3.22.3 Emission Factor
3.22.3.1 CO Emissions
The emission factor for iron foundries (SCC 3-04-003-01) was obtained from Reference 7a.
The emission factor for by-product coke from steel manufacturing was the sum of the emission
factors for three separate processes: charging (SCC 3-03-003-02), pushing (SCC 3-03-003-03) and
oven/door leaks (SCC 3-03-003-08). These emission factors were obtained from Reference 7b. The
units of the emission factor were changed from quantity of coal charged to quantity of coke produced by
using the relationship that one ton of coal charged produces 0.7 tons of coke.
The emission factors for steel manufacturing windbox sintering (SCC 3-03-008-13), basic oxygen
furnaces (SCC 3-03-009-13 and 3-03-009-14), and electric arc furnaces (SCC 3-03-009-04 and 3-03-
009-08) were obtained from Reference 7c.
The uncontrolled emission factor for steel manufacturing blast furnaces was obtained from Reference
8a. The control emission factor was calculated by applying the control efficiency as shown in Equation
3.22-2.
EFcontrolled = EFuncontrolled X 0 ~ CE) (Eq. 3.22-2)
where: EF = emission factor
CE = control efficiency
For the years 1970 through 1984, the control efficiency for blast furnaces was assumed to the 0.999. The
control efficiencies for the years 1960, 1950, and 1940 were 0.995, 0.990, and 0.975, respectively.
3.22.3.2 NOX Emissions
3.22.3.2.1 Iron and Steel Industry —
The emission factor for open hearths was calculated by dividing the emissions by the operating rate
as reported in Reference 9.
The emission factor for roll and finish was based on the emissions from the fuels used in this process
divided by the process operating rate. The fuels used in this process were coke oven gas, residual oil, and
natural gas. The emissions from roll and finish processes were assumed to be the difference between the
total NOX emissions from iron and steel processes and the NOX emissions from open hearth furnaces.
The total NOX emissions from all iron and steel processes using coke oven gas, residual oil, and
natural gas were the sum of the separate emissions from the three fuels. Emissions were calculated by
multiplying the quantity of fuel consumed by the fuel specific emission factor. The quantity of coke oven
gas consumed by iron and steel processes was assumed to be 40 percent of the total annual coke oven gas
production as reported in Reference 10. The quantity of residual oil consumed was calculated by
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multiplying the quantity of raw steel production obtained from Reference 2b by a factor converting tons
of steel produced to the gallons of residual oil consumed (0.00738 x 106 gal/103 ton steel). The quantity
of natural gas consumed was calculated in the same manner as was the quantity of residual oil consumed,
except that a conversion factor of 4.25 x 106 cu. ft gas consumed/103 ton steel was used.
The NOX emission factor for the combustion of coke oven gas was obtained from Reference 7. The
emission factors for the combustion of residual oil, and natural gas were obtained from Reference 7h
(industrial boilers) and 7i (small industrial boilers), respectively. Based on these emission factors and the
fuel consumption data, the NOX emissions from the combustion of coke oven gas, residual oil, and natural
gas were calculated.
The sum of these emissions was the total NOX emissions from the iron and steel processes. The
quantity of emissions from the open hearth furnaces was calculated by multiplying the activity indicator
by the emission factor. The origin of these data were described earlier in this section. The difference
between the total NOX emissions and the open hearth furnace emissions was assumed to be the emissions
from the roll and finish process. The emission factor for this process was calculated by dividing the
emissions by the total steel produced obtained from Reference 1 la.
3.22.3.3 PM-10 and TSP Emissions
3.22.3.3.1 Iron and Steel Industry —
The PM-10 and TSP emission factors for by-product coke were based on the sum of the emission
factors for following six SCCs: 3-03-003-02, 3-03-003-03, 3-03-003-04, 3-03-003-06, 3-03-003-08, and
3-03-003-14. The TSP emission factors for these SCCs were obtained from Reference 7b, with the
exception of SCC 3-03-003-04. The emission factor for this SCC was obtained from Reference 8b. The
PM-10 emission factors of the six SCCs were obtained from Reference 12. The sum of these emission
factors for PM-10 and TSP were divided by 0.7 to convert the emission factors from the amount of coal
charged to the amount of coke produced.
The TSP emission factor for coal preparation and coke handling was obtained from Reference 7.
The PM-10 emission factor was obtained from Reference 13. The TSP emission factors for the beehive
process for the years 1940 through 1975 were obtained from Reference 7. The PM-10 emission factors
for this process for all years and the TSP emission factor after 1975 were assumed to be zero.
The TSP emission factors for blast furnaces were the sum of the emission factors reported in
Reference 14a for the SCCs 3-03-008-01 and 3-03-008-02. The PM-10 emission factors for these two
SCCs were obtained from Reference 12.
The emission factors for windbox (SCC 3-03-0080-13) and discharge (SCC 3-03-008-14) were
obtained from Reference 7d for TSP and from Reference 12 for PM-10. The windbox emission factors
were after coarse particle removal. The emission factors for fugitive processes (SCC 3-03-008-19) were
obtained from Reference 13 for TSP and from Reference 12 for PM-10.
The TSP emission factor for the open hearth furnaces, stack subcategory (SCC 3-03-009-01) was
obtained from Reference 7d. The open hearth furnace, fugitive subcategory TSP emission factor was
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obtained from Reference 14. The PM-10 emission factors for these sources were obtained from
Reference 12.
The TSP emission factor for the basic oxygen furnaces, stack subcategory (SCC 3-03-009-13) was
obtained from Reference 7d. The basic oxygen furnace, fugitive subcategory TSP emission factor was
obtained from Reference 13. The PM-10 emission factors for these sources were obtained from
Reference 12.
The emission factors for the electric arc furnaces, stack subcategory were based on the emission
factors for carbon steel, stack (SCC 3-03-009-04) and alloy steel, stack (SCC 3-03-009-08) obtained
from Reference 7d for TSP and from Reference 12 for PM-10. Weighted average PM-10 and TSP
emission factors were calculated from these emission factors. Weighting factors were the relative
production levels of carbon and alloy steel as reported in Reference 1 la. For the electric arc furnace,
fugitive subcategory, PM-10 and TSP emission factors were obtained from Reference 12 and Reference
13, respectively.
The PM-10 and TSP emission factors for slag blast furnaces and steel furnaces were obtained from
Reference 12 and Reference 13, respectively.
The emission factors for scarfing (SCC 3-03-009-32) were obtained from Reference 7d for TSP and
from Reference 12 for PM-10.
The PM-10 and TSP emission factors for teeming, soaking pits, reheat furnaces, open dust, and ore
screening were obtained from Reference 12 and Reference 13, respectively.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
3.22.3.3.2 Primary Metals Industry (ferroalloys) —
The emission factors for ferrosilicon were based on the emission factors for the following three
electric smelting processes: 50 percent Fe Si (SCC 3-03-006-01), 75 percent Fe Si (SCC 3-03-006-02),
and 90 percent Fe Si (SCC 3-03-006-03). The TSP emission factors for these processes were obtained
from Reference 7e. The PM-10 emission factors were obtained from Reference 12. Weighed averages of
these PM-10 and TSP emission factors were calculated using ferrosilicon production levels obtained from
Reference 6 as weighting factors.
The PM-10 and TSP emission factors for silicon manganese (SCC 3-03-006-05), ferromanganese,
electric furnaces (SCC 3-03-007-01), and silicon metal (SCC 3-03-006-04) subcategories were obtained
from Reference 7e and Reference 12, respectively. The activity for ferromanganese, blast furnaces was
assumed to be zero and, therefore, no emission factor was necessary. The emission factors for other
ferroalloys and ferroalloy material handling were obtained from Table 3.1-3 of this report. The emission
factors for other ferroalloys were based on engineering judgement and those for ferroalloy material
handling were based on data from Reference 15.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
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3.22.3.3.3 Secondary Metals —
The PM-10 and TSP emission factors for cupola furnaces (SCC 3-04-003-01) and electric induction
furnaces (SCC 3-04-003-03) at grey iron foundries were obtained from Reference 7f. The emission
factors for fugitive processes were the sum of the emission factors for all processes reported emitting to
the atmosphere in Reference 8c. It was assumed that the magnesium treatment applied to only 20 percent
of the production. The PM-10 emission factor for fugitive processes was obtained from Reference 12 or
Table 3.1-3 of this report.
The PM-10 and TSP emission factors for steel foundries electric arc furnaces (SCC 3-04-007-01) at
steel foundries were obtained from Reference 7g. The TSP emission factor for fugitive processes was the
sum of the emission factors for all processes, except for magnesium treatment, reported emitting to the
atmosphere in Reference 8c. The PM-10 emission factor for fugitive processes was obtained from
Reference 12 or Table 3.1-3 of this report.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
3.22.3.4 SO2 Emissions
The emission factor for coking in iron and steel manufacturing was based on the emission factors for
six processes. Charging (SCC 3-03-003-02) and interfering (SCC 3-03-003-06) emission factors were
obtained from Reference 7b. Emission factors for pushing (SCC 3-03-003-03), quenching (SCC 3-03-
003-04), oven/door leaks (SCC 3-03-003-08) and topside leaks (SCC 3-03-003-14) were obtained from
Reference 12. Emission factors from all six processes were summed and the result was multiplied by 0.7
to convert the factors from the amount of coal consumed to the amount of coke produced.
The emission factor for sintering in iron and steel manufacturing was calculated by dividing the
emissions by the production rate as reported in Reference 9. This same procedure was used to calculate
the open hearth emission factor.
The emission factor for roll and finish in iron and steel manufacturing was based on the emissions
from the fuels used in this process divided by the process operating rate. The fuels used in this process
were coke oven gas and residual oil. The emissions from the roll and finish process were assumed to be
the difference between the total SO2 emissions from iron and steel processes and the SO2 emissions from
open hearth furnaces.
Total SO2 emissions from all iron and steel processes using coke oven gas and residual oil were the
sum of the separate emissions from the two fuels. The emissions were calculated by multiplying the
quantity of fuel consumed by the fuel specific emission factor. The quantity of coke oven gas consumed
by the iron and steel processes was assumed to be 40 percent of the total annual coke oven gas
production as reported in Reference 10. The quantity of residual oil consumed was calculated by
multiplying the quantity of raw steel production obtained from Reference 2b by a factor converting tons
of steel produced to the gallons of residual oil consumed (0.00738 x 106 gal/103 ton steel).
The SO2 emission factor for the combustion of coke oven gas was obtained from Reference 7. The
emission factor for the combustion of residual oil was obtained from Reference 7i and multiplied by the
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sulfur content obtained yearly for No. 6 fuel oil from Reference 16. Based on these emission factors and
the fuel consumption data, the SO2 emissions from the combustion of coke oven gas and residual oil were
calculated.
Summing of these emissions resulted in the total SO2 emissions from the iron and steel processes.
The quantity of emissions from the open hearth furnaces was calculated by multiplying the activity
indicator by the emission factor. The origin of these data were described earlier in this section. The
difference between total SO2 emissions and open hearth furnace emissions was assumed to be the
emissions from the roll and finish processes. The emission factor for this process was calculated by
dividing the emissions by the quantity of raw steel produced obtained from Reference 9.
3. 22. 3. 5 VOC Emissions
The emission factor for coking was based on the emission factors for six processes. Charging (SCC
3-03-003-02) and pushing (SCC 3-03-003-03), and oven/door leaks (SCC 3-03-003-08) emission factors
were obtained from Reference 7b. Emission factors for quenching (SCC 3-03-003-04), interfering (SCC
3-03-003-06) and topside leaks (SCC 3-03-003-14) were obtained from Reference 17. The emission
factors from all six processes were summed and the result was multiplied by 0.7 to convert the factors
from the amount of coal consumed to the amount of coke produced.
The VOC emission factor for windbox sintering (SCC 3-03-008-13) was obtained from
Reference 17.
3.22.4 Control Efficiency
The control efficiencies for several processes were derived from the actual and uncontrolled
emissions reported in Reference 18 or Reference 19 using Equation 3.22-3.
(E,. 3.22-3)
where: CE = control efficiency
UE = uncontrolled emissions
AE = actual emissions
3.22.4.1 CO Emissions
The control efficiency for iron foundries was derived from Reference 18 or Reference 19 using
Equation 3.22-3.
The control efficiency for steel manufacturing basic oxygen furnaces was computed from Reference
18 or Reference 19 using Equation 3.22-3. For blast furnaces, the percentage control efficiency was
assumed to be 99.9 percent. This was taken into account in the calculation of the CO emission factor
and, therefore, no separate control efficiency was used. For all other steel manufacturing processes, no
control efficiencies were applied to the activity data to estimate the CO emissions.
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3.22.4.2 NOX Emissions
No control efficiencies were applied to the activity data to estimate NOX emissions from the iron and
steel manufacturing processes included in this Tier II category.
3.22.4.3 PM-10 and TSP Emissions
3.22.4.3.1 Iron and Steel Industry —
The TSP control efficiencies for by-product coke production were derived from Reference 18 or
Reference 19 using Equation 3.22-3. The control efficiencies for the beehive process for the years 1940,
1950, 1960, and 1970 through 1975 and for coal preparation/coke handling processes for the years 1976
through 1984 were based on the estimated control efficiency reported in Reference 13. These TSP
control efficiencies were adjusted according to engineering judgement.
The PM-10 control efficiencies for by-product coke production for the years 1975 through 1984
were based on the 1985 PM-10 control efficiency obtained from Reference 20. During these years, any
changes in the TSP control efficiencies from the 1985 TSP control efficiency value were reflected in the
PM-10 control efficiencies. For the years 1940 through 1974, no control efficiencies were used to
estimate the PM-10 emissions from by-product coke production. No control efficiencies were applied to
the activity data to estimate PM-10 emissions from the beehive process or the coal preparation/coke
handling processes.
For blast furnaces, the TSP control efficiencies for the years 1973 through 1984 were assumed to
0.996. No procedure for determining the control efficiencies for the years 1940, 1950, 1960, and 1970
through 1972 is currently available. The PM-10 control efficiencies for the years 1975 through 1984
were equal to the 1985 PM-10 control efficiency obtained from Reference 20. For the years 1940
through 1974, no control efficiencies were used to estimate PM-10 emissions from blast furnaces.
The TSP control efficiencies for the windbox and discharge processes were derived from Reference
18 or Reference 19 using Equation 3.22-3. The control efficiencies for sinter-fugitive processes were
based on the estimated control efficiency reported in Reference 13. This control efficiency was adjusted
annually based on engineering judgement. The PM-10 control efficiencies for these three processes for
the years 1975 through 1984 were based on the 1988 PM-10 control efficiencies obtained from Reference
20. During these years, any changes in the corresponding TSP control efficiencies from the 1985 TSP
control efficiency value were reflected in the PM-10 control efficiencies. For the years 1940 through
1974, no control efficiencies were used to estimate PM-10 emissions.
The TSP control efficiencies for the stack processes of open hearth, basic oxygen, and electric arc
furnaces were derived from Reference 18 or Reference 19 using Equation 3.22-3. The control
efficiencies for the fugitive processes of the basic oxygen and electric arc furnaces were based on the
estimated control efficiencies reported in Reference 13. The control efficiency for the fugitive processes
of the basic oxygen furnace was assumed to be zero for all years.
The PM-10 control efficiencies for the stack processes of these three furnace types for the years
1975 through 1984 were based on the 1988 PM-10 control efficiencies obtained from Reference 20.
During these years, any changes in the corresponding TSP control efficiencies from the 1985 TSP control
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efficiency value were reflected in the PM-10 control efficiencies. For the years 1940 through 1974, no
control efficiencies were used to estimate PM-10 emissions. No control efficiencies were applied to the
activity data to estimate PM-10 emissions from the fugitive processes of all three furnace types.
The TSP control efficiencies for slag blast and slag steel furnaces were based on the estimated
control efficiencies reported in Reference 13. The yearly variations in these control efficiencies are
assumed to be the results of adjustments made based on engineering judgement.
The PM-10 control efficiencies for slag steel furnaces for the years 1975 through 1984 were based
on the 1988 PM-10 control efficiency obtained from Reference 20. During these years, any changes in
the TSP control efficiencies from the 1985 TSP control efficiency value were reflected in the PM-10
control efficiencies. For the years 1940 through 1974, no control efficiencies were use to PM-10
emissions. No control efficiencies were applied to the activity to estimate PM-10 emissions from slag
blast furnaces.
The TSP control efficiencies for scarfing were derived from Reference 18 or Reference 19 using
Equation 3.22-3. The PM-10 control efficiencies for the years 1975 through 1984 were based on the
1988 PM-10 control efficiency obtained from Reference 20. During these years, any changes in the TSP
control efficiencies from the 1985 TSP control efficiency value were reflected in the PM-10 control
efficiencies. For the years 1940 through 1974, no control efficiencies were use to estimate PM-10
emissions for scarfing.
No control efficiencies were applied to the activity data to estimate PM-10 and TSP emissions from
teeming, soaking pits, and reheat furnaces.
The TSP control efficiencies for open dust and ore screening were based on the estimated control
efficiencies reported in Reference 13. The yearly variations in these control efficiencies are assumed to be
the results of adjustments made based on engineering judgement. No control efficiencies were applied to
the activity data to estimate PM-10 emissions from open dust and ore screening.
3.22.4.3.2 Primary Metals Industry (ferroalloys) —
The TSP control efficiencies for all production processes, except other ferroalloy production and
ferroalloy material handling processes were derived from Reference 18 or Reference 19 using
Equation 3.22-3. The TSP control efficiencies for ferroalloy production and ferroalloy material handling
processes were based on engineering judgment.
The PM-10 control efficiencies for ferrosilicon, silicon manganese, and silicon metal production and
the ferromanganese electric furnace for the years 1975 through 1984 were based on the 1988 PM-10
control efficiencies obtained from Reference 20. During these years, any changes in the corresponding
TSP control efficiencies from the 1985 TSP control efficiency value were reflected in the PM-10 control
efficiencies. For the years 1940 through 1974, no control efficiencies were used to estimate PM-10
emissions.
No control efficiencies were applied to the activity data to estimate PM-10 emissions from
ferromanganese blast furnace, other ferroalloy production, and ferroalloy material handling processes.
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3.22.4.3.3 Secondary Metals Industry —
The TSP control efficiencies for all grey iron and steel foundry processes were derived from
Reference 18 or Reference 19 using Equation 3.22-3.
The PM-10 control efficiencies for all grey iron and steel foundry processes, excluding the fugitive
processes for the years 1975 through 1984 were based on the 1988 PM-10 control efficiencies obtained
from Reference 20. During these years, any changes in the corresponding TSP control efficiencies from
the 1985 TSP control efficiency value were reflected in the PM-10 control efficiencies. For the years
1940 through 1974, no control efficiencies were used to estimate PM-10 emissions.
No control efficiencies were applied to the activity data to estimate PM-10 emissions from the
fugitive processes of grey iron and steel foundries.
3.22.4.4 SO2 Emissions
No control efficiencies were applied to the activity data to estimate SO2 emissions from the iron and
steel manufacturing processes included in this Tier II category.
3.22.4.5 VOC Emissions
No control efficiencies were applied to the activity data to estimate VOC emissions from the by-
product coke and sintering processes included in this Tier II category.
3.22.5 References
1. Minerals Industry Surveys, Iron and Steel Scrap. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Monthly.
(a) Table on consumption of iron and steel scrap and pig iron in the United States by type of
furnace or other use.
2. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC.
(a) Table containing information on "Petroleum, Coal, and Products."
(b) Table containing information on "Metals and Manufactures."
3. Minerals Industry Surveys, Iron Ores. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Monthly.
4. Minerals Yearbook, Slag Iron and Steel. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Annual.
5. Minerals Yearbook, Ferroalloys. Bureau of Mines, U.S. Department of the Interior, Washington,
DC. Annual.
(a) Table entitled, "Table 2. Ferroalloys Produced and Shipped from Furnaces in the U.S."
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6. Minerals Yearbook, Silicon. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
(a) "Table 1. Production, Shipments, and Stocks of... and Silicon Metal in the U.S. in 19xx"
7. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 7.10-3
b. Volume I, Table 7.2-1
c. Volume I, Table 7.5-3
d. Volume I, Table 7.5-1
e. Volume I, Table 7.4-3
f. Volume I, Table 7.10-2
g. Volume I, Table 7.13-1
h. Volume I, Table 1.3-1
i. Volume I, Table 1.4-1
8. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Volume I, Table 7.5-1, Supplement 11, October 1980
b. Volume I, Table 7.2-1, Supplement 11, October 1980
c. Volume I, Table 7.10-2, Supplement 11, October 1980
9. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park, NC. February 9, 1980.
10. Quarterly Coal Report: January - March. DOE/EIA-0121(xx/lQ). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Quarterly.
11. Minerals Yearbook, Iron and Steel. Bureau of Mines, U.S. Department of the Interior, Washington,
DC. Annual.
(a) Table 1, Salient Iron and Steel Statistics.
12. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
13. Internal Memorandum from Walt Barber to David Hawkins on Final Fugitive Emission Factors
derived by Joint EPA/AISI Study. U.S. Environmental Protection Agency. November 6, 1978.
14. Compilation of Air Pollutant Emission Factors, Second Edition, Supplements 1 through 14, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC.
a. Volume I, Part B, Table 7.5-1
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15. Summary of Paniculate and Sulfur Oxide Emission Reductions Achieved National for Selected
Industrial Source Categories. EPA-340/1 -76-0086. U.S. Environmental Protection Agency.
Washington, DC. November 1976.
16. Heating Oils. U.S. Department of Energy. Obtainable from the National Institute for Petroleum
and Energy Research, ITT Research Institute, P.O. Box 2128, Bartlesville, OK. Annual.
17. Criteria Pollutant Emission Factors for the 1985 NAPAP Emissions Inventory
18. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
19. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
20. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.23 METALS PROCESSING - NOT ELSEWHERE CLASSIFIED: 05-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(05) METALS PROCESSING (03) Metals Processing not Mining Operations (iron ore
elsewhere classified (NEC) mining, taconite processing,
bauxite crushing, copper ore
crushing, zinc ore crushing, and
lead ore crushing)
3.23.1 Technical Approach
The PM-10 and TSP emissions included in this Tier category were the sum of the emissions from the
source categories listed above. Emissions were estimated only for particulate matter from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in thousand short tons and emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1992 for TSP and for the years
1975 through 1984 for PM-10. For some source categories, the PM-10 emissions exceeded the TSP
emissions as calculated by the procedures presented in this section. Because this represents a physical
impossibility, a more realistic estimate of the PM-10 emissions was assumed to be the TSP emissions
value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.23-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.23-1)
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.23.2 Activity Indicator
The activity indicator for iron ore mining was the total quantity of crude iron ore mined obtained
from Reference 1. The activity indicator for taconite processing was the quantity of pellet production
(agglomerates) obtained from Reference la. The activity indicator for bauxite crushing was the
consumption of crude and dried bauxite (domestic and foreign ores combined) reported in Reference 2.
The activity indicator for copper ore crushing was the gross weight of copper ore produced on a dry
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weight basis obtained from Reference 3a. The activity indicator for zinc ore crushing was the gross
weight of zinc ore produced on a dry weight basis reported in Reference 4a. The activity indicator for
lead ore crushing was the gross weight of lead ore produced on a dry weight basis obtained from
Reference 4.
3.23.3 Emission Factor
The TSP emission factors for iron ore mining were obtained from Reference 5. The TSP emission
factors for taconite processing were the sum of the emission factors for nine individual processes obtained
from Reference 6a. The processes and SCCs are listed in Table 3.23-1. The TSP emission factors were
obtained from Reference 6b for bauxite crushing (SCC 3-03-000-01). The PM-10 emission factors for
these sources were obtained from Reference 7.
The TSP emission factors for zinc ore crushing and lead ore crushing were obtained from Reference
6c. The PM-10 emission factors were obtained from Reference 7 or Table 3.1-3 of this report.
The emission factors for copper ore crushing were the sum of the emission factors for seven
individual processes. These processes and the corresponding SCCs are listed in Table 3.23-2. The TSP
emission factors were obtained from Reference 5 with the exception of the copper ore crushing emission
factors which were obtained from Reference 6c. The PM-10 emission factors for all seven processes
were obtained from Reference 7 or Table 3.1-3 of this report.
3.23.4 Control Efficiency
The TSP control efficiencies for taconite processing and bauxite crushing were derived from
Reference 8 or Reference 9 using Equation 3.23-2.
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
The TSP control efficiencies for copper, zinc, and lead ore crushing were based on engineering
judgment. No additional basis for the yearly variations in these control efficiencies is currently available.
The PM-10 control efficiencies for taconite processing and bauxite crushing for the years 1975
through 1984 were based on the 1988 PM-10 control efficiencies obtained from Reference 10. During
these years, any changes in the corresponding TSP control efficiencies from the 1985 TSP control
efficiency value were reflected in the PM-10 control efficiencies. For the years 1940 through 1974, no
control efficiencies were used to estimate PM-10 emissions.
No control efficiencies were applied to the activity data to estimate PM-10 emissions from iron ore
mining and copper, zinc, and lead ore crushing.
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3.23.5 References
1. Minerals Yearbook, Iron Ore. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
a. Table entitled, "Usable Iron Ore Produced in the U.S. in 19xx by District, State, & Type of
Product."
2. Minerals Yearbook, Bauxite and Alumina. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Annual.
3. Minerals Yearbook, Copper. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
a. Table entitled, "Salient Copper Statistics."
4. Minerals Yearbook, Lead. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
a. Table entitled, "Production of Lead and Zinc in Terms of Recoverable Metals, in U.S. in 19xx,
by State."
5. Assessment of Fugitive Paniculate Emission Factors for Industrial Processes. EPA-450/3-78-107.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1978.
6. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 8.22-1
b. Volume I, Table 7.1-2
c. Volume I, Table 7.18-1
7. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
8. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
9. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
10. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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Table 3.23-1. PM-10 and TSP Emission Factor
SCCs for Taconite Processing
SCC Description
3-03-023-01 Primary Crushing
3-03-023-02 Fines Crushing
3-03-023-04 Ore Transfer
3-03-023-07 Bentonite Storage
3-03-023-08 Bentonite Blending
3-03-023-09 Traveling Grate Feed
3-03-023-10 Traveling Grate Discharge
3-03-023-12 Indurating Furnace
3-03-023-16 Pellet Transfer
Table 3.23-2. PM-10 and TSP Emission Factor
Processes for Copper Ore Crushing
Description
Open pit/overburden removal
Drill/blast
Loading
Truck dumping
Transfer/conveying
Copper Ore Crushing
Storage
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3.24 PETROLEUM AND RELATED INDUSTRIES - OIL AND GAS PRODUCTION: 06-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(06) PETROLEUM AND (01) Oil and Gas Production Petroleum Marketing and
RELATED INDUSTRIES Production - crude oil and
natural gas
Sulfur Recovery Plants - natural
gas fields
3.24.1 Technical Approach
The SO2 and VOC emissions included in this Tier category were the sum of the emissions from the
source categories listed above. Emissions were estimated only for SO2 and VOC from an activity
indicator and emission factor. In order to utilize these values in the Trends spreadsheets, the activity
indicator for SO2 emissions from natural gas fields was expressed in thousand short tons and the emission
factor was expressed in metric pounds/short ton. For VOC emissions from crude oil production and
natural gas liquids, the activity indicators were expressed in millions barrels and the emission factors were
expressed in metric pounds/thousand barrels.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984 for both pollutants.
3.24.2 Activity Indicator
The activity indicator for the SO2 emissions from natural gas fields was the quantity of sulfur
recovered by natural gas plants obtained from Reference 1. The activity indicator for VOC emissions
from crude oil production was the total U.S. field production including lease condensate obtained from
Reference 2a. The activity indicator for VOC emissions from natural gas liquids category was the total
field production of natural gas plant liquids was obtained from Reference 2a.
3.24.3 Emission Factor
The SO2 emission factor for natural gas fields was based on the actual emissions for the SCCs 3-
01-032-01 through 3-01-032-04. These emission data were summed and divided by the sum of the
corresponding operating rates. All data was obtained from Reference 3 or Reference 4.
The VOC emission factor for crude oil production was obtained from Reference 5. The VOC
emission factor for natural gas liquids was obtained from Reference 5.
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3.24.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate the SO2 and VOC emissions
from the sources included in this Tier II category.
3.24.5 References
1. Minerals Industry Surveys, Sulfur. Bureau of Mines, U.S. Department of the Interior, Washington,
DC. Monthly.
2. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
(a) Table 1
3. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
4. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
5. Control Techniques for VOC Emissions from Stationary Sources. EPA-450/3-85-008. U.S.
Environmental Protection Agency, Research Triangle Park, NC. September, 1985.
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3.25 PETROLEUM AND RELATED INDUSTRIES - PETROLEUM REFINERIES AND
RELATED INDUSTRIES: 06-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(06) PETROLEUM AND (02) Petroleum Refineries and FCC, TCC, and Flares
RELATED INDUSTRIES Related Industries Sulfur Recovery
Compressors
Blow Down Systems
Process Drains
Vacuum Jets and Cooling
Towers
3.25.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators for CO, NOX, PM-10, TSP, and SO2 emissions were expressed in
thousand short tons and emission factors were expressed in metric pounds/short ton. For VOC
emissions, activity indicators were expressed in millions barrels and emission factors were expressed in
metric pounds/thousand barrels. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.25-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 325-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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3.25.2 Activity Indicator
3.25.2.1 CO Emissions
The activity indicators for Fluid Catalytic Cracking (FCC) and Thermal Catalytic Cracking (TCC)
units in petroleum refineries were based on the separate FCC and TCC capacities. The TCC capacity was
obtained from Reference 1 as the value reported in the "other" category for cnt cracking fresh feed
charge capacity. (Sum of values for individual refineries.) The FCC capacity was not available directly,
but was calculated as the difference between the total capacity and the TCC capacity. Total capacity of
catalytic cracking fresh feed in bbl/stream day was obtained from Reference 1. This value was converted
to bbl/calendar year by multiplying by 328.5 (365 days/year x 0.9 calendar day/stream day).
The FCC and TCC capacities were converted to throughput data using the refinery operating ratio.
This ratio was obtained from Reference 2a and converted to a percentage. Capacities were multiplied by
this refinery operating percentage to obtain the corresponding throughputs. The FCC and TCC
throughputs were used as the activity indicators.
3.25.2.2 NOX Emissions
The activity indicators for FCC and TCC in petroleum refineries were based on the separate FCC
and TCC capacities. The TCC capacity was obtained from Reference 1 as the value reported in the
"other" category for cnt cracking fresh feed charge capacity. (Sum of values for individual refineries.)
The FCC capacity was not available directly, but was calculated as the difference between total capacity
and TCC capacity. Total capacity of catalytic cracking fresh feed in bbl/stream day was obtained from
Reference 1. This value was converted to bbl/calendar year by multiplying by 328.5 (365 days/year x 0.9
calendar day/stream day).
The FCC and TCC capacities were converted to throughput data using the refinery operating ratio.
This ratio was obtained from Reference 2a and converted to a percentage. Capacities were multiplied by
this refinery operating percentage to obtain the corresponding throughputs. The FCC and TCC
throughputs were used as the activity indicators.
The activity indicator for flares in petroleum refineries was based on total refinery crude capacity in
bbl/calendar day obtained from Reference 1. This value was multiplied by 365 to convert it to an annual
value. The activity indicator was calculated by multiplying the capacity by the VOC control efficiency for
blow down systems, expressed as a percentage. The derivation of this control efficiency is described in
section 3.25.4.4.
3.25.2.3 PM-10 and TSP Emissions
The activity indicators for FCC and TCC in petroleum refineries were based on the separate FCC
and TCC capacities. The TCC capacity was obtained from Reference 1 as the value reported in the
"other" category. The FCC capacity was not available directly, but was calculated as the difference
between total capacity and TCC capacity. Total capacity of catalytic cracking fresh feed in bbl/stream
day was obtained from Reference 1. This value was converted to bbl/calendar year by multiplying by
328.5 (365 days/year x 0.9 calendar day/stream day).
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The FCC and TCC capacities were converted to throughput data using the refinery operating ratio.
This ratio was obtained from Reference 2a and converted to a percentage. Capacities were multiplied by
this refinery operating percentage to obtain the corresponding throughputs. The FCC and TCC
throughputs were used as the activity indicators.
3.25.2.4 SO2 Emissions
The activity indicator for sulfur recovery plants at refineries was the quantity of sulfur recovered by
petroleum refineries obtained from Reference 3.
The activity indicators for FCC and TCC in petroleum refineries were based on the separate FCC
and TCC capacities. The TCC capacity was obtained from Reference 1 as the value reported in the
"other" category. The FCC capacity was not available directly, but was calculated as the difference
between total capacity and TCC capacity. Total capacity of catalytic cracking fresh feed in bbl/stream
day was obtained from Reference 1. This value was converted to bbl/calendar year by multiplying by
328.5 (365 days/year x 0.9 calendar day/stream day).
The FCC and TCC capacities were converted to throughput data using the refinery operating ratio.
This ratio was obtained from Reference 2a and converted to a percentage. Capacities were multiplied by
this refinery operating percentage to obtain the corresponding throughputs. The FCC and TCC
throughputs were used as the activity indicators.
The activity indicator for flares in petroleum refineries was based on the total refinery crude capacity
in bbl/calendar day obtained from Reference 1. This value was multiplied by 365 to convert it to an
annual value. The activity indicator was calculated by multiplying the capacity by the VOC control
efficiency for blow down systems, expressed as a percentage. The derivation of this control efficiency is
described in section 3.25.4.4.
3.25.2.5 VOC Emissions
The activity indicators for FCC and TCC in petroleum refineries were based on the separate FCC
and TCC capacities. The TCC capacity was obtained from Reference 1 as the value reported in the
"other" category. The FCC capacity was not available directly, but was calculated as the difference
between total capacity and TCC capacity. Total capacity of catalytic cracking fresh feed in bbl/stream
day was obtained from Reference 1. This value was converted to bbl/calendar year by multiplying by
328.5 (365 days/year x 0.9 calendar day/stream day).
The FCC and TCC capacities were converted to throughput data using the refinery operating ratio.
This ratio was obtained from Reference 2a and converted to a percentage. Capacities were multiplied by
this refinery operating percentage to obtain the corresponding throughputs. The FCC and TCC
throughputs were used as the activity indicators.
The activity indicators for the petroleum refinery process operations of compressor, blow down
systems, process drains, cooling towers, and miscellaneous processes were the total crude capacity
reported in Reference 1. The capacity, expressed in bbl/calendar day, was multiplied by 365 to convert it
to an annual figure. The activity indicator for vacuum jets was the total vacuum distillation capacity
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obtained from Reference 1. The capacity, expressed in bbl/stream day, was multiplied by the following
factor to convert it to an annual value: 365 days/year x 0.95 calendar day/stream day.
3.25.3 Emission Factor
3.25.3.1 CO Emissions
The emission factors for FCC and TCC in petroleum refineries were obtained from Reference 4a for
SCCs 3-06-002-01 and 3-06-003-01, respectively. In this reference, TCC was categorized as moving-
bed catalytic cracking units.
3.25.3.2 NOX Emissions
The emission factors for FCC, TCC, and flares in petroleum refineries were obtained from Reference
4a for SCCs 3-06-002-01, 3-06-003-01, and 3-06-004-01, respectively. In this reference, TCC was
categorized as moving-bed catalytic cracking units and flares were categorized as blow down system with
vapor recovery.
3.25.3.3 PM-10 and TSP Emissions
The TSP emission factors for FCC and TCC in petroleum refineries were obtained from Reference
4a for SCCs 3-06-002-01 and 3-06-003-01, respectively. In this reference, TCC was categorized as
moving-bed catalytic cracking units. The PM-10 emission factors for these sources were obtained from
Reference 5. For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from these emission sources.
3.25.3.4 SO2 Emissions
The emission factor for sulfur recovery plants at refineries was based on SCCs 3-01-032-01 through
3-01-032-04. These emission data were summed and divided by the sum of the corresponding operating
rates. All data was obtained from Reference 6 or Reference 7.
The emission factors for FCC, TCC, and flares in petroleum refineries were obtained from Reference
4a for SCCs 3-06-002-01, 3-06-003-01, and 3-06-004-01, respectively. In this reference, TCC was
categorized as moving-bed catalytic cracking units and flares were categorized as blow down system with
vapor recovery.
3.25.3.5 VOC Emissions
The emission factors for FCC and TCC in petroleum refineries were obtained from Reference 1.
These emission factors were converted to a reactive basis using the profile SDM 306002 obtained from
Reference 8.
The emission factors for the petroleum refinery process operations of blow down systems, process
drains, vacuum jets, cooling towers, and miscellaneous processes were obtained from Reference 1. The
emission factor for compressors was obtained from Reference 9.
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The emission factors were converted to a reactive basis using profiles from Reference 8, except for
the emission factor for vacuum jets for which the profile was obtained from Reference 10. Compressors,
blow down systems, process drains, and cooling towers were converted to a reactive basis using the
profiles SDM 202002, SDM 306009, SDM 306005, and SDM 306007, respectively, obtained from
Reference 8. The emission factor for miscellaneous processes was converted using the profiles SDM
306008A, 8P, 8Y 8Z (Aug), and 8N.
3.25.4 Control Efficiency
3. 25. 4. 1 CO Emissions
The control efficiencies for FCC and TCC in petroleum refineries were derived from the actual and
uncontrolled emissions reported in Reference 6 or Reference 7 according to Equation 3.25-2.
where: CE = control efficiency
UE = uncontrolled emissions
AE = actual (controlled) emissions
3. 25. 4. 2 NOX Emissions
No control efficiencies were applied to the activity data to estimate the NOX emissions from the
petroleum refinery sources included in this Tier II category.
3.25.4.3 PM-10 and TSP Emissions
The TSP control efficiencies for FCC and TCC in petroleum refineries were derived from the actual
and uncontrolled emissions reported in Reference 6 or Reference 7 according to Equation 3.25-2. The
PM-10 control efficiencies for these processes for the years 1975 through 1984 were based on the 1988
PM-10 control efficiencies obtained from Reference 11. During these years, any changes in the
corresponding TSP control efficiencies from the 1985 TSP control efficiency value were reflected in the
PM-10 control efficiencies. For the years 1940 through 1974, no control efficiencies were used to
estimate PM-10 emissions.
3. 25. 4. 4 VOC Emissions
The control efficiencies for FCC and TCC in petroleum refineries were assumed to be 95 percent of
the corresponding CO control efficiencies.
For the years 1970 through 1984, the emission factors for the petroleum refinery process operations
of blow down systems, process drains, and vacuum jets were based on the controlled and uncontrolled
emission factors. The controlled emission factors were estimated using weighted averages of emission
factors for "old" refinery capacity (pre-1970) and "new" refinery capacity where the "old" and "new"
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capacities for used as weighting factors. A detailed description of the calculation procedure is presented
below.
The first step in this procedure was the development of the breakdown of the refineries capacity into
"old" and "new". For blow down systems and process drains, the total crude oil capacity of refineries
was obtained from Reference 1 for the year under study and for the previous year. The difference
between total capacity for the year under study and capacity from the previous year was assumed to be
the new capacity for the year under study. If the difference was negative, the new capacity was assumed
to be zero.
In order to calculate the old capacity, the NSPS capacity was calculated. This was done by adding
the new capacity for the year under study to 1 percent of the total capacity from the previous year. This
sum, the NSPS capacity, was subtracted from the total capacity for the year under study, resulting in the
old capacity.
The same procedure was used to estimate the old and new capacities for vacuum jets. In place of
the total crude oil capacity, the total vacuum distillation capacity obtained from Reference 1 was used.
For each of the three processes, two controlled emission factors were used to calculate a weighted
average controlled emission factor. The average 1970 emission factor represented the emission rate of
older operations and, therefore, was weighted by the old capacity. The NSPS emission factor, applicable
to newer operation, was weighted by the new capacity. The 1970 and NSPS emission factors for each
subcategory are presented in Table 3.25-1, along with the corresponding uncontrolled emission factors.
The calculation of the weighted average controlled emission factors is summaries in Equation 3.25-3.
™ (Capacity old x EFoU) + (Capacitynew x EFmJ
(Capacity., + Capacity^) (Eq' 3'25'3)
where: EF = emission factor
The control efficiency for each process was calculated as the percentage difference between the
controlled emission factor calculated according to the methodology above and the uncontrolled emission
factors presented in Table 3.25-1. This calculation is summarized in Equation 3.25-4.
CE =
Uncontrolled
where: CE = control efficiency
EF = emission factor
For the years 1940, 1950, and 1960, the procedure for determining the control efficiencies for blow
down systems, process drains, and vacuum jets is currently unavailable.
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No control efficiencies were applied to the activity data to estimate VOC emissions from
compressors, cooling towers, or miscellaneous processes used in petroleum refinery process operations.
3.25.5 References
1. Oil and Gas Journal. Annual Refining Survey, P.O. Box 2601, Clinton, IA. Annual.
2. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC. Annual.
(a) Table containing information on Petroleum, Coal, and Products
3. Minerals Industry Surveys, Sulfur. Bureau of Mines, U.S. Department of the Interior, Washington,
DC. Monthly.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
(a) Volume I, Table 9.1-1
5. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
6. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
7. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
8. Volatile Organic Compound (VOC) Species Data Manual. EPA-450/4-80-015. U.S.
Environmental Protection Agency, Research Triangle Park, NC. July 1980.
9. Air Pollution Aspects of Petroleum Refining. PHS-763. U.S. Public Health Service, Washington,
DC.
10. Control Techniques Guidelines. EPA-450/2-77-025. U.S. Environmental Protection Agency,
Washington, DC. 1977.
11. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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Table 3.25-1. Emission Factors Used in the Calculation of the Control
Efficiencies for the Blow Down Systems, Process Drains, and Vacuum
Jets Subcategories
Subcategories Emission Factors (lb/106 bbl)
1970 NSPS Uncontrolled
Blow down Systems 178.84 5.26 263
Process Drains 205.2 57.0 570
Vacuum Jets 108.75 0.0 145
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3.26 PETROLEUM AND RELATED INDUSTRIES - ASPHALT MANUFACTURING:
06-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(06) PETROLEUM AND (03) Asphalt Manufacturing Batching - dryers and fugitives
RELATED INDUSTRIES Roofing - blowing and felt
saturation
Blowing
3.26.1 Technical Approach
The PM-10, TSP, and VOC emissions included in this Tier category were the sum of the emissions
from the source categories listed above. Emissions were estimated only for particulates and VOC from
an activity indicator, emission factor, and control efficiency, where applicable. In order to utilize these
values in the Trends spreadsheets, activity indicators for PM-10 and TSP emissions were expressed in
thousand short tons and emission factors were expressed in metric pounds/short ton. For VOC
emissions, the activity indicator was expressed in millions barrels and the emission factor was expressed
in metric pounds/thousand barrels. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies for VOC were used for the years 1940, 1950, 1960, and 1970 through 1984 and for TSP for
the years through 1992. For PM-10, these procedures were used for the years 1975 through 1984. For
some source categories, the PM-10 emissions exceeded the TSP emissions as calculated by the
procedures presented in this section. Because this represents a physical impossibility, a more realistic
estimate of the PM-10 emissions was assumed to be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.26-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x ^p —: y-^- (Eq. 3.26-1)
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.26.2 Activity Indicator
The total amount of asphalt and road oil supplied, expressed in barrels, was obtained from Reference
1 and was multiplied by 2.29. This result was used as the PM-10 and TSP activity indicators for the
asphalt batching operations of dryers and fugitive processes. The activity indicators for the asphalt
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roofing operations of blowing and felt saturation were the total domestic consumption of asphalt obtained
from Reference 2.
The VOC activity indicator for asphalt blowing was the total crude capacity, expressed in barrels/day
obtained from Reference 3. This daily value was multiplied by 365 to convert to an annual figure.
3.26.3 Emission Factor
The PM-10 and TSP emission factors for asphalt batching dryers were the weighted average of the
emission factors for rotary dryers, conventional plant (SCC 3-05-002-01), drum dryers, and drum mix
plant (SCC 3-05-002-05). The TSP emission factors were obtained from References 4a and 4b and the
PM-10 emission factors were obtained from Reference 5. These emission factors were weighted by the
number of records in Reference 6 or Reference 7 corresponding to the rotary and drum dryer SCCs.
The PM-10 and TSP emission factors for asphalt batching fugitive processes were obtained from
Reference 5 and Reference 8, respectively.
The TSP emission factors for blowing operations for asphalt roofing were obtained from Reference
4c for saturant (SCC 3-05-001-01) and coating (SCC 3-05-001-02). The PM-10 emission factors were
obtained from Reference 5. Weighted averages of these two emission factors were calculated by
weighting the saturant emission factor by 95 percent and the coating emission factor by 5 percent.
The TSP emission factors for felt saturation operations in asphalt roofing were obtained from
Reference 4c for dipping only (SCC 3-05-001-03) and dipping/spraying (SCC 3-05-001-04). The PM-10
emission factors were obtained from Reference 5. Weighted average of these emission factors were
calculated by weighting the dipping only emission factors by two-thirds and the dipping/spraying emission
factors by one-third.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
The VOC emission factor for asphalt blowing was obtained from Reference 4.
3.26.4 Control Efficiency
The TSP control efficiencies for asphalt batching dryers were the weighted average of the control
efficiencies for drum and rotary dryers derived from Reference 6 or Reference 7 using Eqiatopm 3.26-2.
These control efficiencies were weighted in the same manner as the drum and rotary dryer emission
factors.
where: CE = control efficiency
UE = uncontrolled emissions
AE = controlled emissions
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The 1980 TSP control efficiency for asphalt batching fugitive processes was calculated using data
from Reference 3 for the SCCs 3-05-002-03 and 3-05-002-04. For subsequent years, it was assumed that
the fugitive control efficiencies changed in proportion to the changes in dryer control efficiencies. No
procedure for determining the control efficiencies prior to 1980 is currently available.
The TSP control efficiencies for blowing operations in asphalt roofing were the weighted averages
of the control efficiencies for saturant and coating derived from Reference 6 or Reference 7 using the
equation given above. These individual control efficiencies were weighted in the same manner as the
saturant and coating emission factors.
The TSP control efficiencies for felt saturation operation in asphalt roofing were the weighted
averages of the control efficiencies for dipping and dipping/spraying derived from Reference 6 or
Reference 7 using the equation given above. These individual control efficiencies were weighted in the
same manner as the dipping and dipping/spraying emission factors.
The PM-10 control efficiencies for asphalt batching dryers and for blowing and felt saturation
operations for the years 1975 through 1984 were based on the 1988 PM-10 control efficiencies obtained
from Reference 9. During these years, any changes in the corresponding TSP control efficiencies from
the 1985 TSP control efficiency values were reflected in the PM-10 control efficiencies. For the years
1940 through 1974, no control efficiencies were used to estimate PM-10 emissions from asphalt roofing
operations or asphalt batching fugitive processes.
No control efficiencies were applied to the activity data to estimate VOC emissions from asphalt
blowing.
3.26.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
2. Asphalt Usage United States & Canada. The Asphalt Institute, College Park, MD. Annual.
3. Oil and Gas Journal. Annual Refining Survey, P.O. Box 2601, Clinton, IA. Annual.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 8.1-1
b. Volume I, Table 8.1-3
c. Volume I, Table 8.2-1
5. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
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6. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
7. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
8. Assessment of Fugitive Paniculate Emission Factors for Industrial Processes. EPA-450/3-78-107.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1978.
9. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.27 OTHER INDUSTRIAL PROCESSES - AGRICULTURE, FOOD, AND KINDRED
PRODUCTS: 07-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(07) OTHER INDUSTRIAL (01) Agriculture, Food, and Cotton ginning, cattle feedlots,
PROCESSES Kindred Products alfalfa dehydrators, country
elevators, terminal elevators, feed
mills, grain milling (wheat, corn-
dry, corn-wet, rice, soybeans)
Bakeries, fermentation, and
vegetable oil
3.27.1 Technical Approach
The PM-10, TSP, and VOC emissions included in this Tier category were the sum of the emissions
from the source categories listed above. Emissions were estimated only for particulates and VOC from
an activity indicator, emission factor, and control efficiency, where applicable. In order to utilize these
values in the Trends spreadsheets, the activity indicators were expressed in thousand short tons and the
emission factors were expressed in metric pounds/short ton. All control efficiencies were expressed as
dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies for VOC were used for the years 1940, 1950, 1960, and 1970 through 1984 and for TSP for
the years through 1992. For PM-10, these procedures were used for the years 1975 through 1984. For
some source categories, the PM-10 emissions exceeded the TSP emissions as calculated by the
procedures presented in this section. Because this represents a physical impossibility, a more realistic
estimate of the PM-10 emissions was assumed to be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.27-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.27-1)
This calculation was used in place of estimating the emissions based on activity indicators, emission
factors, and control efficiencies.
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3.27.2 Activity Indicator
3.27.2.1 PM-1 Oand TSP Emissions
The activity indicator for cotton ginning was the number of running bales obtained from Reference
la.
The cattle feedlot activity indicator was based on the number of cattle and calves slaughtered,
expressed in thousands, reported in Reference Ib. This value was multiplied by 0.46 to determine the
final activity indicator.
The activity indicator for alfalfa dehydrators was total production obtained from Reference 2.
The activity indicators for country elevators and terminal elevators were based on the total
production of five major grains. Total production of sorghum was obtained from Reference 3. Total
productions of wheat, corn, oats, and barley were each obtained from Reference Ib. Production figures
for each grain were converted from bushels to total weight using the conversion factors listed in Table
3.27-1. The production figures for the five grains were summed and multiplied by 0.8. This grain
production by weight was the activity indicator for both country elevators and terminal elevators.
The activity indicator for feed mills is the total consumption of wheat, corn, oats, barley, sorghum,
and alfalfa meal. When the year under study was a census year, total consumption data (SIC 2048) was
obtained from Reference 2. For a noncensus year, grain consumption by feed mills was estimated using
the total grain production as determined for the country elevator subcategory. Total production was
multiplied by the ratio of total grain production to total grain consumption data (SIC 2048) obtained for
the previous census year.
The activity indicator for the wheat milling was the total quantity of grindings of wheat expressed in
thousands of bushels reported in Reference la. The quantity was converted to weight using the wheat
conversion factor presented in Table 3.27-1.
The activity indicator for the dry corn milling was the total production of dry corn. When the year
under study was a census year, the total dry corn production was obtained from Reference 2. For
noncensus years, the dry corn production was calculated by multiplying the total corn production
obtained from Reference Ib for the year under study by the factor 0.021. For the years 1940 through
1973, this multiplicative factor, as well as a procedure for determining the factor, is currently unavailable.
The activity indicator for wet corn milling was determined in the same manner as dry corn milling.
The only difference being the use of 0.059 as the multiplicative factor for noncensus years after 1974.
The activity indicator for rice was the total rice production. The production figure was obtained as
the total shipments from mills in southern states and California or the total production reported in
Reference Ib.
The activity indicator for soybeans was based on the total soybean production as obtained from
Reference 3. This value was converted from bushels to weight using the conversion factor for wheat
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given in Table 3-27-1. It was assumed that 70 percent of the total production was domestic
consumption. The final activity indicator for soybeans represented only the domestic consumption.
3.27.2.2 VOC Emissions
The activity indicator for bakeries was the production of wheat flour obtained from Reference Ib.
This value, expressed in thousand sacks, was multiplied by 27.21 tons bread baked/106 sacks.
The activity indicator for the fermentation processes was based on the stocks of distilled spirits and
production of beer reported in Reference Ib. Stocks of distilled spirits were converted to metric pounds
by the factor 0.1814 metric Ib/gal. Beer production figure was converted to metric pound using the
factor 0.06 metric Ib/bbl. The activity indicator was the sum of distilled spirits and beer production
figures.
The activity indicator for vegetable oil subcategory was the refined oil production for soybean,
cotton seed, corn, and coconut obtained from Reference 4.
3.27.3 Emission Factor
3.27.3.1 PM-1 Oand TSP Emissions
The emission factors for cotton ginning were the sum of the emission factors for the following four
processes: unleading fan (3-02-004-01), seed cotton cleaning system (SCC 3-02-004-02), stick/burr
machine (SCC 3-02-004-03), and miscellaneous (SCC 3-02-004-04). These emission factors were
obtained from Reference 5a for TSP and from Reference 6 from PM-10.
The PM-10 and TSP emission factors for cattle feedlots (SCC 3-02-020-01) were obtained from
Reference 6 and Reference 5b, respectively.
The emission factors for alfalfa dehydrator were the sum of the emission factors from three
processes: primary cyclone and dryer (SCC 3-02-001-02), meal collector (SCC 3-02-001-03), and pellet
cooler (SCC 3-02-001-04). The emission factors for these processes were obtained from Reference 5c
for TSP and from Reference 6 for PM-10.
The emission factors for country elevators were the sum of the emission factors from six process
listed in Table 3.27-2. The emission factors for terminal elevators were the sum of the emission factors
from seven process listed in Table 3.27-3. The PM-10 and TSP emission factors for the elevator
processes were obtained from Reference 6 and Reference 5d, respectively.
The emission factors for feed mills were the sum of the emission factors from five process listed in
Table 3.27-4. The emission factors for these processes were obtained from Reference 5e for TSP and
from Reference 6 for PM-10.
The PM-10 and TSP emission factors for wheat milling were based on the emission factors obtain
from Reference 6 and Reference 5e, respectively, for the following three processes: receiving (SCC 3-02-
007-31), precleaning/handling (SCC 3-02-007-32), and millhouse (3-02-007-34). It was assumed that a
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99 percent control applied to the millhouse emission factor. The resulting controlled emission factors for
the millhouse process were added to the other emission factors to obtain the final PM-10 and TSP
emission factors.
The PM-10 and TSP emission factors for dry corn were the sum of the emission factors obtain from
Reference 6 and Reference 5e, respectively, for the following four processes: receiving (SCC 3-02-007-
41), drying (SCC 3-02-007-42), precleaning/handling (SCC 3-02-007-43), and cleaning (3-02-007-44).
The emission factors for wet corn were the sum of the emission factors for the following three processes:
receiving (SCC 3-02-007-51), handling (SCC 3-02-007-52), and cleaning (3-02-007-53). The PM-10
emission factors were obtained from Reference 6; the TSP emission factors were obtained from
Reference 5e .
The PM-10 and TSP emission factors for rice were the sum of the emission factors obtain from
Reference 6 and Reference 5e, respectively, for the following processes: receiving (SCC 3-02-007-71)
and precleaning/handling (SCC 3-02-007-72).
The emission factors for soybeans were the sum of the emission factors from 10 processes listed in
Table 3.27-5. The emission factors for these processes were obtained from Reference 5e for TSP and
from Reference 6 for PM-10.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.27.3.2 VOC Emissions
The emission factor for bakeries was weighted average of the emission factors for sponge dough
(SCC 3-02-032-01) and straight dough (SCC 3-02-032-02). These emission factors were obtained from
Reference 5f. The weighting factor for sponge dough was 0.915 and for straight dough was 0.085.
The emission factor for fermentation processes was based on the assumption of complete
evaporation of all volatile compounds (i.e. the emission factor was 2000 Ib/ton).
The emission factor for vegetable oil was based on the 1979 emission estimates obtained from the
EPA's Emission Standards and Engineering Division. The total emissions were divided by the 1977
production rate to obtain the emission factor for vegetable oil. The source of the 1977 production rate is
currently unavailable.
3.27.4 Control Efficiency
3.27.4.1 PM-1 Oand TSP Emissions
The TSP control efficiencies for all agricultural industrial processes, excluding country and terminal
elevators, were derived from Reference 7 or Reference 8 using Equation 3.27-2.
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(B,. 3.27-2)
where: CE = control efficiency
UE = uncontrolled emissions
AE = actual (controlled) emissions after
The TSP control efficiencies for country and terminal elevators were the weighted average of the
control efficiencies for the SCCs given in Table 3.27-2 and Table 3.27-3, respectively. These individual
control efficiencies were derived from Reference 7 or Reference 8 using Equation 3.27-2. The final
country and terminal elevator control efficiencies were calculated using weighting factors obtained in
Reference 5d.
The PM-10 control efficiencies for all agricultural industry emission sources for the years 1975
through 1984 were based on the 1988 PM-10 control efficiencies obtained from Reference 9. During
these years, any changes in the corresponding TSP control efficiencies from the 1985 TSP control
efficiency value were reflected in the PM-10 control efficiencies. For the years 1940 through 1974, no
control efficiencies were used to estimate PM-10 emissions.
3.27.4.2 VOC Emissions
No control efficiencies were applied to the activity data to estimate VOC emissions from bakeries,
fermentation processes, and vegetable oil production.
3.27.5 References
1 . Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC.
(a) Table containing information on "textile products."
(b) Table containing information on "food and kindred products."
2. Census of Manufactures . Bureau of the Census, U.S. Department of Commerce, Washington, DC.
Available every 5 years.
3. Crop Production. GPO20-B-S/NOO 1/028/80029/1. Crop Reporting Board Economic Statistics &
Cooperative Service, U.S. Department of Agriculture, Washington, DC. Monthly.
4. Current Industrial Reports, Fats and Oil. Bureau of the Census, U.S. Department of Commerce,
Washington, DC. Annual.
5. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 6.3-1
b. Volume I, Table 6.15-1
c. Volume I, Table 6.1-1
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d. Volume I, Table 6.4-5 (column 3)
e. Volume I, Table 6.4-6
f. Volume I, Section 6.13
6. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
7. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
8. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
9. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
Table 3.27-1. Conversion of Grain Volume (in bushels) to Weight (in pounds)
Grain Ib/bu
Wheat 60
Corn 56
Oats 32
Barley 48
Sorghum 56
Table 3.27-2. PM-10 and TSP Emission Factor SCCs for Country Elevators
SCC Description
3-02-006-03 Cleaning
3-02-006-04 Drying
3-02-006-05 Unloading (receiving)
3-02-006-06 Loading (shipping)
3-02-006-09 Removal from bins
3-02-006-10 Headhouse (legs)
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Table 3.27-3. PM-10 and TSP Emission Factor SCCs for Terminal Elevators
SCC Description
3-02-005-03 Cleaning
3-02-005-04 Drying
3-02-005-05 Unloading (receiving)
3-02-005-06 Loading (shipping)
3-02-005-09 Tripper (gallery belt)
3-02-005-10 Removal from bins
3-02-005-11 Headhouse (legs)
Table 3.27-4. PM-10 and TSP Emission Factor SCCs for Feed Mills
SCC Description
3-02-008-02 Receiving
3-02-008-03 Shipping
3-02-008-04 Handling
3-02-008-05 Grinding
3-02-008-06 Pellet Coolers
Table 3.27-5. PM-10 and TSP Emission Factor SCCs for Soybean Milling
SCC Description
3-02-007-81 Receiving
3-02-007-82 Handling
3-02-007-84 Drying
3-02-007-85 Cracking/Dehulling
3-02-007-86 Hull Grinding
3-02-007-87 Bean Conditioning
3-02-007-88 Flaking
3-02-007-89 Meal Dryer
3-02-007-90 Meal Cooler
3-02-007-91 Bulk Loading
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3.28 OTHER INDUSTRIAL PROCESSES - WOOD, PULP AND PAPER, AND
PUBLISHING PRODUCTS: 07-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(07) OTHER INDUSTRIAL (03) Wood, Pulp and Paper, Pulp and Paper - kraft and sulfite
PROCESSES and Publishing Products Semi-Chemical Wood Pulp
Production
Plywood
Lumber
3.28.1 Technical Approach
The CO, NOX, PM-10, TSP, and SO2 emissions included in this Tier category were the sum of the
emissions from the source categories listed above. Emissions were estimated from an activity indicator,
emission factor, and control efficiency, where applicable. In order to utilize these values in the Trends
spreadsheets, activity indicators were expressed in thousand short tons and emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.28-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 328-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.28.2 Activity Indicator
For CO and NOX emissions, the activity indicator for kraft pulp and paper was the production value
reported for sulfate obtained from Reference 1. For SO2 emissions, the activity indicator for kraft pulp
production and sulfite was the combined production of sulfate and sulfite at kraft mills and sulfite mills
obtained from Reference 1.
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The PM-10 and TSP activity indicators for the two pulp and paper production processes were
obtained from Reference 1 . The activity indicator for kraft pulp was the production value reported for
sulfate and the indicator for sulfite was the production value reported for sulfite.
The PM-10 and TSP activity indicators for the two semi-chemical processes were based on the total
semi-chemical wood pulp production obtained from Reference 2. It was assumed that indicator for
recovery furnaces was one-third of the total production while the indicator for fluid bed reactors was 15
percent of the total production.
The PM-10 and TSP activity indicator for plywood was the softwood plywood production obtained
from Reference 3a. When this reference was not available, the total plywood production was estimated
using the total plywood production from Reference 4 for the census year preceding the year under study.
The combined total production values of plywood from southern pine and douglas fir were obtained from
Reference 2 for the census year and the year under study. Total plywood production was projected to
the year under study using Equation 3.28-2.
P
P = P x (pme
r plywood, i r plywood, j
where: i = year under study
j = census year
P = production
The PM-10 and TSP activity indicator for lumber was total lumber production obtained from
Reference 5 or Reference 2.
3.28.3 Emission Factor
The CO emission factor for kraft pulp and paper processes was the sum of the emission factors for
recovery furnaces (SCC 3-07-001-04) and lime kilns (SCC 3-07-001-06) obtained from Reference 6a.
The NOX emission factor for kraft pulp processes was calculated by dividing the actual emissions by
the operating rate. These values were obtained from Reference 7.
The PM-10 and TSP emission factors for the kraft process in pulp and paper production were the
sum of the emissions factors for the following three processes: recovery furnaces/direct contact
evaporators (SCC 3-07-001-04), smelt tanks (SCC 3-07-001-05), and lime kilns (SCC 3-07-001-06).
These PM-10 and TSP emission factors were obtained from Reference 8 and Reference 9a.
The TSP emission factor for the sulfite process in pulp and paper production was obtained from
Reference 10. The PM-10 emission factor was obtained from Table 3.1-3 in this report.
The TSP emission factors for the two semi-chemical processes of recovery furnaces and fluid red
reactors were obtained from Reference 1 1 . The PM-10 emission factor was obtained from Reference 8
or Table 3.1-3 of this report.
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The TSP emission factor for plywood was obtained from Reference 10. The PM-10 emission factor
was obtained from Table 3.1-3 of this report.
The TSP emission factor for lumber was calculated by dividing the actual emissions reported in
Reference 7 by the 1977 lumber production reported in Reference 2. The PM-10 emission factor was
obtained from Reference 8 or Table 3.1-3 of this report.
The SO2 emission factor for kraft pulp production and sulfite was the weighted sum of the emission
factors for kraft pulp production and for sulfite mills. The emission factor for kraft pulp production was
obtained from Reference 9a. The sulfite mills emission factor was calculated from the controlled and
uncontrolled sulfite mills emission factors of 20 Ib/ton and 52 Ib/ton, respectively. These emission factors
were obtained from Reference 10. Assuming the particulate control efficiency was 0.90 for sulfite mills,
the controlled emission factor was multiplied by 0.9 and the uncontrolled emission factor by 0.1. The
resulting products were summed. Weighting factors for summing the emission factors for kraft pulp
production and sulfite mills were the relative production levels obtained from Reference 1 .
3.28.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate CO, NOX, or SO2 emissions from
the pulp and paper sources included in this Tier II category.
The TSP control efficiencies for the pulp and paper, plywood, and lumber production processes
were derived from Reference 12 or Reference 13 using Equation 3.28-3. The TSP control efficiencies for
the semi-chemical processes were assumed to be equal to the control efficiencies for the kraft process in
pulp and paper production.
where: CE = control efficiency
UE = uncontrolled emissions
AE = actual (controlled) emissions after
The PM-10 control efficiencies for kraft processes in pulp and paper production and fluid red
reactors in semi-chemical production for the years 1975 through 1984 were based on the 1988 PM-10
control efficiencies obtained from Reference 14. During these years, any changes in the corresponding
TSP control efficiencies from the 1985 TSP control efficiency value were reflected in the PM-10 control
efficiencies. For the years 1940 through 1974, no control efficiencies were used to estimate PM-10
emissions.
No control efficiencies were applied to the activity data to estimate PM-10 emissions from sulfite
processes in pulp and paper production and recovery furnaces in semi-chemical production. For plywood
and lumber production, no control efficiencies were applied in the estimation of PM-10 and TSP
emissions.
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3.28.5 References
1. Current Industrial Reports, Pulp, Paper and Board. Bureau of the Census, U.S. Department of
Commerce, Washington, DC. Annual.
2. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC. Annual.
3. Current Industrial Reports, Softwood Plywood
(a) Table: Production, Quantity and Value of Shipments of Softwood Plywood
4. Census of Manufactures. U.S. Department of Commerce, Bureau of the Census, Washington, DC.
(available every 5years)
5. Current Industrial Reports, Lumber Production and Mill Stocks. Bureau of the Census, U.S.
Department of Commerce, Washington, DC. Annual.
6. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Volume I, Table 10.1.2-1
7. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park,NC. February 9, 1980.
8. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
9. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 10.1-1
10. Compilation of Air Pollutant Emission Factors, Third Edition, and Supplements 1-14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
11. Paniculate Pollution System Study. U.S. Environmental Protection Agency. Prepared by Midwest
Research Institute, Kansas City, MO. 1970.
12. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
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13. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
14. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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3.29 OTHER INDUSTRIAL PROCESSES - RUBBER AND MISCELLANEOUS PLASTIC
PRODUCTS: 07-04
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(07) OTHER INDUSTRIAL (04) Rubber and Miscellaneous Tires
PROCESSES Plastic Products
3.29.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source category
listed above. Emissions were estimated only for VOC from an activity indicator and emission factor. In
order to utilize these values in the Trends spreadsheets, the activity indicator was expressed in thousand
short tons and the emission factor was expressed in metric pounds/short ton.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984.
3.29.2 Activity Indicator
The activity indicator for tires was the production of pneumatic casing obtained from Reference la.
3.29.3 Emission Factor
The VOC emission factor for tires was the sum of the emission factors for the processes listed in
Table 3.29-1 and were extracted from Reference 2. These emission factors were expressed as lbs/1,000
tires. The summed emission factor was converted to Ibs/ton, assuming that 1,000 tires weigh one ton.
3.29.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from tire
production.
3.29.5 References
1. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC.
(a) Table containing information on "rubber and rubber products."
2. Control Techniques Guidelines. EPA-450/2-77-025. U.S. Environmental Protection Agency,
Washington, DC. 1977.
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Table 3.29-1. VOC Emissions Factor SCCs for Tire Production
SCC Description
3-08-001-01 Undertread & Sidewall Cementing
3-08-001-02 Bead Dipping
3-08-001-03 Bead Swabbing
3-08-001-04 Tire Building
3-08-001-05 Tread End Cementing
3-08-001-06 Green Tire Spraying
3-08-001-07 Tire Curing
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3.30
OTHER INDUSTRIAL PROCESSES - MINERAL PRODUCTS: 07-05
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(07) OTHER INDUSTRIAL
PROCESSES
Tier II Category
(05) Mineral Products
Tier II Subcategory
Mineral Products (cement,
bricks, clay, concrete, glass,
gypsum, and lime)
Mining Operations (coal, sand
and gravel, stone and rock,
phosphate rock, clay, and potash)
Chemical Industry (fertilizers -
rock pulverization)
Asphalt Roofing
3.30.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in thousand short tons and emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.30-1.
PM-10 Emissionsyear = PM-10 Emissions 1975
TSP Emissionsyear
TSP Emissions
(Eq. 3.30-1)
1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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3.30.2 Activity Indicator
3.30.2.1 CO Emissions
The activity indicator for asphalt roofing was the total domestic consumption obtained from
Reference 1.
The activity indicators for kiln and fugitive processes in lime production were the lime production
obtained from Reference 2.
3.30.2.2 NOX Emissions
The activity indicator for cement manufacturing was the total quantity of cement production as
obtained from Reference 3.
The activity indicator for glass manufacturing was based on the sum of total production of flat glass
obtained from Reference 4 and the net packed weight of glass containers obtained from Reference 5. The
resulting value was multiplied by 1.10 to account for miscellaneous glass products.
The activity indicator for lime kiln and fugitive processes was the lime production obtained from
Reference 2.
3.30.2.3 PM-10 and TSP Emissions
3.30.2.3.1 Mineral Products Industry —
The activity indicators for the three cement manufacturing processes were the total quantity of
cement production as obtained from Reference 3.
The total brick production, expressed in millions of bricks, was obtained from Reference 6. The
quantity was multiplied by 6.5 Ib/brick. To this value was added the sum of the sewer pipes and fittings
production value and the structural facing tile production value as reported in Reference 6a. The final
result was the activity indicator for bricks.
The activity indicator for clay sintering was the quantity of common clay and shale used in
lightweight aggregate production as reported Reference 7.
The activity indicator for concrete batching was based on the sum of the total shipments of portland
cement to concrete product manufacturers and to ready-mix plants as reported in Reference 3 a. The
resulting sum was multiplied by 7.5.
The activity indicators for the furnace, forming, and curing processes of fiber glass production were
the production of textile type and wool type glass fiber obtained from Reference 8.
The activity indicator for glass was based on the sum of the flat glass production value obtained
from Reference 4 and the net packed weight of glass containers obtained from Reference 5. The resulting
value was multiplied by 1.10 to account for miscellaneous glass products.
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The activity indicator for calciners used in gypsum manufacturing was the quantity of calcined
gypsum produced as reported in Reference 9. For dryers used in gypsum manufacturing , the activity
indicator was one-half of the total quantity produced.
The activity indicators for kilns and fugitive processes used in lime manufacturing were the lime
production figure obtained from Reference 2.
3.30.2.3.2 Mining Operations —
The activity indicator for surface coal mining was the total coal production by surface mining
methods obtained from Reference 10 or from Reference 11.
For coal handling, the activity indicator was the sum of the quantity of coal cleaned and crushed and
screened as reported in Reference 10. For years when these data were not reported, the value was
extrapolated from latest available data based on the total coal production.
The activity indicator for coal mining thermal dryers was the quantity of coal thermally dried
obtained from Reference 10. For years when these data were not available, the value was extrapolated
from previous year's data, based on the change in the total coal production from Reference 10.
For coal mining, pneumatic dryers, the activity indicator was the quantity of coal processed obtained
from Reference 10. For years when these data were not available, the value was extrapolated from the
previous year's data based on the change in the total coal production from Reference 10.
The activity indicator for sand and gravel was the sum of the total production of sand and gravel for
construction and for industrial purposes obtained from Reference 12. The total production of stone and
rock crushing was obtained from Reference 13. The activity indicators for the three phosphate rock
processing operations were the marketable production of phosphate rock obtained from Reference 14.
The activity indicator for clays was the total domestic clay sold or used by producers as reported in
Reference 7.
The activity indicator for potash was the total potash production, expressed in potassium oxide
(K2O) equivalent, and was obtained from Reference 2.
3.30.2.3.3 Chemical Industry —
The activity indicator for rock pulverization for fertilizers was the sum of the phosphate rock sales of
single superphosphate and triple superphosphate obtained from Reference 14.
3.30.2.4 SO2 Emissions
The activity indicators for the three cement manufacturing processes were the total quantity of
cement production as obtained from Reference 3.
The activity indicator for glass manufacturing was based on the sum of the flat glass production
value obtained from Reference 4, and the net packed weight of glass containers obtained from Reference
5. The resulting value was multiplied by 1.10 to account for miscellaneous glass products.
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The activity indicators for the lime kiln and fugitive processes were the lime production figure
obtained from Reference 2.
3.30.2.5 VOC Emissions
The activity indicator for glass manufacturing was based on the sum of the flat glass production
value obtained from Reference 4, and the net packed weight of glass containers obtained from Reference
5. The resulting value was multiplied by 1.10 to account for miscellaneous glass products.
3.30.3 Emission Factor
3.30.3.1 CO Emissions
The emission factor for asphalt roofing was the weighted average of the emission factors for
controlled plants (2.85 Ib/ton) and uncontrolled plants (0.22 Ib/ton). The weighting factors were the
fraction of plants with controls and the faction of plants without controls. The fraction of plants with
controls was calculated by dividing the TSP control efficiency for the category asphalt roofing - blowing
by 0.956. All other plants were assumed to operate without controls. The overall emission factor
calculation is summarized in Equation 3.30-2.
CETSP\
EF = 2.85 x rap
0.956 )
CE
rap
+ 10.22 x I 1 - - , I (Eq. 3.30-2)
1 ' 0.956 '
where: CETSP = TSP control efficiency for the category asphalt roofing - blowing
The emission factor for lime manufacturing (SCC 3-05-016-04) was obtained from Reference 15a.
3.30.3.2 NOX Emissions
The emission factor for cement manufacturing (SCC 3-05-006-06) was obtained from
Reference 15b.
The emission factor for glass manufacturing was the weighted average of the emission factors for
three glass types as reported in Reference 15c. A list of the glass types, SCCs and weighting factors are
presented in Table 3.30-1.
The emission factor for lime was the weighted average of the emission factors for the SCCs
3-05-016-xx. These emission factors and the corresponding weighting factors were obtained from
Reference 16.
3.30.3.3 PM-10 and TSP Emissions
3.30.3.3.1 Mineral Products Industry —
The PM-10 and TSP emission factors for kilns used in cement manufacturing were the weighted
average of the emission factors for the dry process kilns (SCC 3-05-006-06) and the wet process kilns
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(SCC 3-05-007-06). These emission factors were obtained from Reference 15b for TSP and Reference
17 for PM-10. The weighting factors were the relative capacity of the wet process and of the dry process
as reported in Reference 3.
The emission factors for grinders used in cement manufacturing were the weighted average of the
emission factors for the dry process clinker grinder (SCC 3-05-006-17) and the wet process clinker
grinder (SCC 3-05-007-17). The PM-10 and TSP emission factors were obtained from Reference 17 and
Reference 15b, respectively, and were weighted by the relative capacity of the wet process and of the dry
process as reported in Reference 3.
The TSP emission factors for cement manufacturing fugitive processes were obtained from
Reference 18. The PM-10 emission factor was obtained from Reference 17 or Table 3.1-3 of this report.
The PM-10 and TSP emission factors for bricks was the sum of the emission factors for materials
handling and for kilns. The emission factors for material handling were obtained from Reference 18 for
TSP and from Reference 17 or Table 3.1-3 of this report for PM-10. The PM-10 and TSP emission
factors for kilns were the weighted average of the SCCs listed in Table 3.30-2 and were obtained from
Reference 17 and Reference 15d, respectively. The weighting factors were based on References 19 or
20.
The emission factors for clay sintering were the sum of the emission factors for the five processes
listed in Table 3.30-3. These represent the processing of raw clay and shale combined. The raw clay
sintering and finished product processing and screening emission factors for TSP were obtained from
Reference 15e. The emission factors for crushing and screening and transfer and conveying were
obtained from Reference 17. The storage emission factor was assumed to be 0.3 Ib/ton for TSP and zero
for PM-10.
The PM-10 and TSP emission factors for concrete batching (SCC 3-05-011-01) were obtained from
Reference 17 and Reference 15f, respectively. The values were converted from lb/yd3 to Ibs/ton using the
factor 0.5.
The emission factors for furnaces used in fiber glass manufacturing were the weighted average of the
emission factors for the furnace types listed in Table 3.30-4. The emission factors for these furnace types
were obtained from Reference 15g for TSP and from Reference 17 for PM-10. The weighting factors
were based on the operating rates obtained from Reference 19 or 20 for these types of furnaces.
The emission factors for fiber glass forming and curing processes were the weighted average of the
emission factors for three processes. The TSP emission factor for the rotary spun wool type (SCC 3-05-
012-04) was obtained from Reference 2la. The TSP emission factors for the flame attenuation wool type
(SCC 3-05-012-08) and the textile type (SCC 3-05-012-014) were obtained from Reference 15g. The
PM-10 emission factors for the three processes were obtained from Reference 17. The weighting factors
were based on the operating rates obtained from Reference 19 or 20 for these three processes.
The emission factors for glass were based on the emission factors for three types of glass: container
glass, melting furnace (SCC 3-05-014-02), flat glass, melting furnace (SCC 3-05-014-03), and pressed
and blown glass, melting furnace (SCC 3-05-014-04). These emission factors were obtained from
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Reference 15c for TSP and From Reference 17 for PM-10. The weighted averages of these emission
factors were calculated using the following weighting factors: 0.75 for container glass, 0.15 for flat glass,
and 0.1 for blown and pressed glass.
The PM-10 and TSP emission factors for gypsum manufacturing dryers (SCC 3-05-015-01) and
calciners (SCC 3-05-015-11) were obtained from Reference 17 and Reference 21b, respectively. For
calciners, it was assumed that all calciners were continuous kettle calciners.
The emission factors for lime manufacturing kilns were the weighted average of the emission factors
for two types of kilns: vertical kilns (SCC 3-05-016-03) and rotary kilns (SCC 3-05-016-04). These
PM-10 and TSP emission factors were obtained from Reference 17 and Reference 15h, respectively, and
were weighted using the data from Reference 22. The PM-10 and TSP emission factors for the fugitive
processes were obtained from Reference 18 or Table 3.1-3 of this report.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.30.3.3.2 Mining Operations —
The PM-10 and TSP emission factors for surface mining and coal handling were obtained from
Reference 18. The emission factors for thermal dryers (SCC 3-05-010-01) were obtained from Reference
15i for TSP and from Reference 17 for PM-10. The pneumatic dryers emission factors were based on
engineering judgement and are presented in Table 3.1-3 of this report.
The TSP emission factor for sand and gravel was obtained from Reference 21c. The PM-10
emission factor was obtained from Reference 17 or Table 3.1-3 of this report.
The emission factors for stone and rock crushing were the weighted averages of the emission factors
for the processes listed in Table 3.30-5. The PM-10 and TSP emission factors for these processes were
obtained from Reference 17 and Reference 2Id, respectively, and were weighted by the number of
records in Reference 19 or Reference 20, except for miscellaneous operations process (SCC 3-05-020-
06). Emission factors for this process were added to the weighted average of the emission factors of the
other four processes.
The emission factors for phosphate rock drying or calcining processes were the weighted average of
the emission factors for drying (SCC 3-05-019-01) and calcining (SCC 3-05-019-05) processes. The
PM-10 and TSP emission factors were obtained from Reference 17 and Reference 15j, respectively, and
were weighted by the 1974 production of phosphate rock reported in Reference 14a. It was assumed that
phosphate rock production from Florida represented the drying processes and production from the
western States represented the calcining process.
The emission factors for phosphate rock grinding (SCC 3-05-019-02) and material handling (SCC 3-
05-019-03) were obtained from Reference 15j for TSP and from Reference 17 for PM-10.
The emission factors for clays were the weighted averages of the emission factors for three
processes: drying (SCC 3-05-008-01), grinding (SCC 3-05-008-02), and storage (SCC 3-05-008-03).
The PM-10 and TSP emission factors were obtained from Reference 17 and Reference 15k, respectively.
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Weighting factors were 0.7 for the drying process, 1 for the grinding process and 0.5 for the storage
process.
The TSP emission factor for potash was calculated by dividing actual emissions reported in
Reference 16 by total production of potash, expressed in potassium oxide (K2O) equivalent weights,
obtained from Reference 7. The PM-10 emission factor was obtained from Reference 17.
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.30.3.3.3 Chemical Industry —
The PM-10 and TSP emission factors for rock pulverization (SCC 3-05-019-02) were obtained from
Reference 17 and Reference 22, respectively. For the years prior to 1975, emission factors were not
employed in the estimation of PM-10 emissions from the sources included in this Tier II category.
3.30.3.4 SO2 Emissions
The emission factor for cement manufacturing was based on the uncontrolled SO2 emissions, the
total cement production, and the SO2 control efficiency for cement kilns. The uncontrolled emissions
were produced by mineral sources and by the combustion of fuels used to fire the kilns. The uncontrolled
emission factors for the mineral sources and the combustion of coal, residual oil, and distillate oil are
presented in Table 3.30-6. The uncontrolled emissions from mineral sources were calculated using the
emission factor and the total cement production obtained from Reference 3.
The uncontrolled emissions from coal combustion were calculated using the emission factor, the coal
consumed by cement plants obtained from Reference 3, and the sulfur content of the coal. The sulfur
content was the average sulfur content for all coal shipped to industrial plants. The average sulfur
content of coal was determined from the sulfur content by coal producing districts obtained for the
category "Other industrial uses and retail dealers" in Reference lOa. This reference provided the sulfur
content values reported in 1977 and it was assumed that these values remained constant during the years
1940 through 1984. In order to obtain the average sulfur content for a specific year, the sulfur content by
district was weighted by the distribution of coal by district or origin for the category "Other Industrial"
obtained from Reference 23 or 24.
The uncontrolled emissions from residual oil were calculated using the emission factor, the residual
oil consumed by cement plants, and the sulfur content of the oil. The quantity of residual oil consumed
by cement plants was assumed to be two-thirds of the total oil consumed by cement plants as reported in
Reference 3. The sulfur content for residual oil was for No. 6 fuel oil obtained from Reference 25.
The uncontrolled emissions from distillate oil were calculated using the emission factor, the residual
oil consumed by cement plants, and the sulfur content of the oil. The quantity of distillate oil consumed
by cement plants was assumed to be one-third of the total oil consumed by cement plants as reported in
Reference 3. The sulfur content for distillate oil was assumed to be 0.3 percent.
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The uncontrolled emission factor for cement manufacturing was determined by dividing the total
uncontrolled emissions from mineral sources and fuel combustion by the total cement production
obtained from Reference 3. These calculations are summarized in Equation 3.30-3:
_£
_,_, SO~, uncontrolled . , __, .
EFS02, controlled = X 0 ~ CESO2, wJ (Eq. 3.30-3)
where: EF = emission factor
E = emissions
P = production
CE = control efficiency
The SO2 control efficiency for kilns was interpolated from the TSP control efficiency for cement
kilns. The TSP control efficiency is described in section 3.30.4.2. The interpolation of the SO2 control
efficiency from the TSP control efficiency was made using the following two reference points: TSP
control efficiency of 0.99 corresponded to a SO2 control efficiency of 0.1375 and TSP control efficiency
of 0.95 corresponded to a SO2 control efficiency of 0.12.
The SO2 emission factor for glass manufacturing was the weighted average of the emission factor for
the three types of glass: container glass, furnace (SCC 3-05-014-02), flat glass, furnace (SCCS-05-014-
03), and blown glass, furnace (SCC 3-05-014-04). These emission factors were obtained from Reference
15c. The weighting factors were 0.75 for container glass, 0.15 for flat glass, and 0.1 for blown glass.
The SO2 emission factor for lime processing was calculated by dividing the total actual SO2
emissions by the lime production rate. These values were obtained from Reference 16.
3.30.3.5 VOC Emissions
The VOC emission factor for glass manufacturing was the weighted average of the emission factor
for the three types of glass: container glass, furnace (SCC 3-05-014-02), flat glass, furnace (SCCS-05-
014-03), and blown glass, furnace (SCC 3-05-014-04). These emission factors were obtained from
Reference 15c. The weighting factors were 0.75 for container glass, 0.15 for flat glass, and 0.1 for blown
glass.
3.30.4 Control Efficiency
3.30.4.1 CO, NO;, SO2, and VOC Emissions
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, or VOC
emissions from the sources included in this Tier II category.
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3.30.4.2 PM-10 and TSP Emissions
3. 30. 4. 2. 1 Mineral Products Industry —
The TSP control efficiencies for all Mineral Products Industry production processes, except the
fugitive processes, were derived from Reference 19 or Reference 20 using Equation 3.30-4. For any
process where the emission factor was the weighted average of more specific emission factors, the
control efficiency was calculated in the same manner. The more specific control efficiencies were derived
using Equation 3.30-4.
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
The TSP control efficiencies for the fugitive processes in cement manufacturing and lime
manufacturing were based on engineering judgment.
The PM-10 control efficiencies for all mineral products industry production processes, except the
fugitive processes, for the years 1975 through 1984 were based on the 1988 PM-10 control efficiencies
obtained from Reference 26. During these years, any changes in the corresponding TSP control
efficiencies from the 1985 TSP control efficiency value were reflected in the PM-10 control efficiencies.
For the years 1940 through 1974, no control efficiencies were used to estimate the PM-10 emissions.
No control efficiencies were applied to the activity data to estimate PM-10 emissions from the
fugitive processes in cement and lime manufacturing.
3. 30. 4. 2. 2 Mining Operations —
The TSP control efficiencies for all mining operations processes, except those described below, were
derived from Reference 19 or Reference 20 using the equation given for the Mineral Products Industry
processes. For any process where the emission factor was the weighted average of more specific
emission factors, the control efficiency was calculated in the same manner. The more specific control
efficiencies were derived using Equation 3.30-4.
For coal mining, pneumatic dryers, the TSP control efficiencies for the years 1980 through 1984
were obtained from Reference 22. No procedure for determining the control efficiencies for the years
prior to 1980 is currently available.
The TSP control efficiency for clay production was the weighted average of the control efficiencies
for the drying, grinding, and storage processes obtained from Reference 19 or Reference 20. The
weighted average of these individual process control efficiencies was calculated in the same manner
described for the clay emission factor. No procedure for determining the yearly variation in the control
efficiencies is currently available.
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The TSP control efficiency for potash production for the years 1981 through 1984 was assumed to
be a constant value of 0.80. This value was based on engineering judgment. For the years prior to 1981,
no control efficiency was applied to the activity data to estimate TSP emissions from potash production.
The PM-10 control efficiencies for coal mining thermal dryers, stone and rock crushing, phosphate
rock production processes, clay production, and potash production for the years 1975 through 1984 were
based on the 1988 PM-10 control efficiencies obtained from Reference 26. During these years, any
changes in the corresponding TSP control efficiencies from the 1985 TSP control efficiency value were
reflected in the PM-10 control efficiencies. For the years 1940 through 1974, no control efficiencies
were used to estimate PM-10 emissions.
3.30.4.2.3 Chemical Industry —
For rock pulverization, the TSP control efficiencies for the years 1974 through 1984 were obtained
from Reference 22. For the years prior to 1974, no procedure to determined the TSP control efficiencies
is currently available.
The PM-10 control efficiencies for rock pulverization for the years 1975 through 1984 were equal to
the 1988 PM-10 control efficiency obtained from Reference 26. For the years 1940 through 1974, no
control efficiencies were use to estimate PM-10 emissions.
3.30.5 References
1. Asphalt Usage United States & Canada. The Asphalt Institute, College Park, MD. Annual.
2. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
3. Minerals Industry Surveys, Cement. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Monthly.
(a) Table entitled, "Portland Cement Shipments in 19xx, by District of Origin & Type of
Customer."
4. Current Industrial Reports, Flat Glass. Bureau of the Census, U.S. Department of Commerce,
Washington, DC. Annual.
5. Current Industrial Reports, Glass Containers. Bureau of the Census, U.S. Department of
Commerce, Washington, DC. Annual.
6. Current Industrial Reports, Clay Construction Products. Bureau of the Census, U.S. Department of
Commerce, Washington, DC. Annual.
(a) Table entitled, "Production and Shipments of Clay Construction Products."
7. Minerals Yearbook, Clays. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-165 Category: 07-05
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8. Current Industrial Reports, Fibrous Glass. Bureau of the Census, U.S. Department of Commerce,
Washington, DC. Annual.
9. Minerals Industry Surveys, Gypsum. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Monthly.
10. Coal Production. DOE/EIA-0118(xx). Energy Information Administration, U.S. Department of
Energy, Washington, DC. Annual.
a. Table entitled, "Shipments of Bituminous Coal and Lignite by District, Consumer, Use,
Average Sulfur Content - 1977."
11. Quarterly Coal Report: January - March. DOE/EIA-0121 (xx/1Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Quarterly.
12. Minerals Yearbook, Sand and Gravel. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Annual.
13. Minerals Industry Surveys, Stone (Crushed and Dimension). Bureau of Mines, U.S. Department of
the Interior, Washington, DC. Monthly.
14. Minerals Yearbook, Phosphate. Bureau of Mines, U.S. Department of the Interior, Washington,
DC. Annual.
a. Table entitled, "Table 2, Production of Phosphate Rock in the U.S. by Region"
15. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 8.15-1
b. Volume I, Table 8.6-1
c. Volume I, Table 8.13-1
d. Volume I, Table 8.3-1
e. Volume I, Table 8.8-1
f. Volume I, Table 8.10-1
g. Volume I, Table 8.11-1
h. Volume I, Table 8.15-1
i. Volume I, Table 8.9-1
j. Volume I, Table 8.18-1
k. Volume I, Table 8.7-1
16. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park,NC. February 9, 1980.
17. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-166 Category: 07-05
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18. Assessment of Fugitive Paniculate Emission Factors for Industrial Processes. EPA-450/3-78-107.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1978.
19. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
20. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
21. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Volume I, Table 8.11-1
b. Volume I, Table 8.14-1
c. Volume I, Section 8.19.1
d. Volume I, Table 8.20-1
22. Summary of Paniculate and Sulfur Oxide Emission Reductions Achieved National for Selected
Industrial Source Categories. EPA-340/1-76-0086. U.S. Environmental Protection Agency,
Washington, DC. November 1976.
23. Coal Distribution: January-December 19xx. DOE/EIA-0125(xx/4Q). U.S. Department of Energy,
Washington, DC. Annual.
a. Table entitled, "Domestic Distribution of U.S. Coal by Origin, Destination, and Consumer:
January-December 19xx."
24. Minerals Yearbook, Coal. Bureau of Mines, U.S. Department of the Interior, Washington, DC.
Annual.
25. Heating Oils. U.S. Department of Energy. Obtainable from the National Institute for Petroleum and
Energy Research, ITT Research Institute, P.O. Box 2128, Bartlesville, OK. Annual.
26. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
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Table 3.30-1. NOX Emission Factor SCCs and Weighting Factors
for Glass Manufacturing
SCC
Description
Weighting Factor
3-05-014-02
3-05-014-03
3-05-014-04
Container Glass: Melting Furnace
Flat Glass: Melting Furnace
Blown Glass: Melting Furnace
0.75
0.15
0.10
Table 3.30-2. PM-10 and TSP Emission Factor SCCs
for Kilns Used in Brick Manufacturing
SCC
Description
3-05-003-11 Curing and firing - gas fired tunnel kiln
3-05-003-12 Curing and firing - oil fired tunnel kiln
3-05-003-13 Curing and firing - coal fired tunnel kiln
3-05-003-14 Gas fired periodic kiln
3-05-003-15 Oil fired periodic kiln
3-05-003-16 Coal fired periodic kiln
Table 3.30-3. PM-10 and TSP Emission Factor SCCs
for Clay Sintering
SCC
Description
3-05-009-03 Raw clay sintering
3-05-009-04 Crushing and screening
3-05-009-05 Transfer and conveying
Storage
3-05-009-08 Finished product processing & screening
Table 3.30-4. PM-10 and TSP Emission Factor SCCs
for Fiber Glass Furnaces
SCC
Description
3-05-012-01
3-05-012-02
3-05-012-03
3-05-012-07
3-01-012-11
3-05-012-12
3-05-012-13
Glass Furnace Wool - Regenerative
Glass Furnace Wool - Recuperative
Glass Furnace Wool - Electric
Glass Furnace Wool - Unit Melter
Glass Furnace Textile - Regenerative
Glass Furnace Textile - Recuperative
Glass Furnace Textile - Unit Melter
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Table 3.30-5. PM-10 and TSP Emission Factor SCCs
for Stone and Rock Crushing
SCC Description
3-05-020-01 Primary Crushing
3-05-020-02 Secondary Crushing
3-05-020-03 Tertiary Crushing
3-05-020-04 Recrushing/Screening
3-01-020-06 Miscellaneous Operations
Table 3.30-6. Uncontrolled SO2 Emissions Factors for Cement Manufacturing
Fuel Emission Factor
Mineral Source 10.2 Ib/ton cement produced
Coal 30.45 Ib/ton coal consumed
Residual Oil 124.5 lb/1,000 gal residual oil consumed
Distillate Oil 112.35 lb/1,000 gal distillate oil consumed
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3.31 SOLVENT UTILIZATION - DECREASING: 08-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category
(08) SOLVENT UTILIZATION (01) Degreasing
3.31.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source category
listed above. Emissions were estimated only for VOC from an activity indicator and emission factor. In
order to utilize these values in the Trends spreadsheets, the activity indicator was expressed in thousand
short tons and the emission factor was expressed in metric pounds/short ton.
The procedures for determining the activity indicator and emission factor were used for the years
1940, 1950, 1960, and 1970 through 1984.
3.31.2 Activity Indicator
The activity indicator for degreasing was the weighted sum of the total consumption of six solvents
as reported in References 1, 2, and 3. These solvents are listed in Table 3.31-1, along with the
corresponding weighting factors, expressed as percentages, and references for consumption information.
Activity = (S1. x [/.) (Eq. 3.31-1)
z = l
where: S; = total production/sales of solvent
U; = fraction of S; for end use as degreasing solvent (the "weighting factor" of Table 3.3 1-
1)
3.31.3 Emission Factor
For this category, it was assumed that all of the solvents evaporated. Therefore, the VOC emission
factor for degreasing was 2,000 Ib/ton.
3.31.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from degreasing.
3.31.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-170 Category: 08-01
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2. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
3. Synthetic Organic Chemicals, United States Production and Sales. USITC Publication 1745. U.S.
International Trade Commission, Washington, DC. Annual.
Table 3.31-1. Solvents and Weighting Factors for
Degreasing
Solvent
Special Naphtha
Perchloroethylene
Trichloroethylene
Monochlorobenzene
Cyclohexanone
Ethylene Butyl (EB) Glycol
Ether
Weighting
Factor (%)
6.7
16.3
98
20
1
9
Consumption
References
1
2
3
3
3
3
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3.32 SOLVENT UTILIZATION - GRAPHIC ARTS: 08-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category
(08) SOLVENT UTILIZATION (02) Graphic Arts
3.32.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source category
listed above. Emissions were estimated only for VOC from an activity indicator and emission factor. In
order to utilize these values in the Trends spreadsheets, the activity indicator was expressed in thousand
short tons and the emission factor was expressed in metric pounds/short ton.
The procedures for determining the activity indicator and emission factor were used for the years
1940, 1950, 1960, and 1970 through 1984.
3.32.2 Activity Indicator
The activity indicator for graphics arts was the weighted sum of the total consumption of four
solvents, as reported in References 1, 2, and 3. These solvents are listed in Table 3.32-1, along with the
corresponding weighting factors, expressed as percentages, and references for consumption information.
To account for miscellaneous solvent usage, 1.8 percent of the weighted sum was added to obtain the
final activity.
Activity = (S1. x [/.) (Eq. 3.32-1)
z = l
where: S; = total production/sales of solvent
U; = fraction of S; for end use as degreasing solvent (the "weighting factor" of Table 3.32-
1)
3.32.3 Emission Factor
For this category, it was assumed that all of the solvents evaporated. Therefore, the VOC emission
factor for graphic arts was 2,000 Ib/ton.
3.32.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from graphic
arts.
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3.32.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
2. Synthetic Organic Chemicals, United States Production and Sales. USITC Publication 1745. U.S.
International Trade Commission, Washington, DC. Annual.
3. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
Table 3.32-1. Solvents and Weighting Factors for Graphic Arts
Solvent
Special Naphtha
Ethyl Acetate
Ethyl Benzene
Ethylene Ethyl (EE) Glycol
Ether
Weighting
Factor
6.4
20.0
0.025
5.0
Consumption
References
1
2
3
2
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-173
1940-1984 Methodology
Category: 08-02
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3.33 SOLVENT UTILIZATION - DRY CLEANING: 08-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category
(08) SOLVENT UTILIZATION (03) Dry Cleaning
3.33.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source category
listed above. Emissions were estimated only for VOC from an activity indicator and emission factor. In
order to utilize these values in the Trends spreadsheets, the activity indicator was expressed in thousand
short tons and the emission factor was expressed in metric pounds/short ton.
The procedures for determining the activity indicator and emission factor were used for the years
1940, 1950, 1960, and 1970 through 1984.
3.33.2 Activity Indicator
The activity indicator for dry cleaning was the weighted sum of the total consumption of two
solvents, as reported in References 1 and 2. These solvents are listed in Table 3.33-1, along with the
corresponding weighting factors, expressed as percentages, and references for consumption information.
3.33.3 Emission Factor
For this category, it was assumed that all of the solvents evaporated. Therefore, the VOC emission
factor for dry cleaning was 2,000 Ib/ton.
3.33.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from dry
cleaning.
3.33.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
2. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-174 Category: 08-03
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Table 3.33-1. Solvents and Weighting Factors for Dry Cleaning
Weighting Consumption
Solvent Factor (%) References
Special Naphtha 2.0 1
Perchloroethylene (93.4%) 58.9 2
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-175 Category: 08-03
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3.34 SOLVENT UTILIZATION - SURFACE COATINGS: 08-04
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(08) SOLVENT UTILIZATION (04) Surface Coatings Architectural Coating
Auto Refinishing
Adhesives
Other Solvent Use
3.34.1 Technical Approach
The VOC emissions included in this Tier category were the sum of the emissions from the source
categories listed above, except for the other solvent use subcategory. One-half of the VOC emissions for
this subcategory are included in this Tier II category. Emissions were estimated only for VOC from an
activity indicator and emission factor. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in thousand short tons and emission factors were expressed in metric
pounds/short ton.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984.
3.34.2 Activity Indicator
The activity indicator for adhesives was the weighted sum of the total consumption of the three
following solvents: special naphtha, methyl ethyl ketone (MEK), and methyl isobutyl ketone (MIBK).
The consumption data for special naphtha was obtained from Reference 1, MEK was obtained from
Reference 2, and MIBK was obtained from Reference 3. The weighting factors for the three solvents
were 1, 2.1, and 0.7, respectively. The activity indicator for this source category was the sum of the
weighted consumption values.
The activity indicator for architectural coating processes was based on the quantity of paint shipped
obtained from Reference 4 for the paint types listed in Table 3.34-1. The quantity of paint shipped was
multiplied by the corresponding solvent content given in Table 3.34-1 for each paint type. The solvent
content for the architectural coatings n. s. k. type was the weighted average of the solvent content values
for the other architectural coating paint types subcategories. The weighting factors were the ratio of the
quantity of paint shipped for the specific paint type divided by the total quantity of paint shipped for all of
the architectural coating paint types. The activity indicator for this source category was the total amount
of solvent contained in the total quantity of paint shipped for all paint types.
The activity indicator for auto refinishing was the quantity of paint shipped multiplied by a solvent
content value of 11.95 Ib/gal. The quantity of paint shipped was obtained from Reference 4 under the
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-176 Category: 08-04
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category "Automotive, other transportation and machinery refinish paints, and enamels, including
primers."
The activity indicator for other solvent uses was based on the production of the solvents listed in
Table 3.34-2, along with the references for these data values. The production values were converted to
gallons and then to pounds using the conversion factors 43 gallons/barrel and 6.5 pounds/gallon,
respectively. Each solvent production value was multiplied by the corresponding percentage
consumption presented in Table 3.34-2 to obtain the solvent consumption. The values presented in Table
3.34-2 under "Solvent Consumption" were used when the referenced data was unavailable. The amount
of each solvent included in this source category was the product of the solvent consumption and the
corresponding percent miscellaneous solvent presented in Table 3.34-2. These products were summed
and an additional 1.8 percent was added to account for miscellaneous solvents. This final result was the
activity indicator for the other solvent use subcategory.
The activity indicators for the fourteen surface coating operations listed in Table 3.34-3 were based
on the quantity of paint shipped obtained from Reference 4. For aircraft, railroads, and other metal
products, the quantity of paint shipped was multiplied by 72.7, 27.3, and 6.5, respectively, to determine
the quantity of paint included in those subcategories. The quantity of paint shipped was multiplied by the
corresponding solvent content given in Table 3.34-3 for operation. The activity indicator for
maintenance coatings subcategory was the sum of the activity for the interior and exterior paints as listed
in Table 3.34-3.
The activity indicator for fabric coating operations was based on the textile production index
obtained from Reference 1 or Reference 2. The index for 1983 and 1984 was multiplied by an adjustment
factor of 3.96.
The activity indicator for plastics parts surface coating operations was based on the rubber and
plastic production index obtained from Reference 1 or Reference 2. The index for 1983 and 1984 was
multiplied by an adjustment factor of 0.59. For the years 1970 through 1982, the annual indicies were
multiplied by an adjustment factor of 0.254. Prior to 1970, the activity was assumed to be zero for
plastics parts coating surface.
The activity indicator for paper coating operations was the quantity of solvents used in the
production of paper and in the production of pressure tape and labels. The amount of solvents used in
the production of paper was based on the quantity of paper produced as reported in Reference 4 under
the classification "paper, paperboard, film and foil finishes". This production value was multiplied by the
solvent content value of 38.8 Ib/gal to obtain the quantity of solvent used in the production of paper.
The quantity of solvents used in the production of pressure tape and labels was based on the
consumption of the four solvents listed in Table 3.34-4. The quantity of each solvent produced was
obtained from the references provided in Table 3.34-4. Each production value was multiplied by the
percent consumption to determine the quantity of solvent consumed and the percent of solvent use to
determine the amount of each solvent used in the production of pressure tape and labels. These values
are presented in Table 3.34-4. The total quantity of solvents used was the sum of the quantities of the
individual solvents.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-177 Category: 08-04
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The final activity indicator for paper coating operations was the sum of the quantity of solvent used
in the production of paper and in the production of pressure tape and labels.
The activity indicator for miscellaneous surface coating processes was sum of the quantities of
solvents used for the three processes listed in Table 3.34-5 and the quantity of solvent "slop". The
quantities of solvents used for the three processes listed in Table 3.34-5 were calculated from the quantity
of paint shipped for each process obtained from Reference 4. Each of these production values were
multiplied by the corresponding percentage of solvent consumed and solvent content. The resulting
solvent quantities were summed over the three processes.
To this total was added solvent "slop". This quantity was based on the difference between the
following two values: (1) total quantity of specific solvents consumed by surface coating operations and
(2) quantity of solvents consumed by all within the surface coating operations. The first value was based
on the production level of each solvent listed in Table 3.34-6 as reported in the references indicated.
Production values were converted to gallons and then to pounds using the conversion factors 43
gallons^arrel and 6.5 pounds/gallon, respectively. Each solvent production value was multiplied by the
corresponding percentage consumption presented in Table 3.34-6 to obtain the solvent consumption.
The values presented in Table 3.34-6 under "Solvent Consumption" were used when the referenced data
was unavailable. The amount of each solvent included was the product of the solvent consumption and
the corresponding percent surface coating use presented in Table 3.34-6. These products were summed
and an additional 1.8 percent was added to account for miscellaneous solvents. This final result was the
total quantity of solvents consumed by surface coating operations.
The second value was the sum of the quantity of solvents consumed for operations listed in Table
3.34-7. In some cases, the solvents consumed by specific processes are excluded. The solvent "slop"
value was calculated by subtracting this second value from the first value, as described above.
The final activity indicator for the miscellaneous surface coating processes was the sum of the
quantity of solvents consumed by the three specific processes and from solvent "slop."
3.34.3 Emission Factor
For all source categories included in this Tier II category, it was assumed that all of the solvents
evaporated completely. Therefore, the VOC emission factors for all operations were 2,000 Ib/ton.
Beginning in 1970, the emission factors for the following operations were scaled by annual average
control efficiencies: large appliances, magnet wire, automobiles, cans, metal coils, paper, fabric, metal
furniture, wood furniture, plastic parts, aircraft, machinery, other metal products, and miscellaneous
processes. An adequate procedure for determining the individual control efficiencies applied to the
emission factors for each opeation is currently unavailable.
3.34.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from surface
coating operations included in this Tier II category.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-178 Category: 08-04
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3.34.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
2. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
3. Synthetic Organic Chemicals, United States Production and Sales. USITC Publication 1745. U.S.
International Trade Commission, Washington, DC. Annual.
4. Current Industrial Reports, Paint and Allied Products. Bureau of the Census, U.S. Department of
Commerce, Washington, DC. Annual.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-179 Category: 08-04
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Table 3.34-1. Determination of Activity Indicator for Architectural
Coating Processes: Paint Types
Paint Type Category
Paint Type Subcategory
Solvent Content
(Ib/gal)
Architectural Coatings
Traffic marking paints
Special purpose coatings n.s.k.
Aerosols
Exterior Solvent Type
Exterior Water Type
Interior Solvent Type
Interior Water Type
Architectural lacquers
Architectural coatings n.s.k.
36
.54
3.3
.56
5
a
3.89
5
5
Table 3.34-2. Determination of Activity Indicator for Miscellaneous
Organic Solvent Extraction (other solvent use): Included Solvents
Solvent
Production % Solvent Solvent
Compound Reference Consumption Consumption*
Special Naphthas
n-Butanol
Isobutanol
Butyl Acetates
Perchloroethylene
p-dichlorobenzene
Ethanol
Ethylene Butyl (EB)
Glycol Ether
Diethylene Methyl
(DM) Glycol Ether
Isopropanol
Methanol
Miscellaneous**
1
2
3
3
2
3
2
3
3
2
2
100
100
100
84.2
93.4
100
100
100
100
42
95.3
5461 .6
1269.0
181.207
212.4
358.7
90.3
549.0
413.0
46.9
579.6
7610.7
565.9
% Other
Solvent
Use
5.2
0.4
3.1
40
1
90
35.6
7
30
21.4
2.8
Use default values used in the event that more appropriate numbers are not available.
Compute Miscellaneous solvents consumption as 1.8 percent of the total consumption
of all other solvents
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-180
1940-1984 Methodology
Category: 08-04
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Table 3.34-3. Determination of Activity Indicators for 14 Surface Coating
Operations: Solvent Contents and Reference 4 Categories
Surface Coating
Operation
Large Appliances
Magnet Wire
Automobiles
Cans
Metal Coils
Metal Furniture
Wood Furniture
Flat Wood Products
Large ships
Machinery
Maintenance Coatings
Aircraft
Railroads
Other Metal Products
Reference 4 Category
Appliance, heating equipment, & air conditioner finishes
Electrical insulating coatings
Automobile finishes
Container and closure finishes
Sheet, strip, and coil coatings, including siding
Nonwood furniture and fixture finishes, including business
equipment finishes
Wood furniture, cabinet, and fixture finishes
Wood and composition board flat stock finishes
Marine Paints
Machinery and equipment finishes, including road building
equipment and farm
Industrial new construction & maintenance paints: Interior
Industrial new construction & maintenance paints: Exterior
Other Transportation Equipment
Other Transportation Equipment
Other Industrial Product Finishes
Solvent
Content
(Ib/gal)
7.35
8.48
6.95
4.93
3.15
8.61
20.78
4.50
5.65
6.63
5.66
6.30
0.5
3.83
19.98
Table 3.34-4. Determination of Activity Indicator for Production of Pressure Tape and
Labels: Solvents Used
Solvent Category
Reference
% Solvent
Consumption
% Solvent Use
Special Naphthas
Butyl Acetate
Methyl ethyl ketone (MEK)
Methyl isobutyl ketone (MIBK)
2
4
3
4
100
84.2
100
100
10.3
42.3
15.8
4.2
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-181
1940-1984 Methodology
Category: 08-04
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Table 3.34-5. Determination of the Activity Indicator for
Miscellaneous Surface Coating Operations: Solvent Use in Three
Processes
Process by Reference 4 category
Other Industrial Product Finishes
Product Finishes for OEM (n.s.k.)
Truck, bus, and RV
% Solvent
Consumed
93.5
100.0
100.0
Solvent Content
(Ib/gal)
19.98
19.98
6.95
Table 3.34-6. Determination of Activity Indicator for Miscellaneous Surface Coatings
Operations: Solvent Consumptions for Determination of Solvent "Slop"
Solvent % Solvent Solvent % Surface
Compound Production Consumption Consumption* Coating Use
Reference
Special Naphthas
Acetone
n-Butanol
Isobutanol
Butyl Acetates
Cyclohexanone
Ethyl Acetate
Ethanol
Ethylbenzene
Propylene Glycol
Ethylene Methyl Glycol Ether
Ethylene Ethyl Glycol Ether
Ethylene Butyl Glycol Ether
Diethylene Methyl Glycol Ether
Diethylene Ethyl Glycol Ether
Diethylene Butyl Glycol Ether
Isopropanol
Methyl Ethyl Ketone (MEK)
Methyl Isobutyl Ketone (MIBK)
Miscellaneous**
2
3
3
4
4
4
4
3
3
3
4
4
4
4
4
4
3
3
4
100
89
100
100
84.2
100
70
100
100
100
100
100
100
100
100
100
42
100
100
5461.6
1976.7
1269.0
181.207
212.4
1043.64
190.5
549.0
8987.0
800.0
83.493
117.8
413.0
46.9
38.1
9037
579.6
473.0
426.9
565.9
48.7
15.4
15.3
16.7
60
3.5
65
17.1
0.4
5.7
47
40
52
70
50
30
21.2
85.4
71.9
Use default values in the event that more appropriate numbers are not available.
" Compute Miscellaneous solvents consumption as 1.8 percent of the total consumption of all other solvents.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-182
1940-1984 Methodology
Category: 08-04
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Table 3.34-7. Determination of Activity Indicator for Miscellaneous Surface Coatings
Operations: Solvent Consumptions for All Surface Coating Operations for the
Determination of Solvent "Slop"
Category
Subcategory
Excluded Sources
Surface Coating Operations
Miscellaneous Organic Solvent Extraction
Large Appliances
Automobiles
Cans
Metal Coils
Paper
Metal Furniture
Wood Furniture
Flat Wood Products
Large Ships
Aircraft
Railroads
Machinery
Other Metal Products
Miscellaneous Processes
Maintenance Coatings
Architectural Coatings
Auto Refinishing
Pressure Tapes & Labels
Solvent "slop"
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-183
1940-1984 Methodology
Category: 08-04
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3.35
SOLVENT UTILIZATION - OTHER INDUSTRIAL: 08-05
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category
(08) SOLVENT UTILIZATION (05) Other Industrial
Tier II Subcategory
Waste Solvent Recovery
Miscellaneous Organic Solvent
Use
Solvent Extraction
Plastics Manufacturing -
fabrication
3.35.1 Technical Approach
The VOC emissions included in this Tier category were the sum of the emissions from the waste
solvent recovery source category multiplied by 0.78 and the emissions from the other source categories
listed above. Emissions were estimated only for VOC from an activity indicator and emission factor. In
order to utilize these values in the Trends spreadsheets, activity indicators were expressed in thousand
short tons and emission factors were expressed in metric pounds/short ton.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984.
3.35.2 Activity Indicator
The activity indicator for waste solvent recovery processes was assumed to be zero.
The activity indicator for miscellaneous organic solvent uses was the weighted sum of the total
consumption of eight solvents, as reported in References 1, 2, and 3. These solvents are listed in Table
3.35-1, along with the corresponding weighting factors, expressed as percentages, and references for
consumption information. To account for miscellaneous solvent usage, 7.1 percent of the weighted sum
was added to obtain the final activity.
The activity indicator for solvent extraction processes was the weighted sum of the total
consumption of two solvents, as reported in References 1, 2, and 3. These solvents are listed in Table
3.35-2, along with the corresponding weighting factors, expressed as percentages, and references for
consumption information.
The activity indicator for plastics fabrication processes was the weighted sum of the total
consumption of three solvents, as reported in References 1, 2, and 3. These solvents are listed in Table
3.35-3 along with the corresponding weighting factors, expressed as percentages, and references for
consumption information.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-184
1940-1984 Methodology
Category: 08-05
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3.35.3 Emission Factor
The VOC emission factor for waste solvent recovery processes was the sum of the emission factors
for the five sources presented in Table 3.35-4. These emission factors were obtained from Reference 4a.
For miscellaneous organic solvent uses, solvent extraction processes, and plastics fabrication
processes it was assumed that all of the solvents evaporated completely. Therefore, the VOC emission
factors for these categories were 2,000 Ib/ton.
3.35.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from the source
included in this Tier II category.
3.35.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
2. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
3. Synthetic Organic Chemicals, United States Production and Sales. USITC Publication 1745. U.S.
International Trade Commission, Washington, DC. Annual.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 4.7-1
Table 3.35-1. Determination of Activity Indicator for Miscellaneous Organic Solvent
Uses: Solvents, Weighting Factors, and References
Solvent
Special Naphtha
Acetone (89.0%)
O-Dichloro-benzene
Ethanol
Ethylbenzene
Ethylene Ethyl (EE) Glycol Ether
Ethylene Butyl (EB) Glycol Ether
Methanol (95.3%)
Weighting Factor
(%)
1
0.5
25
5.8
0.075
12
12
4.7
Consumption References
1
2 or 3
2 or 3
2
2
3
3
2
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-185 Category: 08-05
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Table 3.35-2. Determination of Activity Indicator for Solvent
Extraction Processes: Solvents, Weighting Factors, and References
Weighting
Solvent Factor (%) Consumption References
Methyl Ethyl Ketone (MEK) 12.5 2
Methyl Isobutyl Ketone (MIBK) 8.9 3
Table 3.35-3. Determination of Activity Indicator for Plastics Fabrication Processes:
Solvents, Weighting Factors, and References
Solvent
Special Naphtha
Ethyl Acetate
Ethylbenzene
Weighting
Factor (%)
6.5
12
0.25
Consumption References
1
3
2
Table 3.35-4. VOC Emission Factor SCCs for Waste Solvent
Recovery Processes
SCC Description
4-90-002-01 Storage Tank Vent
4-90-002-02 Condenser Vent
4-90-002-03 Incinerator Stack
4-90-002-04 Solvent Spillage
4-90-002-05 Solvent Loading
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-186 Category: 08-05
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3.36 SOLVENT UTILIZATION - NONINDUSTRIAL: 08-06
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(08) SOLVENT UTILIZATION (06) Nonindustrial Fabric Scouring
Cutback Asphalt Paving
Pesticides
Other Solvent Use
3.36.1 Technical Approach
The VOC emissions included in this Tier category were the sum of the emissions from the source
categories listed above, except for the other solvent use category. One-half of the VOC emissions for
this source category are included in this Tier II category. Emissions were estimated only for VOC from
an activity indicator and emission factor. In order to utilize these values in the Trends spreadsheets,
activity indicators were expressed in thousand short tons and emission factors were expressed in metric
pounds/short ton.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984.
3.36.2 Activity Indicator
The activity indicator for fabric scouring was the consumption of perchloroethylene, obtained from
Reference 1, multiplied by 0.062.
The activity indicator for cutback asphalt paving were based on the total quantity of cutback asphalt
obtained from Reference 2. For years since 1980, production figures for cutback paving asphalts
reported in Reference 3 were used to update the 1980 emissions. It was assumed that the 1980 emissions
were proportional to changes in cutback paving asphalt production.
The activity indicator for pesticides was the weighted sum of the total consumption of six solvents,
as reported in References 4 and 5. These solvents are listed in Table 3.36-1, along with the
corresponding weighting factors, expressed as percentages, and references for consumption information.
The activity indicator for other solvent uses was based on the consumption of eleven solvents, as
reported in References 4 and 5. These solvents are listed in Table 3.36-2, along with the corresponding
references for the consumption information. Consumption value for each solvent was converted to
million pounds by using the following conversion factors: 42 gallons/barrel and 6.5 pounds/gallon. The
consumption data for each solvent was multiplied by the general consumption weighting factor and by the
miscellaneous solvent use weighting factor in order to obtain the consumption of each solvent included
within this category. Weighted solvent consumptions were summed and an additional 1.8 percent was
added to account for miscellaneous solvent use.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-187 Category: 08-06
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3.36.3 Emission Factor
For all sources included in this Tier II category, it was assumed that solvents evaporated completely.
Therefore, the VOC emission factors for fabric scouring, cutback asphalt paving, pesticides, and other
solvent uses.
3.36.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from the source
included in this Tier II category.
3.36.5 References
1. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
2. Energy Data Reports, Sales of Asphalt in 1980. U.S. Department of Energy, Washington, DC.
June 1981.
3. Asphalt Usage United States & Canada. The Asphalt Institute, College Park, MD. Annual.
4. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
5. Synthetic Organic Chemicals, United States Production and Sales. USITC Publication 1745. U.S.
International Trade Commission, Washington, DC. Annual.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-188 Category: 08-06
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Table 3.36-1. Determination of Activity Indicator for
Pesticides: Solvents, Weighting Factors, and References
Solvent
Special Naphthas
Isobutanol
m-chlorobenzene
Ethyl Benzene
Ethylene Butyl (EB) Glycol
Ether
Methyl Isobutyl Ketone (MIBK)
Weighting
Factor (%)
3.3
3.2
30.0
0.19
13.0
2.3
Consumption
References
4
5
5
1
5
5
Table 3.36-2. Determination of Activity Indicator for Other Solvent Uses of
Miscellaneous Organic Solvents: Solvents, Weighting Factors, and References
General Consumption Miscellaneous
Weighting Consumption Consumption
Solvent Factor (%) Weighting Factor (%) References
Special Naphthas
n-Butanol
Isobutanol
Butyl Acetates
Perchloroethylene
p-dichlorobenzene
Ethanol
Ethylene Butyl (EB)
Glycol Ether
Diethylene Methyl (DM)
Glyco Ether
Isopropanol
Methanol
100
100
100
84.2
93.4
100
100
100
100
42
95.3
5.2
0.4
3.1
40.0
1.0
90.0
35.6
7.0
30.0
21.4
2.8
4
1
5
5
1
5
1
5
5
1
1
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-189
1940-1984 Methodology
Category: 08-06
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3.37 STORAGE AND TRANSPORT - BULK TERMINALS AND PLANTS: 09-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category
(09) STORAGE AND (01) Bulk Terminals and Plants
TRANSPORT
3.37.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source categories
listed above. Emissions were estimated only for VOC from an activity indicator, emission factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in million barrels and emission factors were expressed in metric
pounds/thousand barrels. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984.
3.37.2 Activity Indicator
The activity indicators for bulk gasoline terminal transfer and storage were the production of finished
motor gasoline obtained from Reference la. This quantity was reported under the heading "Disposition:
Products Supplied."
The activity indicators for bulk gasoline plant transfer and storage were 30 percent of the production
of finished motor gasoline obtained from Reference la. This quantity was reported under the heading
"Disposition: Products Supplied."
3.37.3 Emission Factor
For the years 1970 through 1984, the emission factors for all source categories included in this Tier
II category were based on 1980 emissions data obtained from Reference 2 and 1979 production data
from Reference 1. A more detailed procedure is currently unavailable.
For the years 1960, 1950, and 1940, the emission factors for all source categories, except for
transport at bulk gasoline terminals, steadily increased from the 1970 value. No procedure for
determining these emission factors is currently available.
3.37.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from transfer
and storage at gasoline bulk plants. For the years 1974 through 1984, control efficiencies were applied to
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-190 Category: 09-01
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the activity data to estimate emissions from transfer and storage at gasoline bulk terminals. No procedure
for determining these control efficiencies is currently available.
3.37.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Supply and Disposition of Crude Oil and Petroleum Products."
2. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. June 12, 1980.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-191 Category: 09-01
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3.38 STORAGE AND TRANSPORT - PETROLEUM AND PETROLEUM PRODUCT
STORAGE: 09-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(09) STORAGE AND (02) Petroleum and Petroleum Gasoline Storage at Refineries
TRANSPORT Product Storage Crude Oil Storage - oil field
storage and refinery storage
Other Products - jet naphtha
storage, jet naphtha transfer,
kerosene storage, and distillate
oil storage
3.38.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source categories
listed above. Emissions were estimated only for VOC from an activity indicator, emission factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in million barrels and emission factors were expressed in metric
pounds/thousand barrels. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984.
3.38.2 Activity Indicator
The activity indicator for gasoline storage at refineries was the production of finished gasoline
obtained from Reference la.
The activity indicators for crude oil field storage was the total U.S. field production including lease
condensate obtained from Reference Ib.
The activity indicators for crude refinery storage was the crude oil input to refineries obtained from
Reference Ic.
The activity indicators for both jet naphtha transfer and jet naphtha storage were the production of
naphtha-type jet fuel obtained from Reference Ic. The activity indicators for kerosene storage was the
sum of kerosene-type jet fuel and kerosene obtained from Reference Ic. The activity indicator for
distillate oil storage was the quantity of distillate fuel oil obtained from Reference Ic. These quantities
were reported under the heading "Disposition: Products Supplied."
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-192 Category: 09-02
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3.38.3 Emission Factor
For the years 1970 through 1984, the emission factors for crude oil storage at refineries, gasoline
storage at refineries, jet naphtha storage, jet naphtha transfer, kerosene storage, and distillate oil storage
were based on 1980 emissions data from Reference 2 and 1979 petroleum production data from
Reference 1. A more detailed procedure is currently unavailable.
For the years 1960, 1950, and 1940, emission factors for crude oil storage at refineries and gasoline
storage at refineries steadily increased from the 1970 value. The emission factors of the other sources
listed above remained constant at the 1970 value. No procedure for determining these changing emission
factors is currently available.
For the years 1970 through 1984, the emission factor for crude oil storage at oil fields was based on
the typical losses from storage tank types. The losses were calculated using equations and typical values
from Reference 3. The losses from the different tank types were weighted based on data from Reference
2. A more detailed procedure is currently unavailable. The emissions factors for the years 1960, 1950,
and 1940 increased steadily over the 1970 value. No procedure for determining these emission factors is
currently available.
3.38.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from the source
included in this Tier II category, except for gasoline storage at refineries. For the years 1974 through
1984, control efficiencies were applied to the activity data to estimate emissions from gasoline storage at
refineries. No procedure is currently available to determine these control efficiencies.
3.38.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Refinery Production of Petroleum Products by PAD District."
b. Table 1
c. Table entitled, "Supply and Disposition of Crude Oil and Petroleum Products."
2. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. June 12, 1980.
3. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-193 Category: 09-02
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3.39 STORAGE AND TRANSPORT - PETROLEUM AND PETROLEUM PRODUCT
TRANSPORT: 09-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(09) STORAGE AND (03) Petroleum and Petroleum Refinery Product Loading-
TRANSPORT Product Transport gasoline tank car and tanker and
barge
Crude Oil Loading - tank car/
truck, ship and barge, and tanker
ballasting
3.39.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source categories
listed above. Emissions were estimated only for VOC from an activity indicator, emission factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in million barrels and emission factors were expressed in metric
pounds/thousand barrels. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984.
3.39.2 Activity Indicator
The activity indicator for refinery product loading of tankers and barges was the total movement of
finished motor gasoline between the following PAD districts: from PAD III to PAD I, from PAD II to
PAD II, from PAD III to PAD V, and from PAD V to PAD III. This information was obtained from
Reference la.
The activity indicator for refinery product loading of gasoline tank cars was assumed to be 3.35
percent of the total U.S. production of finished gasoline obtained from Reference Ib.
The activity indicator for crude oil loading of tank cars/trucks was the total receipts of domestic tank
cars and domestic trucks. The activity indicator for ship and barge loading was the total receipts of
domestic crude oil on tankers and barges. The activity indicator for the tanker ballasting was one-half of
the total receipts of domestic crude oil on tankers and barges added to the total receipts of foreign crude
oil on tankers and barges. Information required for these activity indicators was obtained from Reference
Ic.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-194 Category: 09-03
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3.39.3 Emission Factor
The emission factors for all sources included in this Tier II category were based on 1980 emissions
data from Reference 2 and 1979 petroleum production data from Reference 1. The emission factors were
constant for all years. More detailed procedures are currently unavailable.
3.39.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from the source
included in this Tier II category, except for gasoline transfer at refineries. For the years 1974 through
1984, control efficiencies were applied to activity to estimate emissions from gasoline transfer at
refineries. No procedure for determining these control efficiencies is currently available.
3.39.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Movements of Crude Oil and Petroleum by Tanker and Barge Between PAD
District."
b. Table entitled, "Refinery Production of Petroleum Products by PAD District."
c. Table entitled, "Refinery Receipts of Crude Oil by Method of Transportation."
2. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. June 12, 1980.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-195 Category: 09-03
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3.40 STORAGE AND TRANSPORT - SERVICE STATIONS: STAGE I: 09-04
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(09) STORAGE AND (04) Service Stations: Gasoline Service Stations -
TRANSPORT Stage I loading or stage I
3.40.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source categories
listed above. Emissions were estimated only for VOC from an activity indicator, emission factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, the
activity indicator was expressed in million barrels and the emission factor was expressed in metric
pounds/thousand barrels. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984.
3.40.2 Activity Indicator
The activity indicator for gasoline service station loading or stage I was the production of finished
motor gasoline obtained from Reference la. This quantity was reported under the heading "Disposition:
Products Supplied."
3.40.3 Emission Factor
The emission factor for gasoline service station loading for the years 1970 through 1984 was based
on the 1980 emission data from Reference 2 and 1979 petroleum production data from Reference 1. A
more detailed procedure is currently unavailable.
For the years 1960, 1950, and 1940, the emission factors steadily increased from the 1970 value.
No procedure for determining these emission factors is currently available.
3.40.4 Control Efficiency
For the years 1978 through 1984, control efficiencies were applied to the activity to estimate VOC
emissions from gasoline station loading. No procedure for determining these control efficiencies is
currently available.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-196 Category: 09-04
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3.40.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Supply and Disposition of Crude Oil and Petroleum Products."
2. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. June 12, 1980.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-197 Category: 09-04
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3.41 STORAGE AND TRANSPORT - SERVICE STATIONS: STAGE II: 09-05
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(09) STORAGE AND (05) Service Stations: Gasoline Service Stations -
TRANSPORT Stage II loading or stage II
3.41.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source categories
listed above. Emissions were estimated only for VOC from an activity indicator, emission factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in million barrels and emission factors were expressed in metric
pounds/thousand barrels. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984.
3.41.2 Activity Indicator
The activity indicator for gasoline service station unloading or stage II was the production of
finished motor gasoline obtained from Reference la. This quantity was reported under the heading
"Disposition: Products Supplied."
3.41.3 Emission Factor
The emission factor for gasoline service station unloading was based on 1980 emissions data from
Reference 2 and 1979 petroleum production data from Reference 1. This value was used for all years.
More detailed procedure is currently unavailable.
3.41.4 Control Efficiency
For the years 1979 through 1984, control efficiencies were applied to the activity data to estimate
VOC emissions from gasoline service station unloading. No procedure for determining these control
efficiencies is currently available.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-198 Category: 09-05
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3.41.5 References
1. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Supply and Disposition of Crude Oil and Petroleum Products."
2. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. June 12, 1980.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-199 Category: 09-05
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3.42 STORAGE AND TRANSPORT - ORGANIC CHEMICAL STORAGE: 09-07
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(09) STORAGE AND (07) Organic Chemical Storage Waste Solvent Recovery
TRANSPORT Waste Disposal
3.42.1 Technical Approach
The VOC emissions included in this Tier category were the sum of the emissions from the waste
solvent recovery source category multiplied by 0.22 and the emissions from the other source categories
listed above. Emissions were estimated only for VOC from an activity indicator and emission factor. In
order to utilize these values in the Trends spreadsheets, the activity indicators were expressed in thousand
short tons and the emission factors were expressed in metric pounds/short tons.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984.
3.42.2 Activity Indicator
The activity indicator for waste solvent recovery was assumed to be zero.
The activity indicator for waste disposal in petrochemical manufacturing was based on the industrial
organic chemical production index obtained from Reference 1.
3.42.3 Emission Factor
The VOC emission factor for waste solvent recovery was the sum of the emission factors for the five
source listed in Table 3.42-1. Emission factors for these sources were obtained from Reference 2a.
The emission factor for waste disposal in petrochemical manufacturing was obtained from Reference
3.
3.42.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from the source
included in this Tier II category.
3.42.5 References
1. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-200 Category: 09-07
-------
2. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 4.7-1
3. Organic Chemical Manufacturing, Volume 1: Program Report. EPA-450/3-80-023. U.S.
Environmental Protection Agency, Research Triangle Park, NC. December 1980.
Table 3.42-1. VOC Emission Factor SCCs for Waste Solvent Recovery
SCC Description
4-90-002-01 Storage Tank Vent
4-90-002-02 Condenser Vent
4-90-002-03 Incinerator Stack
4-90-002-04 Solvent Spillage
4-90-002-04 Solvent Loading
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-201 Category: 09-07
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3.43 WASTE DISPOSAL AND RECYCLING - INCINERATION: 10-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(10) WASTE DISPOSAL AND (01) Incineration Municipal
RECYCLING Residential
Commercial/Institutional
Conical Woodwaste
3.43.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator, emission factor, and control efficiency, where applicable. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in million short tons and emission factors were
expressed in metric pounds/short ton. All control efficiencies were expressed as dimensionless fractions.
The procedures for determining activity indicators, emission factors, and applicable control
efficiencies were used for the years 1940, 1950, 1960, and 1970 through 1984 for all pollutants except
TSP, for which the procedures were used for the years through 1992, and PM-10, for which the
procedures were used for the years 1975 through 1984. For some source categories, the PM-10
emissions exceeded the TSP emissions as calculated by the procedures presented in this section. Because
this represents a physical impossibility, a more realistic estimate of the PM-10 emissions was assumed to
be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to Equation 3.43-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 343-1)
y TSP Emissions 1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
3.43.2 Activity Indicator
The activity indicator for municipal incineration was the sum of the operating rates for the SCCs 5-
01-001-01 and 5-01-001-02 obtained from Reference 1 or 2.
The activity indicator for residential incineration was the operating rate for residential on-site
incineration obtained from Reference 3.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-202 Category: 10-01
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The activity indicator for commercial/industrial incineration was based on the sum of the operating
rates provided in Reference 1 or 2 for the following SCCs: 5-02-001-01, 5-02-001-02, 5-03-001-01, and
5-03-001-02. The total operating rates for these SCCs were calculated for the year under study and for
the previous year. The activity indicator for the year under study was determined by scaling the activity
indicator for the previous year with the rate of the total operating rates for the year under study and the
previous year. Equation 3.43-2 summarizes this calculation.
, ORi
AL = AL , x | 1 (Eq 3.43.2)
where: i = year
AI = activity indicator
OR = total operating rates
The activity indicator for conical woodwaste incineration was the sum of the operating rates for the
SCCs 5-02-001-05 and 5-03-001-05 obtained from Reference 1 or 2.
3.43.3 Emission Factor
The emission factors for all pollutants except PM-10 and VOC for municipal incineration were
obtained from Reference 4a for the starved air category. The TSP emission factor represented controlled
emissions and, therefore, a separate TSP control efficiency was not used for this category. The PM-10
emission factor was obtained from Reference 5. The source of the VOC emission factor for this source is
currently unavailable.
The emission factors for the residential category were the weighted average of the emission factors
for the two types of domestic single chamber incinerators. These emission factors were obtained from
Reference 4b for all pollutants except PM-10. The PM-10 emission factors for these incinerators were
obtained from Reference 5 or Table 3.1-3 of this report. The weighting factor for the incinerator without
a primary burner was 0.9 and with a primary burner was 0.1.
The emission factor for the commercial/institutional category were the weighted average of the
emission factors for the two combustor types: multiple chamber (SCC 5-02-001-01) and single chamber
(SCC 5-02-001-02). These emission factors for all pollutants except PM-10 were obtained from
Reference 4c. The PM-10 emission factors were obtained from Reference 5. The weighting factor for
the multiple chamber combustor was 0.85 and for the single chamber burner was 0.15.
The emission factors for all pollutants except PM-10 for the conical woodwaste category (SCC 5-
02-001-05) were obtained from Reference 4d. The PM-10 emission factor was obtained from
Reference 5.
3.43.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate CO, NOX, SO2, TSP, or VOC
emissions from solid waste disposal processes.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-203 Category: 10-01
-------
The PM-10 control efficiencies for incineration of municipal and commercial and industrial waste for
the years 1975 through 1984 were based on the 1988 PM-10 control efficiencies obtained from Reference
6. For the years 1940 through 1974, no control efficiencies were used to estimate PM-10 emissions.
3.43.5 References
1. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
2. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
3. Standard Computer Retrievals, NE260 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 2.1-1
b. Volume I, Table 2.1-4
c. Volume I, Table 2.1-3
d. Volume I, Table 2.3-1
5. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listings for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
6. Barnard, William R. and Patricia M. Carlson. "PM-10 Emission Control Efficiency Calculations for
Emissions Trends." Prepared for Arch A. MacQueen, U.S. Environmental Protection Agency,
Research Triangle Park, NC. October 1990.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-204 Category: 10-01
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3.44 WASTE DISPOSAL AND RECYCLING - OPEN BURNING: 10-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(10) WASTE DISPOSAL AND (02) Open Burning Dumps
RECYCLING On-site
3.44.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator and emission factor. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in million short tons and emission factors were expressed in metric
pounds/short ton.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984 for all pollutants except TSP, for which the procedures were
used for the years through 1992, and PM-10, for which the procedures were used for the years 1975
through 1984. For some source categories, the PM-10 emissions exceeded the TSP emissions as
calculated by the procedures presented in this section. Because this represents a physical impossibility, a
more realistic estimate of the PM-10 emissions was assumed to be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to the following equation:
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.44-1)
This calculation was used in place of estimating emissions based on activity indicators and emission
factors.
3.44.2 Activity Indicator
The activity indicator for open burning dumps was the sum of the operating rates for open burning
dumps (SCCs 5-01-002-01 and 5-01-002-02) obtained from Reference 1 or 2.
The activity indicator for on-site open burning was the sum of the operating rate for open burning
(SCCs 5-02-002-01, 5-02-002-02, 5-03-002-01, 5-03-002-02, 5-03-002-03, and 5-03-002-04) obtained
from Reference 3.
'National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-205 Category: 10-02
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3.44.3 Emission Factor
The emission factors for all pollutants except PM-10 for both open burning sources were obtained
from Reference 4a. The PM-10 emission factors were obtained from Reference 5.
3.44.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate emissions from solid waste
disposal processes.
3.44.5 References
1. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
2. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
3. Standard Computer Retrievals, NE260 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Table 2.4-1
5. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-206 Category: 10-02
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3.45 WASTE DISPOSAL AND RECYCLING - OTHER: 10-07
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(10) WASTE DISPOSAL AND (07) Other Waste Disposal of
RECYCLING Petrochemicals
3.45.1 Technical Approach
The VOC emissions included in this Tier category were the emissions from the source category
listed above. Emissions were estimated only for VOC from an activity indicator and emission factor. In
order to utilize these values in the Trends spreadsheets, the activity indicator was expressed in thousand
short tons and the emission factor was expressed in metric pounds/short tons.
The procedures for determining activity indicator and emission factor were used for the years 1940,
1950, 1960, and 1970 through 1984.
3.45.2 Activity Indicator
The activity indicators for the disposal of waste from the manufactur of petrochemicals was based on
the industrial organic chemical production index obtained from Reference 1.
3.45.3 Emission Factor
The VOC emission factor for this source category was obtained from Reference 2.
3.45.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate VOC emissions from solid waste
disposal processes.
3.45.5 References
1. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
2. Organic Chemical Manufacturing, Volume 1: Program Report. EPA-450/3-80-023. U.S.
Environmental Protection Agency, Research Triangle Park, NC. December 1980.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-207 Category: 10-07
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3.46 ON-ROAD VEHICLES: 11
The emissions for all Tier II categories under this Tier I category were determined by the 1940-1984
Methodology for the following source category:
Tier I Category Tier II Category
(11) ON-ROAD VEHICLES (01) Light-duty Gasoline
Vehicles (LDGV) and
Motorcycles (MC)
(02) Light-duty Gasoline
Trucks (LDGT)
(03) Heavy-duty Gasoline
Vehicles (HDGV)
(04) Diesels
3.46.1 Technical Approach
On-road vehicle emissions for the years 1940, 1950, and 1960 were estimated at the national level
for CO, NOX, and VOC (modeled as nonmethane organic gases (NMOG)). The emissions were based on
vehicles miles traveled (VMT) and mobile emission factors. The emissions were calculated for eight
vehicle types [LDGV, MC, LDGT-1, LDGT-2, HDGV, heavy-duty diesel vehicles (HDDV), light-duty
diesel trucks (LDDT), and light-duty diesel vehicles (LDDV)] and three road types (limited access roads,
urban roads, and rural roads). The national annual SO2, TSP, and PM-10 emissions were calculated
using total VMT and emission factors.
3.46.2 Activity Indicator
The activity indicator was national VMT data for each vehicle type and road type as shown in Tables
3.46-1, 3.46-2, and 3.46-3 for 1940, 1950, and 1960, respectively. These data were developed from
VMT data from Reference 1 and redistributed by vehicle type and road type using information from
References 2 and 3.
Difficulty arises in determining the VMT due to the fact that the EPA vehicle classifications do not
correspond directly to the classifications reported in Highway Statistics, Reference 1. As a result, the
reported VMTs will need to be reclassified.
The following procedures were performed except for those instances where the data was not
available then assumptions were made. These assumptions were not documented and therefore cannot be
included in this report.
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Step 1.
Tables VM-1 and VM-2 from the latest version of Highway Statistics, Reference 1 were obtained.
Step 2.
The total national VMTs for each EPA vehicle classification were calculated as follows:
For LDDV: The latest issue of the Market Data Book, Reference 3 was obtained. From this document,
the total number of original sales of diesel passenger cars for the latest model year were extracted. The
estimate of the number of LDDV surviving by calendar year since 1968 was calculated as follows:
LDDV surviving _ [passenger car survival
by model year [ rate by age
[ LDDV original 1
[sales by model year \
(Eq. 3.46-1)
Where the passenger car survival rates were found in Reference 2.
For LDGV: The total VMT for LDDV was subtracted from the total passenger car VMT reported in
VM-1 to get the total number of VMT for LDGV.
For LDGT1, LDGT2, and HDGV: The number of truck sales by weight category was obtained from
Reference 2. For example, in the 1986 edition these values were in the two tables entitled "Retail Sales
of New Trucks by Gross Vehicle Weight and Body Type" and "Total Retail Sales of New Trucks in the
United States." The U.S. factory sales of domestic trucks was obtained from Reference 2. It was
assumed that all imports are in the 0 - 6,000-lb class. Equations 3.42-2 through 3.46-6 summarizes how
the sales of each truck class were calculated.
Sales LDGT1 = RS0to6K + /- DFS0to6K
(Eq. 3.46-2)
Sales LDGT2=RS6tolOK- VCC-M-Q.Q5xCP-DFS6tolOK-DT1()tol4K (Eq. 3.46-3)
SalesHDGT= FCC + M + 0.05 x CP-HDDT+RS.
>10K
(Eq. 3.46-4)
SalesLDDT=DFS0to6k+ Q.
(Eq. 3.46-5)
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SalesHDDT= Q.9>
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Step 4.
The total number of VMT by vehicle class is calculated next. This was done by multiplying the
number of trucks for each year by the corresponding VMT value. The exception to this procedure was
the calculation for HDDT, in which the average of all factory sales data available in each weight class was
used to weight the VMT subtotals. Equation 3.46-9 was used.
HDDT_
"
VMTHDD_2BxQ.9*avg[DFSHDD_2B\ + VMTLHDD* avg[DFSLHDD]
* avg[DFS HHDD\ (Eq. 3.46.9)
0.9*avg[DFSHDD_2B] +avg[DFSLHDD] +avg[DFSMHDD] +avg[DFSHHDD]
where: VMT = vehicle miles traveled
avg (DPS) = "U.S. factory sales of diesel trucks" data available from AAMA, Reference
2, for respective weight class weighted by information on trucks in use by
age, available from AAMA, Reference 2.
The totals were then sum on each vehicle type. The estimates were then normalized to the total
number of VMT reported in VM-1 for all trucks and buses. This was done by multiplying each of the
total VMTs for each truck category by the ratio of the total VMT reported in VM-1 to the total VMT
estimated above.
Step 5.
Next the fraction of the VMT reported for "Other Urban" in Table VM-1 for 55 MPH and
19.6 MPH was calculated using Equations 3.46-10 and 3.46-1 1.
Other Freeways + Other Principal Arterial
' - OtkerUrban -
Minor Arterial + Collector + Local
where: OU = Other Urban VMT obtained from Table VM-1.
All other values obtained from Table VM-2.
Step 6.
The total VMTs by vehicle type were then divided into 3 road speed categories: 55 MPH, 45 MPH,
and 19.6 MPH. For each vehicle type, the VMTs were added together for all road speed categories and
'National Air Pollutant Emission Trends 1940-1984 Methodology
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the fraction of total VMT represented by each speed category was computed using Equations 3.46-12
through 3.46-14.
raction55MPHi = InterstateRuralt + OtherRuralt + InterstateUrbani + OU55MPH x OtherUrba(Eq. 3.46-12)
OtherRural
Fraction,?,,„„. = (Ea 346-13)
45MPH'1 TotalRuralandUrban, l q' '
x Other Urban.
Fractionl96 MPH = r , p , ,TT , L (Eq. 3.46-14)
Total Rural and Urban.
where: i = vehicle type (personal passenger vehicles, 2-axle 4-tire single unit trucks,
combination trucks)
OU55MPH = value calculated in Equation 3.46-10
OU19 6MPH = value calculated in Equation 3.46-11
All other values taken from Table VM-1.
The fractions computed for the VMTs for "Personal Passenger Vehicles" were used to represent the
distribution of VMT for LDGV, LDDV, and MC by road speed categories. The fractions were then
multiplied by the total VMT for those categories to obtain VMT for each road speed category for each
vehicle class. The fraction computed for "2-axle, 4-tire single-unit trucks" was used to distribute total
VMT for LDGT1, LDGT2, and LDDT. The fractions computed for "combinations" were used to
distribute HDDT and HDGT. As a final QA check, the VMT for each road speed category and
MOBILES vehicle class was summed to verify that the total VMT agreed with the total VMT in Table
VM-1.
3.46.3 Emission Factors
The emission factors for CO, NOX, and NMOG, were determined using EPA's MOBILES model as
documented in Reference 4. This model required information on the following parameters: calendar year,
vehicle speeds, temperature, vehicle operating mode, vehicle registration distribution, Reid vapor
pressure (RVP), and altitude. For the years 1940, 1950, and 1960, national annual average conditions
were used as inputs into MOBILES to determine national emission factors for each unique combination
of vehicle type, vehicle speed, and altitude.
The earliest calendar year for which on-road vehicle emission factors can be estimated using
MOBILES is 1960. Therefore, the emission factors for 1940, 1950, and 1960 were all modeled using a
calendar year of evaluation of 1960. The use of 1960 as the calendar year for each of these years gives
reasonable results since no emission standards were in place before 1960.
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Three speeds were modeled in each of the years evaluated. A single speed was selected to represent
each of three road classes — urban, rural, and limited access roads. In 1940 and 1950, the speeds
modeled to correspond with each of these road classes were 19.6 mph for urban roads, 35 mph for rural
roads, and 45 mph for limited access roads. In 1960, the modeled speeds were 19.6 mph for urban roads,
45 mph for rural roads, and 55 mph for limited access roads.
Two sets of temperature data were used in the modeling. For low altitude areas, the average
maximum daily temperature modeled was 65°F and the average minimum daily temperature modeled was
41°F. For high altitude areas, the average maximum daily temperature modeled was 62°F and the average
minimum daily temperature modeled was 38°F. These temperatures were selected to be representative of
national average daily temperature conditions for low and high altitude areas.
In all of the MOBILES modeling, the operating mode assumptions of the Federal Test Procedure
(FTP) were used. In the FTP operating mode, 20.6 percent of all VMT is accumulated in the cold start
mode, 27.3 percent of all VMT is accumulated in the hot start mode, and 52.1 percent of all VMT is
accumulated in the hot stabilized mode.
A national registration distribution was developed for 1970 based on the cars and trucks in operation
by model year obtained from Reference 2 and on truck sales data from References 2 and 3. This
registration distribution was used in determining the emission factors for the years 1940, 1950, and 1960
and is presented in Table 3.46-4.
The gasoline volatility, or Reid vapor pressure (RVP) for the years 1940, 1950, and 1960 was
modeled at 10.1 pounds per square inch (psi). Separate emission factors were calculated for high and
low altitude areas.
Based on these input values for each year, the MOBILES model produced year-specific CO, NOX,
and NMOG emission factors for each combination of vehicle type, road type, and altitude.
The emission factors for PM-10, SO2, and TSP are presented in Table 3.46-5. The procedure for
determining these emission factors is currently unavailable.
3.46.4 Calculation of Emissions
Average national emission factors for CO, NOX, and NMOG by vehicle type and road type were
calculated by weighting the high and low altitude emission factors by the proportion of the VMT
estimated for each of these two altitude groups. It was estimated that 93.5 percent of national VMT was
accumulated in low altitude areas and the remaining 6.5 percent of VMT was accumulated in high
altitude areas. These national average emission factors by vehicle type and road type were then
multiplied by the corresponding national VMT by vehicle type and road type to estimate total national
annual emissions for CO, NOX, and NMOG from on-road vehicles in 1940, 1950, and 1960.
The national annual PM-10, SO2, and TSP emissions were calculated using the total VMT and
emission factors by vehicle type as presented in Tables 3.46-1, 3.46-2, 3.46-3 and 3.46-5.
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3.46.5 References
1. Highway Statistics. Federal Highway Administration, U.S. Department of Transportation,
Washington, DC. Annual.
2. AAMA Motor Vehicle Facts and Figures 19xx. American Automobile Manufacturers Association of
the United States, 1620 Eye Street, N.M., Suite 1000, Washington, DC. Annual.
3. 19xx Market Data Book. Automotive News. 965 E. Jefferson Ave., Detroit, MI. Annual.
4. User's Guide to MOBILES (Mobile Source Emissions Model), Chapter 2. Draft. Office of Mobile
Sources, U.S. Environmental Protection Agency, Ann Arbor, MI. December 1992.
Table 3.46-1. 1940 VMT by Road Type
Vehicle Type
Gasoline
Passenger Cars
Light duty Trucks 1
Light duty Trucks 2
Heavy duty Trucks
Motorcycles
Diesel
Passenger Cars
Light Trucks
Heavy duty Trucks
Total
VMT
Limited
Access
Roads
93.4
9.8
2.5
8.5
0.2
0.0
0.0
0.0
114.4
(billion miles
Urban
Roads
96.6
7.7
1.9
6.1
0.1
0.0
0.0
0.0
112.4
per year)
Rural
Roads
59.1
8.5
2.1
5.4
0.1
0.0
0.0
0.0
75.2
Total
VMT
249.1
26.0
6.5
20.0
0.4
0.0
0.0
0.0
302.0
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Table 3.46-2. 1950 VMT by Road Type
Vehicle Type
Gasoline
Passenger Cars
Light duty Trucks 1
Light duty Trucks 2
Heavy duty Trucks
Motorcycles
Diesel
Passenger Cars
Light Trucks
Heavy duty Trucks
Total
Table
Vehicle Type
Gasoline
Passenger Cars
Light duty Trucks 1
Light duty Trucks 2
Heavy duty Trucks
Motorcycles
Diesel
Passenger Cars
Light Trucks
Heavy duty Trucks
Total
VMT
Limited
Access
Roads
147.0
17.1
4.3
16.8
0.6
0.0
0.0
1.6
187.4
(billion miles
Urban
Roads
127.2
11.9
2.9
9.5
0.6
0.0
0.0
0.6
152.7
3.46-3. 1960 VMT by Road
VMT
Limited
Access
Roads
256.8
24.5
6.1
21.7
1.0
0.0
0.0
7.9
318.0
(billion miles
Urban
Roads
184.5
15.0
3.8
9.0
0.6
0.0
0.0
2.7
215.6
per year)
Rural
Roads
87.8
14.1
3.5
11.6
0.4
0.0
0.0
0.7
118.1
Type
per year)
Rural
Roads
144.8
19.2
4.7
12.7
0.4
0.0
0.0
2.3
184.1
Total
VMT
362.0
43.1
10.7
37.9
1.6
0.0
0.0
2.9
458.2
Total
VMT
586.1
58.7
14.6
43.4
2.0
0.0
0.0
12.9
717.7
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Table 3.46-4. National Vehicle Registration Distribution used in Determining Emission
Factors for the Years 1940, 1950, and 1960
Number of Years
Preceding
Current Year
-1
-2
-3
-4
-5
-6
-7
-8
-9
-10
-11
-12
-13
-14
-15
-16
-17
-18
-19
-20
-21
-22
-23
-24
-25
Vehicle Types
LDGV
0.081
0.111
0.105
0.102
0.099
0.096
0.089
0.082
0.068
0.05
0.036
0.024
0.014
0.01
0.008
0.006
0.006
0.006
0.005
0.001
0.001
0
0
0
0.001
LDGT1
0.085
0.119
0.094
0.093
0.085
0.078
0.073
0.063
0.052
0.04
0.036
0.03
0.025
0.024
0.02
0.02
0.016
0.018
0.013
0.003
0.003
0.002
0.002
0.002
0.005
LDGT2
0.1
0.122
0.109
0.094
0.086
0.072
0.068
0.058
0.048
0.037
0.034
0.028
0.023
0.022
0.018
0.019
0.016
0.017
0.014
0.003
0.002
0.002
0.002
0.001
0.005
HDGV
0.058
0.077
0.071
0.082
0.072
0.073
0.07
0.066
0.061
0.053
0.052
0.042
0.035
0.034
0.027
0.029
0.025
0.028
0.021
0.004
0.003
0.003
0.002
0.002
0.009
LDDV
0.081
0.111
0.105
0.102
0.099
0.096
0.089
0.082
0.068
0.05
0.036
0.024
0.014
0.01
0.008
0.006
0.006
0.006
0.005
0.001
0.001
0
0
0
0.001
LDDT
0.085
0.119
0.094
0.093
0.085
0.078
0.073
0.063
0.052
0.04
0.036
0.03
0.025
0.024
0.02
0.02
0.016
0.018
0.013
0.003
0.003
0.002
0.002
0.002
0.005
HDDV
0.104
0.132
0.11
0.114
0.098
0.085
0.08
0.062
0.048
0.033
0.03
0.025
0.019
0.017
0.014
0.01
0.006
0.004
0.004
0.001
0.001
0.001
0.001
0
0.001
MC
0.133
0.145
0.138
0.116
0.123
0.114
0.069
0.044
0.024
0.009
0.084
0.001
0
0
0
0
0
0
0
0
0
0
0
0
0
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Table 3.46-5. PM-10, TSP, and SO2 On-road Vehicles Emission Factors for
1940, 1950, and 1960
PM-10 TSP SO2
(Ib/thousand VMT) (Ib/thousand VMT) (Ib/thousand VMT)
Vehicle Type
Gasoline
Passenger Cars
Light duty Trucks 1
Light duty Trucks 2
Heavy duty Trucks
Motorcycles
Diesel
Passenger Cars
Light Trucks
Heavy duty Trucks
1940
1.28
1.3
1.37
2.88
0
NA
NA
NA
1950
1.21
1.24
1.27
2.69
0
NA
NA
6.51
1960
1.42
1.46
1.35
3.15
0.77
NA
NA
2.39
1940
1.36
1.38
1.53
2.88
0
NA
NA
NA
1950
1.28
1.32
1.41
2.69
0
NA
NA
6.51
1960
1.5
1.54
1.51
3.15
0.77
NA
NA
2.30
1940
NA
NA
NA
0.1
NA
NA
NA
NA
1950
NA
NA
NA
0.81
NA
NA
NA
NA
1960
NA
NA
NA
0.54
NA
NA
NA
NA
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3.47 NON-ROAD ENGINES AND VEHICLES - NON-ROAD GASOLINE ENGINES: 12-01
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(12) NON-ROAD ENGINES AND (01) Non-road Gasoline Farm Tractors
VEHICLES Engines Other Farm Equipment
Construction
Snowmobiles
Small Utility Engines
Heavy-duty General Utility
Engines
Motorcycles
3.47.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. For all pollutants except PM-10, the emissions
were estimated from an activity indicator and emission factor. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in million gallons and emission factors were
expressed in metric pounds/thousand gallons.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, and 1960 for CO, NOX, SO2, and VOC and for TSP the procedures were used for the years
1940, 1950, 1960, and 1970 through 1992.
The estimation of PM-10 emissions for the years 1940, 1950, and 1960 was based on the relative
change in TSP emissions from the 1975 value according to Equation 3.47-1.
TSP Emissions
PM-10 Emissions = PM-10 Emissions W7^ x — (Eq 347-1)
y TSP Emissions 1975
This calculation was used in place of estimating the emissions based on activity indicators and emission
factors.
The 1975 PM-10 emissions were determined using the 1975 activity indicators as described in
section 3.47.2 and the 1975 PM-10 emission factors. The PM-10 emission factors for all sources except
gasoline-powered heavy duty general utility engines were determined from the corresponding TSP
emission factors and the particle size distributions obtained from Reference la. For snowmobiles and
motorcycles, the size distribution for unleaded gasoline was used. For the other gasoline-powered
engines, the leaded gasoline size distribution was used. The emission factor for gasoline-powered heavy
duty general utility engines was obtained for SCC 2-02-003-01 from Reference 2.
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3.47.2 Activity Indicator
The activity indicator for gasoline-powered farm tractors was based on the 1973 gasoline
consumption by farm tractors.3 The 1973 consumption was adjusted to the year under study using the
ratio of the quantity of gasoline consumed by all agricultural equipment in 1973 to the quantity in the year
under study. These data were obtained from Reference 4a.
f~ * (~*
r~i(-~< _ (~~<(~~< y Agriculture, i
^^Tractor, i ~ ^^Tractor, 1973 ~T<7^ ^ ^' 3-47-2)
Agriculture, 1973
where: i = year under study
GC = gasoline consumption
The activity indicator for other gasoline-powered farm equipment was based on gasoline
consumption. Gasoline consumption by other farm equipment was assumed to be equivalent to
8.52 percent of the quantity of gasoline consumed by farm tractors as determined by the preceding
procedure.
The activity indicator for gasoline-powered construction equipment was the total gasoline
consumption by construction equipment as reported in Reference 4.
The activity indicator for gasoline-powered snowmobiles was based on the 1973 gasoline
consumption by snowmobiles as reported in Reference 3. The 1973 consumption data was adjusted to
the year under study using the ratio of the number of snowmobile registrations in 1973 and in the year
under study as reported in Reference 5. Equation 3.47-3 summarizes this procedure.
D
Snowmobiles, i
Snowmobiles, i ~ Snowmobiles, 1973
v ,
(Eq. 3.47-3)
Snowmobiles, 1973
where: i = year under study
GC = gasoline consumption
R = registration of snowmobiles
The activity indicator for small utility gasoline engines was based on the 1980 gasoline consumption
by small engines (533 x 106 gallons). The 1980 consumption data was adjusted to the year under study
using the ratio of the number of single unit dwellings in 1980 and in the year under study. The number of
single unit dwellings in 1980 was obtained from Reference 6. For the year under study, the number of
single unit dwellings was estimated by adjusting the number of single unit dwellings in 1980 with the
number of new one-family structures started each year between 1980 and the year under study. The
number of new one-family structure started was obtained from Reference 7 for each year. Equation 3.47-
4 summarizes this procedure.
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/ , v Single Unit Dwellings.
GCSmallEngineSt t = (533 x 106 gal) x * (Eq. 3.47-4)
* Smg/e t/ntf Dwellings 19W
where: i = year under study
GC = gasoline consumption
The activity indicator for heavy duty general utility gasoline engines was the total gasoline consumed
by the industrial commercial category obtained from Reference 4.
The activity indicator for motorcycles was the gasoline consumption calculated from the number of
motorcycles, the average annual off-highway mileage traveled, and the median estimated average miles
per gallon. The motorcycle population and the off-highway mileage were obtained from Reference 8.
The average miles per gallon (MPG) was assumed to be 44.0. Equation 3.47-5 summarizes this
calculation.
- Number of Motorcydes x Off-Hig^MHeage
The activity indicator for gasoline-powered vessels was the total quantity of gasoline consumed by
the marine sector (private and commercial) from Reference 4a.
3.47.3 Emission Factor
The emission factors for gasoline-powered farm tractors and other farm equipment were obtained
from Reference Ib for all pollutants except PM-10. The VOC emission factors were multiplied by the
reactive VOC fraction of 0.918, based on data for profile 90-6021D from Reference 9.
The emission factors for all pollutants, except PM-10, for gasoline construction equipment were the
weighted averages of the emission factors for five equipment types. These equipment types and
corresponding weighting factors are listed in Table 3.47-1. Emission factors for each equipment type
were obtained from Reference Ic. The VOC emission factor was multiplied by the reactive VOC fraction
of 0.918. This fraction was based on data for profile 90-602ID from Reference 9.
The emission factors for snowmobiles were obtained from Reference Id for all pollutants except
PM-10. The VOC emission factors were multiplied by the reactive VOC fraction of 0.918, based on data
for profile 90-602ID from Reference 9.
The emission factors for all pollutants, except PM-10, for small gasoline utility engines were the
weighted averages of the emission factors for five equipment types. These equipment types and
corresponding weighting factors are listed in Table 3.47-2. Emission factors for each type were obtained
from Reference le. The VOC emission factor was multiplied by the reactive VOC fraction of 0.918,
based on data for profile 90-6021D from Reference 9.
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The emission factors for heavy duty general utility gasoline engines were obtained from Reference If
for all pollutants except PM-10. The VOC emission factors were multiplied by the reactive VOC fraction
of 0.918, based on data for profile 90-6021D from Reference 9.
The emission factors for all pollutants, except PM-10, for motorcycles were obtained from the
MOBILE 2 (1978 version) model.10 Specific parameters used in the model are provided in Table 3.47-3.
Resulting emission factors, expressed as grams/VMT were converted to lbs/1,000 gal using the factor
20.8.
The CO, NOX, SO2, and VOC emission factors for gasoline-powered vessels were the weighted
averages of the emission factors for inboard and outboard motors. The emission factors were obtained
from Reference Ig and Ih. Two sets of weighting factors were used for each type of motor. The first
weighting factors were the number of registered inboard and outboard motorboats obtained from
Reference 1 1 . The second weighting factors accounted for the greater fuel consumption per hour of
operation for inboards (2.55) than for outboards (1.55). Equation 3.47-6 summarizes the calculation of
the emission factors.
2.55) + (EFout x Rouf x 1.55)]
3 47-6 )
.3.4/o
X2.55) +(^x 1.55)]
where: EF = emission factor
R = number of registrations
in = inboards
out = outboards
The VOC emission factor was multiplied by the reactive VOC fraction of 0.9172. This fraction was
based on data for profile 9-60-21B from Reference 9. The TSP emission factor for gasoline powered
vessels was assumed to be zero.
For the years 1940, 1950, and 1960, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.47.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate emissions from nonroad gasoline
vehicles and engines.
3.47.5 References
1 . Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume II, Table 2-20, Appendix L
b. Volume II, Table II-6-2
d. Volume II, Table II-8-1
e. Volume II, Table II-5-1
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f. Volume I, Table 3.3-1
g. Volume II, Table II-3.5
h. Volume II, Table II-4.1
2. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
3. Exhaust Emissions from Uncontrolled Vehicles and Related Equipment Using Internal Combustion
Engines. U.S. Environmental Protection Agency. Prepared by Southwest Research Institute, San
Antonio, TX, under Contract No. EHS-70-108. October 1973.
4. Highway Statistics. Federal Highway Administration, U.S. Department of Transportation,
Washington, DC. Annual.
a. Table MF-24
5. International Snowmobile Industry Association, 7535 Little River Turnpike, Suite 330, Annandale,
VA 22003. Contact: Roy Muth (703) 273-9606.
6. American Housing Survey, Current Housing Reports, Series H-l50-83. Bureau of the Census, U.S.
Department of Commerce, Washington DC. Biennual.
7. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC. Annual.
8. Motorcycle Industry Council, Inc., 19xx Motorcycle Statistical Annual. Costa Mesa, CA. Annual.
9. Volatile Organic Compound (VOC) Species Data Manual. EPA-450/4-80-015. U.S.
Environmental Protection Agency, Research Triangle Park, NC. July 1980.
10. Mobile Source Emissions Model (MOBILE2) Version 2. Office of Mobile Sources, U.S.
Environmental Protection Agency, Ann Arbor, MI. 1978.
11. Boating Registration Statistics. National Marine Manufacturers Association, 401 N. Michigan
Avenue, Suite 1150, Chicago, IL. Annual.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-222 Category: 12-01
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Table 3.47-1. Emission Factor Equipment Types and
Weighting Factors for Gasoline Construction Equipment
Weighting Factor, based on
Equipment Type consumption in 1,000 gal/year
Wheel Tractor 94,774
Motor Grader 12,240
Wheel Loader 104,726
Roller 147,439
Table 3.47-2. Emission Factor Equipment Types and
Weighting Factors for Gasoline Small Utility Gasoline
Engines
Weighting Factor, based on
Engine Type percentage consumption
Wheel Tractor (2-stroke) 0.065
Motor Grader (4-stroke) 0.935
Table 3.47-3. MOBILE 2 (1978 version) Parameters for Calculation of
Emission Factors for Motorcycles
Altitude Low
Speed 19.6MPH
Ambient Temp. 57°F
Hot Start/Cold Start Percentages Zero
All other variables default values
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-223 Category: 12-01
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3.48 NON-ROAD ENGINES AND VEHICLES - NON-ROAD DIESEL ENGINES: 12-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category. The emissions for this Tier II category were determined by the 1940-1984
Methodology for the following source categories.
Tier I Category Tier II Category Tier II Subcategory
(12) NON-ROAD ENGINES AND (02) Non-road Diesel Engines Farm Tractors
VEHICLES Other Farm Equipment
Heavy-duty General Utility
Engines
3.48.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. For all pollutants except PM-10, the emissions
were estimated from an activity indicator and emission factor. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in million gallons and emission factors were
expressed in metric pounds/thousand gallons.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, and 1960 for CO, NOX, SO2, and VOC. For TSP, the procedures were used for the years
1940, 1950, 1960, and 1970 through 1992.
The estimation of PM-10 emissions for the years 1940, 1950, and 1960 was based on the relative
change in TSP emissions from the 1975 value according to Equation 3.48-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.48-1)
This calculation was used in place of estimating emissions based on activity indicators and emission
factors.
The 1975 PM-10 emissions were determined using the 1975 activity indicators as described in
section 3.48.2 and the 1975 PM-10 emission factors. The PM-10 emission factors for all sources, except
diesel-powered heavy duty general utility engines were determined from the corresponding TSP emission
factor and the particle size distribution obtained from Reference la. The emission factor for diesel-
powered heavy duty general utility engines was obtained from Reference 2 for SCC 2-02-001-02.
3.48.2 Activity Indicator
The activity indicators for diesel farm tractors and other diesel farm equipment were based on the
adjusted total sales (or deliveries) of diesel fuel used on farms obtained from Reference 3 a or 4a. It was
'National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-224 Category: 12-02
-------
assumed that 95.5 percent of this quantity was consumed by farm tractors and 4.5 percent was consumed
by other farm equipment.
The activity indicator for diesel construction equipment was the adjusted total sales (or deliveries) of
off-highway diesel distillate fuel oil for use in construction from Reference 3b or 4b.
The activity indicator for heavy-duty general utility diesel engines was the sum of the adjusted total
sales (or deliveries) of off-highway diesel distillate fuel oil for other uses and of diesel for military uses.
These data was obtained from Reference 3b or 4b.
3.48.3 Emission Factor
The emission factors for all pollutants except PM-10 for farm diesel tractors and other farm diesel
equipment were obtained from Reference Ib. The VOC emission factors were multiplied by the reactive
VOC fraction of 0.952, based on data for profile 90-7021 from Reference 5.
For diesel construction equipment, the emission factors for all pollutants except PM-10 were the
weighted averages of the emission factors for nine equipment types. These equipment types and the
corresponding weighting factors are listed in Table 3.48-1. Emission factors for each equipment type
were obtained from Reference Ic. The VOC emission factor was multiplied by the reactive VOC fraction
of 0.952, based on data for profile 90-7021 from Reference 5.
The emission factors for heavy duty general utility diesel engines were obtained from Reference Id
for all pollutants except PM-10. The VOC emission factors were multiplied by the reactive VOC fraction
of 0.952, based on data for profile 90-7021 from Reference 5.
For the years 1940, 1950, and 1960, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.48.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate emissions from nonroad diesel
vehicles and engines
3.48.5 References
1. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume II, Table 2-2, Appendix L,
b. Volume II, Table II-6-2
c. Volume II, Table II-7-1
d. Volume II, Table 3.3-1
2. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-225 Category: 12-02
-------
3. Petroleum Marketing Monthly. DOE/EIA-0380(xx/01). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Deliveries for Farm Use: Distillate Fuel Oil and Kerosene"
b. Table entitled, "Deliveries for Military Use: Distillate Fuel Oil and Residual Fuel Oil; Deliveries
for Off-Highway Use: Diesel"
4. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Adjusted Sales for Farm Use: Distillate Fuel Oil and Kerosene."
b. Table entitled, "Adjusted Sales for Military Use: distillate Fuel Oil and Residual Fuel Oil;
Adjusted Sales for Off-Highway Use: Diesel."
5. Volatile Organic Compound (VOC) Species Data Manual. EPA-450/4-80-015. U.S.
Environmental Protection Agency, Research Triangle Park, NC. July 1980.
Table 3.48-1. Emission Factor Equipment Types and
Weighting Factors for Diesel Construction Equipment
Weighting Factor, based on
Equipment Type consumption in 1,000 gal/year
Tracklaying Tractor 912,279
Wheel Tractor 846,035
Wheeled Dozer 47,077
Scraper 621,523
Motor Grader 164,368
Wheeled Loader 753,511
Tracklaying Loader 229,680
Off-Highway Truck 470,550
Roller 30,180
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-226 Category: 12-02
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3.49 NON-ROAD ENGINES AND VEHICLES - AIRCRAFT: 12-03
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(12) NON-ROAD ENGINES AND (03) Aircraft FAA Facilities
VEHICLES Military Facilities
General Aviation
3.49.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. For all pollutants except PM-10, the emissions
were estimated from an activity indicator and emission factor. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in thousand LTO cycles and emission factors
were expressed in metric pounds/LTO cycle.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, and 1960 for CO, NOX, SO2, and VOC and for TSP the procedures were used for the years
1940, 1950, 1960, and 1970 through 1992.
The estimation of PM-10 emissions for the years 1940, 1950, and 1960 was based on the relative
change in TSP emissions from the 1975 value according to Equation 3.49-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.49-1)
This calculation was used in place of estimating PM-10 emissions based on activity indicators and
emission factors.
The 1975 PM-10 emissions were determined using the 1975 activity indicators as described in
section 3.49.2 and the 1975 PM-10 emission factor obtained from Table 3.1-3 of this report.
3.49.2 Activity Indicator
The activity indicators for commercial, air taxi, general aviation, and military aircraft using Federal
Aviation Administration (FAA) facilities were the landings and take-offs (LTOs). The total airport
operations reported in Reference 1 for each aircraft category were divided by 2 in order to obtain the
number of LTO cycles.
The activity indicator for general aviation aircraft using military facilities was assumed to be a
constant 1200 LTOs.
'National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-227 Category: 12-03
-------
The activity indicator for military aircraft using military facilities was based on the military LTOs at
military facilities from the year preceding the year under study. Total military LTOs from the year
preceding were calculated as the sum of military LTOs from military facilities and from FAA facilities.
Total LTOs were projected to the year of study by using the ratio between total flying hours for active
U.S. military aircraft flying in the continental United States for the year under study and for the preceding
year. Total flying hours data were obtained from Reference 2. From the resulting total military LTOs for
the year under study, military LTOs from FAA facilities were subtracted in order to determine military
LTOs from military facilities for the year under study. The procedure for determining the miliary LTOs
from FAA facilities was described previously. This overall calculation of the activity indicator is
summarized in Equation 3.49-2.
FH, .
~ MLT°FAA, i (Eq. 3.49-2)
MLTOw, i
where: MLTO = military LTO
MF = military facilities
FAA = FAA facilities
FH = total flying hours
i = year under study
The activity indicator for general aviation aircraft using other facilities was based on the assumption
that civil aircraft average 250 LTO cycles per year. Total general aviation LTOs were estimated by
multiplying the number of registered civil aircraft, excluding gliders, blimps, and balloons, by the average
LTO cycles per year. The number of registered civil aircraft was obtained from Reference 3. From this
total was subtracted the general aviation LTOs at FAA facilities and at military facilities. These values
were determine using procedures described previously. This calculation is summarized in Equation 3.49-
3.
GAOF = (AC x 250 cycles/year) - GAFAA - GAMF (Eq. 3.49-3)
where: GA = General Aviation LTOs
AC = Number of U.S. registered civil aircraft, excluding gliders, blimps, and balloons
OF = Other Facilities
FAA = FAA Facilities
MF = Military Facilities
3.49.3 Emission Factor
The emission factors for all pollutants except PM-10 for commercial aircraft using FAA facilities
were the weighted averages of the emission factors for each commercial aircraft type. These emission
factors are presented in Table 3.49-1. The weighting factors were the estimated LTO's for each aircraft
type.
'National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-228 Category: 12-03
-------
In order to estimate the LTO's for each aircraft type, the estimated number of LTOs by aircraft type
from the year preceding the year under study were projected to the year under study. This projection was
accomplished for each aircraft type using the ratio of the number of aircraft in operation in the year under
study to the number in the the preceding year. These values were obtained from Reference 3. The
estimated number of LTO's by aircraft type for the preceding year were obtained by using this same
methodology on data from the preceding year.
The estimated LTOs by aircraft type for the year under study were normalized to the actual total
number of LTO's as reported in Reference 1. These normalized LTOs for each aircraft type were the
weighting factor used to calculate the weight average emission factors for commercial aircraft using FAA
facilities.
The emission factors for all pollutants except PM-10 for air taxis using FAA facilities were the
weighted averages of the emission factors for each air taxi aircraft type.4 These emission factors are
presented in Table 3.49-2. Weighting factors were the estimated number of each air taxi aircraft type as
reported in Reference 3.
The emission factors for all pollutants except PM-10 for general aviation aircraft using FAA facilities
were the weighted averages of the emission factors for each aviation aircraft type.4 These emission
factors are presented in Table 3.49-3. Weighting factors were the estimated number of flying hours for
each aircraft type obtained from Reference 2a. It was assumed that the number of flying hours was
proportional to the number of LTO cycles.
The emission factors for all pollutants except PM-10 for military aircraft using FAA facilities were
the weighted averages of the emission factors for each military aircraft type.4 These emission factors are
presented in Table 3.48-4. Weighting factors were the estimated number of flying hours for each military
aircraft type obtained from Reference 2b. It was assumed that the number of flying hours was
proportional to the number of LTO cycles.
The emission factors for all pollutants except PM-10 for military aircraft using military facilities were
the same factors as were used for military aircraft using FAA facilities.4 The emission factors for all
pollutants except PM-10 for general aviation aircraft using military facilities were the same factors as
were used for general aviation aircraft using FAA facilities.
The emission factors for all pollutants except PM-10 for general aviation aircraft using other
facilities were the same factors as were used for general aviation aircraft using FAA facilities.4
For the years 1940, 1950, and 1960, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.49.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate emissions from aircraft.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-229 Category: 12-03
-------
3.49.5 References
1. FAA Air Traffic Activity FY 19xx. Federal Aviation Administration, U.S. Department of
Transportation, Washington, DC. Annual.
a. Table 4, "Airport Operations at Airports with FAA-Operated Traffic Control Towers by Region
and by State and Aviation Category."
2. FAA Aviation Forecasts Fiscal Years 19xx-19xx. Federal Aviation Administration, U.S.
Department of Transportation, Washington, DC. Annual.
a. Table 9
b. Table 23
3. Census of U.S. Civil Aircraft, Calendar Year 19xx. Federal Aviation Administration, U.S.
Department of Transportation, Washington, DC. Annual.
a. Table 1.1. For Regional, use number of registered aircraft, Table 3.2.
4. Compilation of Air Pollutant Emission Factors (AP-42), Volume II Mobile Sources, 4th Edition,
Motor Vehicle Emission Laboratory, U.S. Environmental Protection Agency, Ann Arbor, MI.
September 1985.
Table 3.49-1. Emission Factors for Commercial Aircraft using FAA Facilities
Commercial Aircraft
BAG 1 1 1
Boeing 707
Boeing 727
Boeing 737
Boeing 747
L1011
DCS
DC9
DC10
General
CO
103.63
262.64
55.95
37.3
145.1
124.7
262.64
37.3
116.88
Emission
NO,
15.04
25.68
29.64
19.76
10.52
78.98
25.68
19.76
49.59
Factors (Ibs/LTO)
VOC*
71.19
214.53
13.21
8.81
42.37
71.71
214.53
8.81
46.3
SO,
1.7
4.28
3.27
2.18
7.55
5.3
3.27
2.18
4.98
TSP
1.46
4.52
1.17
0.78
5.2
3.9
1.17
0.78
0.21
1.0
' Reactive VOC (already adjusted).
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-230
1940-1984 Methodology
Category: 12-03
-------
Table 3.49-2. Emission Factors for Air Taxis using FAA Facilities
Emission Factor (Ibs/LTO)
Air Taxi Aircraft
Turbojets
Turboprops
Pistons
General
CO
50.26
7.16
100**
NO,
26.63
0.82
0.6**
voc*
11.87
4.99
3.2**
SO,
2.94
0.18
0.02**
TSP
1.05
0.46
0.3**
* VOC adjustment factor is 0.983 for turbojets and 0.929 for pistons.
"Assumed values used for pistons.
Table 3.49-3. Emission Factors for General Aviation Aircraft using FAA Facilities
Emission Factor (Ibs/LTO)
General Aviation Aircraft
Piston:
Single Engine
Multi-Engine
Turboprop
Turbojet
Rotocraft Piston
Rotocraft Turbine
General
CO
11.35
64.67
6.76
54.36
11.35
13.33
NO,
0.02
0.075
0.92
2.02
0.02
4.34
VOC*
0.23
1.35
6.46
6.62
0.23
2.75
SO,
0
0
0.17
0.74
0
0.26
TSP
0.02
0.02
0.46
0.5**
0.02
0.4
* Reactive VOC (already adjusted),
**Particulate emission factor for Turbojet is best guess estimate.
Table 3.49-4. Emission Factors for Military Aircraft using FAA Facilities
Emission Factor (Ibs/LTO)
Military Aircraft
Jet (fixed wing)
Turboprop
Piston
Helicopter
General
CO
52.4
23.2
53.2
13.33
NO,
9.65
14.1
0.29
4.34
VOC*
29
11.6
5.5
2.75
SO,
1.56
0.74
0.033
0.26
TSP
28
0.46
0.28
0.4
*Reactive VOC (already adjusted).
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-231
1940-1984 Methodology
Category: 12-03
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3.50 NON-ROAD ENGINES AND VEHICLES - MARINE VESSELS: 12-04
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(12) NON-ROAD ENGINES AND (04) Marine Vessels Residual Fuel Oil
VEHICLES Diesel Oil
Coal
3.50.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. For all pollutants except PM-10, the emissions
were estimated from an activity indicator and emission factor. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in million gallons and emission factors were
expressed in metric pounds/thousand gallons.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, and 1960 for CO, NOX, SO2, and VOC and for TSP the procedures were used for the years
1940, 1950, 1960, and 1970 through 1992.
The estimation of PM-10 emissions for the years 1940, 1950, and 1960 was based on the relative
change in TSP emissions from the 1975 value according to Equation 3.50-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x y— (Eq. 3.50-1)
This calculation was used in place of estimating PM-10 emissions based on activity indicators and
emission factors.
The 1975 PM-10 emissions were determined using the 1975 activity indicators as described in
section 3.50.2 and the 1975 PM-10 emission factors obtained from Table 3.1-3 of this report.
3.50.2 Activity Indicator
The activity indicator for residual fuel oil was the "adjusted" quantity of residual fuel oil delivered
for transportation use, vessel bunkering obtained from Reference la or Reference 2a.
The activity indicator for diesel oil was the "adjusted" quantity of distillate fuel oil (for diesel)
delivered for transportation use, vessel bunkering obtained from Reference la or Reference 2a.
The procedure for determining the activity for the years 1940, 1950, and 1960 is currently
unavailable. The activity indicator for coal was assumed to be zero after 1979.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-232 Category: 12-04
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3.50.3 Emission Factor
The emission factors for all pollutants except PM-10 for residual fuel oil were based on the emission
factors for residual oil-fired commercial steamships obtained from Reference 3a. The emission factors
were presented separately for three modes of operation; hotelling, cruise, and full power. Weighted
averages of these emission factors were calculated for each pollutant based on the relative amount of time
vessels spend operating under these different modes. It was assumed that 80 percent of the time was
spent hotelling and 20 percent was spent under full power.
The VOC emission factor was converted to the reactive VOC emission factor by using the factor for
profile 101004 obtained from Reference 4.
The emission factors for all pollutants except PM-10 for diesel oil were weighted averages of the
emission factors for diesel-fired vessels operating underway and operating under auxiliary power.
Weighting factors were based on the relative amount of time the ships spent operating in these modes:
20 percent under auxiliary power and 80 percent underway. The final VOC emission factor was
converted to the reactive VOC emission factor by using the factor for profile 907021 obtained from
Reference 4.
The emission factors for diesel-fired vessels under auxiliary power were the averages of the emission
factors for diesel-fired vessels operating under auxiliary power at 50 percent load. The emission factors
for all pollutants except for TSP were obtained from Reference 3b and were averaged over the four
output ratings. The average TSP emission factor was obtained from Reference 3c.
The emission factors for diesel-fired vessels underway were the weighted averages of the emission
factors for commercial motorships and distillate oil-fired commercial steamships. The emission factors
were weighted by the relative population of motorships and steamships. It was assumed that of the
overall fleet of diesel-fired vessels, 75 percent were motorships and 25 percent were steamships.
The emission factors for commercial motorships were the averages of the emission factors for the
river, Great Lakes, and coastal waterway classifications. The emission factors for all pollutants except
for TSP were obtained from Reference 3d and were averaged over the three waterway classifications.
The average TSP emission factor was assumed to be equal to the emission factor railroad locomotive
obtained from Reference 3e.
The emission factors for commercial distillate oil-fired steamships were the weighted averages of the
emission factors for two modes of operations: hotelling and full power. These emission factors were
obtained from Reference 3 a. The emission factors were weighted by the relative time the steamship spent
operating under these two modes. It was assumed that steamship spent 80 of the time hotelling and 20
percent at full power.
The emission factors for all pollutants for coal combustion by marine vessels after 1979 were
assumed to have a value of zero. The procedure for determining the activity for the years 1940, 1950,
and 1960 is currently unavailable.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-233 Category: 12-04
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For the years 1940, 1950, and 1960, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.50.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate emissions from marine vessels.
3.50.5 References
1. Petroleum Marketing Monthly. DOE/EIA-0380(xx/01). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. TableA13andA14
2. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. TableA13andA14
3. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume II, Table II-3-2
b. Volume II, Table II-3-4
c. Volume II, Table 3.3-1
d. Volume II, Table II-3-1
e. Volume II, Table II-2-1
4. Volatile Organic Compound (VOC) Species Data Manual. EPA-450/4-80-015. U.S.
Environmental Protection Agency, Research Triangle Park, NC. July 1980.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-234 Category: 12-04
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3.51 NON-ROAD ENGINES AND VEHICLES - RAILROADS: 12-05
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier II Category Tier II Subcategory
(12) NON-ROAD ENGINES AND (05) Railroads Diesel
VEHICLES Residual Fuel Oil
Coal
3.51.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. For all pollutants except PM-10, the emissions
were estimated from an activity indicator and emission factor. In order to utilize these values in the
Trends spreadsheets, activity indicators were expressed in million gallons and emission factors were
expressed in metric pounds/thousand gallons.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, and 1960 for CO, NOX, SO2, and VOC and for TSP the procedures were used for the years
1940, 1950, 1960, and 1970 through 1992.
The estimation of PM-10 emissions for the years 1940, 1950, and 1960 was based on the relative
change in TSP emissions from the 1975 value according to Equation 3.51-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.51-1)
This calculation was used in place of estimating emissions based on activity indicators and emission
factors.
The 1975 PM-10 emissions were determined using the 1975 activity indicators as described in
section 3.51.2 and the 1975 PM-10 emission factors obtained from Table 3.1-3 of this report.
3.51.2 Activity Indicator
The activity indicator for the combustion of diesel fuel by locomotives was the "adjusted" quantity
of distillate fuel oil deliveries for transportation use (railroads) obtained from Reference 1 or Reference 2.
The activity indicator for the combustion of residual fuel oil by locomotives was based on the
"adjusted" quantity of residual fuel oil sales to the "All Other" end use category from Reference 1 or
Reference 2. It was assumed that the ratio of fuel consumption by railroads to the fuel consumption
included in the "All Other" end use category (which includes railroads) is 8.83 x 10"4. Therefore, the
activity indicator was the value obtained from Reference 1 or Reference 2 multiplied by 8.83 x 10"4.
'National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-235 Category: 12-05
-------
The activity indicator for the combustion of coal was the quantity of U.S. coal distribution by
"transportation" obtained from Reference 3a. It was assumed that "transportation" as defined in
Reference 3 represented the locomotive category.
3.51.3 Emission Factor
The emission factors for diesel fuel combustion by locomotives were obtained from Reference 4a for
all pollutants except PM-10. The VOC emission factor was multiplied by 0.952 to account for the
reactive portion.
For the combustion of residual fuel oil, the emission factors for all pollutants except PM-10 and
VOC were obtained from Reference 4a. The VOC emission factor was obtained from Reference 4b and
was multiplied of 0.952 to account for the reactive portion. The SO2 factor was multiplied by the sulfur
content value of 1.34.
The emission factors for all pollutants except PM-10 for the combustion of coal were obtained from
Reference 4c. In this reference, the TSP factor was listed as the spreader stoker emission factor. The
SO2 emission factor was multiplied by a sulfur content value of 2.0.
For the years 1940, 1950, and 1960, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.51.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate emissions from railroads.
3.51.5 References
1. Petroleum Marketing Monthly. DOE/EIA-0380(xx/01). Energy Information Administration, U.S.
Department of Energy, Washington, DC. January issue.
2. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
3. Coal Distribution January-December 19xx. DOE/EIA-0125(xx/4Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
a. Table entitled, "Distribution of U.S. Coal by Origin, Destination, and Consumer"
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume II, Table II-2-1
b. Volume I, Table 1.3-1 (Industrial Residual Oil Boilers)
c. Volume I, Table 1.1-1 (Bituminous Coal Hand-fired Units)
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-236 Category: 12-05
-------
3.52 MISCELLANEOUS - OTHER COMBUSTION: 14-02
The emissions for this Tier II category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category Tier II Category Tier II Subcategory
(14) MISCELLANEOUS (02) Other Combustion Wildfires
Prescribed Burning
Agricultural Burning
Structural Fires
Coal Refuse Burning
3.52.1 Technical Approach
The CO, NOX, PM-10, TSP, SO2, and VOC emissions included in this Tier category were the sum of
the emissions from the source categories listed above. Emissions were estimated from an activity
indicator and emission factor. In order to utilize these values in the Trends spreadsheets, activity
indicators for wildfires and prescribed burning were expressed in acres and emission factors were
expressed in metric pounds/thousand short tons. For the other sources, activity indicators were
expressed in thousand short tons and emission factors were expressed in metric pounds/short ton.
The procedures for determining activity indicators and emission factors were used for the years
1940, 1950, 1960, and 1970 through 1984 for all pollutants except TSP, for which the procedures were
used for the years through 1992, and PM-10, for which the procedures were used for the years 1975
through 1984. For some source categories, the PM-10 emissions exceeded the TSP emissions as
calculated by the procedures presented in this section. Because this represents a physical impossibility, a
more realistic estimate of the PM-10 emissions was assumed to be the TSP emissions value.
The estimation of PM-10 emissions for the years prior to 1975 was based on the relative change in
TSP emissions from the 1975 value according to the Equation 3.52-1.
TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x :—: y-^- (Eq. 3.52-1)
This calculation was used in place of estimating the emissions based on activity indicators and emission
factors.
3.52.2 Activity Indicator
The activity indicator for wildfires is the sum of protected and unprotected land areas burned for
each of the five regions. These regions are defined in Table 3.52-1. The area of protected land burned
was obtained from Reference 1. Default values used for the unprotected land area burned are given in
Table 3.52-2.
'National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-237 Category: 14-02
-------
For the years 1978 through 1984, the activity indicator for prescribed burning was the acreage
burned in 1978 reported in Reference 2. The data are reported for two regions: Southern and Western.
It was assumed that the acreage burned remained constant for the years 1978 through 1984. No
procedure for determining the acreage burned for the years prior to 1978 is currently available.
The activity indicator for agricultural burning was based on the total quantity of agricultural
products burned in 1974 as reported in Reference 3. Because no data were available after 1974, the
activity indicators for this category for the years after 1974 were assumed to be the same as that for
1974.
The activity indicator for structural fires was based on the total number of building fires as reported
in Reference 4. It was assumed that 6.8 tons of material is burned for every building fire. Alternatively,
an estimate of the quantity of material burned was obtained from Reference 5.
The activity indicator for coal refuse burning was based on the estimated total quantity of coal refuse
in 1971 from Reference 6. It was assumed that this quantity had been steadily declining over the period
after the report was published. A rough approximation was deemed sufficient.
3.52.3 Emission Factor
The emission factors for wildfires were composed of two factors: fuel loading and pollutant yield.
The fuel loading related the area of land burned to the quantity of vegetation consumed by fire. The fuel
loading data were specific to five regions of the United States. The States included in each region are
listed in Table 3.52-1. The pollutant yield related the amount of a given pollutant emitted to the amount
of vegetation consumed by fire. The information on these two factors was obtained from Reference 7a
except the pollutant yield for PM-10 which was obtained from Table 3.1-2 of this report.
The emission factors for prescribed fires were composed of two factors: fuel loading and pollutant
yield. These factors were defined in the same manner as for the wild fire category. The fuel loading was
specific to two regions of the United States. The information on these two factor was obtained from
Reference 6, except for the SO2, NOX, and PM-10 pollutant yield values. The SO2 and NOX pollutant
yields were assumed to be the same as the pollutant yields for wildfires and, therefore, were obtained
from Reference 7a. The PM-10 pollutant yield was obtained from Table 3.1-3 of this report.
The emission factors for all pollutants except PM-10 for agricultural burning were the average of the
emission factors for burning sugar cane and field crops. These emission factors were obtained from
Reference 7b, except for the NOX emission factors which were obtained from Reference 7c. The PM-10
emission factor was obtained from Table 3.1-3 of this report.
The emission factors for all pollutants except PM-10 for structural burning were obtained from
Reference 8. These emission factors were for open burning and were adjusted using engineering
judgment. The PM-10 emission factor was obtained from Table 3.1-3 of this report.
The emission factors for all pollutants except PM-10 for coal refuse burning were obtained from
Reference 9. These emission factors were for open burning and were adjusted using engineering
judgment. The PM-10 emission factor was obtained from Table 3.1-3 of this report.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-238 Category: 14-02
-------
For the years prior to 1975, emission factors were not employed in the estimation of PM-10
emissions from the sources included in this Tier II category.
3.52.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate emissions from the sources
included in this Tier II category.
3.52.5 References
1. The National Forest Fire Report. Forest Service, U.S. Department of Agriculture. Annual.
2. Source Assessment Prescribed Burning. EPA-600/2-79-019H, U.S. Environmental Protection
Agency, Research Triangle Park, NC. 1979.
3. Emissions Inventory from Forest Wildfires, Forest Managed Burns, and Agricultural Burns.
EPA-450/3-74-062. U.S. Environmental Protection Agency, Research Triangle Park, NC.
November 1974.
4. Statistical Abstract of the United States. Bureau of the Census, U.S. Department of Commerce,
Washington, DC. Annual.
5. National Fire Protection Association, Boston, MA.
6. Information Circular 8515. U.S. Bureau of Mines, U.S. Department of the Interior, Washington,
DC. 1971.
7. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Volume I, Section 11.1
b. Volume I, Table 2.4-5
8. Compilation of Air Pollutant Emission Factors, AP-42. U.S. Environmental Protection Agency,
Research Triangle Park, NC. February 1972.
9. OAQPS Data File on National Emissions. National Air Data Branch, U.S. Environmental
Protection Agency, Research Triangle Park, NC. 1984.
National Air Pollutant Emission Trends 1940-1984 Methodology
Procedures Document for 1900-1996 3-239 Category: 14-02
-------
Table 3.52-1. States Comprising Regions for Wild Fires Acreage Burned Information
Rocky Mountain
Arizona
Colorado
Idaho
Kansas
Montana
Nebraska
Nevada
New Mexico
North Dakota
South Dakota
Utah
Wyoming
Pacific
Alaska
California
Guam
Hawaii
Oregon
Washington
East
Connecticut
Delaware
Maine
Maryland
Massachusetts
New Hampshire
New Jersey
New York
Pennsylvania
Rhode Island
Vermont
West Virginia
North Central
Illinois
Indiana
Iowa
Michigan
Minnesota
Missouri
Ohio
Wisconsin
South
Alabama
Arkansas
Florida
Georgia
Kentucky
Louisiana
Mississippi
North Carolina
Oklahoma
South Carolina
Tennessee
Texas
Virginia
Table 3.52-2. Land Area Burned on Unprotected Lands
Region
Acreage
(thousands of
acres)
Rocky Mountain
Pacific
East
North Central
South
198.1
184.8
65.1
296.0
1,584.1
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-240
1940-1984 Methodology
Category: 14-02
-------
SECTION 4.0
NATIONAL CRITERIA POLLUTANT ESTIMATES
1985 -1996 METHODOLOGY
Each year the U.S. Environmental Protection Agency (EPA) prepares national estimates for
assessing trends in criteria pollutant emissions. In the past, the emissions were estimated using consistent
top-down methodologies employing national statistics on economic activity, material flows, etc., for the
years 1940 to the current year of the report. Although emissions prepared in this way were useful for
evaluating changes from year to year, they did not provide a geographically detailed measure of emissions
for any given year. Bottom-up inventories, where emissions are derived at the plant or county level, are
extremely useful in many applications, such as inputs into atmospheric models. During the past several
years, changes have been made to the methodologies in order to produce emissions for the National Air
Pollutant Emission Trends, 1900-19961 (Emission Trends) report, starting at the county level, which
both represent a bottom-up inventory and allow for an evaluation of changes in emissions from year to
year. These methodological changes allowed for the incorporation of even more detailed state data.
Starting with this year's Emission Trends report,1 state data including emission estimates have been
incorporated.
4.1 INTRODUCTION
The carbon monoxide (CO), nitrogen oxides (NOX), sulfur dioxide (SO2), and volatile organic
compound (VOC) emissions presented in this report for the years 1985 through 1989 have been
estimated according to the methodology for developing the Interim Inventories, with several exceptions.
The Interim methodology was developed to produce the inventories for the years 1987 through 1991 and
is presented in the Regional Interim Emission Inventories (1987-1991).2 A similar methodology was
developed for the preparation of a national 1990 particulate matter inventory as documented in the
Development of the OPPE Paniculate Programs Implementation Evaluation System? In order to
generate the necessary emissions for the Emission Trends report, the Interim methodology has been
expanded to generate CO, NOX, SO2, and VOC emissions for the years 1985 and 1986, as well as
particulate matter less than 10 microns (PM-10) emissions for the years 1985 through 1989.
The 1990 Interim Inventory has been revised with state emissions when available. The state non-
utility point emissions were obtained from the Ozone Transport Assessment Group (OTAG), Grand
Canyon Visibility Transport Commission (GCVTC), and Aerometric Information Retrieval
System/Facility Subsystem (AIRS/FS). Area source emissions were also obtained from OTAG,
California, and Oregon. On-road emissions were calculated by EPA from state-provided emission factor
inputs and vehicle miles traveled (VMT). All gaps in emissions were filled with 1990 Interim Inventory
emissions. The 1990 state emissions (hereafter referred to as the 1990 National Emission Trends [NET]
inventory) is the basis for the 1991 through 1996 emissions.
Two pollutants, particulate matter less than 2.5 microns (PM-2.5) and ammonia (NH3), have been
added to the list of pollutants inventoried by EPA's Emission Factors and Inventory Group (EFIG).
Emissions and associated data for these two pollutants are available for the years 1990 through 1996.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-1 Introduction
-------
A detailed description of the methodologies used to generate the CO, NOX, VOC, SO2, and PM-10
emissions for the years 1985 through 1996 and PM-2.5 and NH3 emissions for the years 1990 through
1996 are presented in this section. The description is divided into subsections based on similar
approaches in estimating the emissions. The beginning of each subsection lists the Tier I category, and
below, if necessary. Table 4.1-1 shows the subsection/tier category relationships. If a Tier II category is
not listed, it is currently not estimated within the NET Inventory.
4.1.1 Lead Emissions
The lead (Pb) emissions for the years 1985 through 1995 have been estimated using the
methodologies presented in section 5.0 of this report. The weighted emission factors and control
efficiencies were assumed to be constant from 1990 to 1996. The 1996 preliminary estimates were
projected by one of two methods applied to the appropriate source category. The first of these two
methods used a quadratic regression with weighted 20-year specific source category activity data. The
second method used a linear regression with weighted 7-year activity data. This second method was
applied to source categories where the trend in the activity data has changed significantly over the past 10
years.
4.1.2 Carbon Monoxide, Nitrogen Oxides, Volatile Organic Compounds, Sulfur Dioxide,
Particulate Matter (PM-10 and PM-2.5), and Ammonia Emissions
Emissions were developed at the county and Source Classification Code (SCC) level for most source
categories. These emissions are then summed to the Tier level. There are four levels in the Tier
categorization. The first and second level, referred to as Tier I and Tier II, respectively, are the same for
each of the six criteria pollutants and are listed in Table 4.1-2. The third level, Tier III, is unique for each
of the six pollutants. The fourth level, Tier 4, is the SCC level. Table 4.1-3 lists the Tier I and Tier II
codes and names with the associated SCC and SCC description. Due to space limitations, the SCC
descriptions have been truncated.
Although the emissions were derived at the SCC level, the growth indicators for the point sources
for 1985 through 1996 were assigned at the Standard Industrial Classification (SIC) level for all sources
except the stationary fuel combustion sources. A match-up between two digit SICs and SCCs, as well as
Tier category, is impossible, since the SICs are defined at the plant level but the SCCs are defined at the
process level. Therefore, the same SIC could be used in two or more Tier I categories. For example,
Plant A produces and stores adipic acid. This plant would be assigned SIC code 28 (Chemical and Allied
Products). The manufacturing section of the plant would be assigned an SCC of 3-01-001-03 and would
be included in Tier I category 04, Chemical and Allied Product Manufacturing. The section of the plant
where the adipic acid is stored would be assigned an SCC of 3-01-001-02 and would be included in Tier I
category 09, Storage and Transport. As this example shows, in order to use the methodology for the
years 1985 to 1996, both the SCC (to determine which Tier category methodology to apply) and the SIC
(to know which growth indicator to choose) must be known.
4.1.3 References
1. National Air Pollutant Emission Trends, 1900-1996, under development. U.S. Environmental
Protection Agency, Research Triangle Park, NC. October 1997.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-2 Introduction
-------
2. Regional Interim Emission Inventories (1987-1991), Volume I: Development Methodologies.
EPA-454/R-93-021a. U.S. Environmental Protection Agency, Research Triangle Park, NC. May
1993.
3. Development of the OPPE Paniculate Programs Implementation Evaluation System, Final,
Prepared for the Office of Policy, Planning and Evaluation/Office of Policy Analysis, U.S.
Environmental Protection Agency, under EPA Contract No. 68-D3-0035, Work Assignment
No. 0-10, Washington, DC. July 1994.
Table 4.1-1. Section 4.0 Structure
Subsection
Tier I
Tier I
4.1 Introduction
4.2 Fuel Combustion - Electric
Utility
Fuel Combustion - Electric Utility
(01)
Majority of Coal (01), Oil (02), and
Gas (03). The point level - steam
4.3 Industrial
Fuel Combustion - Electric Utility
(01)
Fuel Combustion - Industrial (02)
Chemical & Allied Product
Manufacturing (04)
Metals Processing (05)
Petroleum & Related Industries
(06)
Other Industrial Processes (07)
Storage & Transport (09)
Waste Disposal & Recycling (10)
_Mi_s_c_eJI_a_neous_(1jl_) _____________
Other Combustion (03)
_Mi_s_c_e_lla_neous_(Jj|_) _____________
_Solve_nt_ytiHzation_(08[ _________
Other [(04), mainly gas turbines],
Internal Combustion (05), The area
source level - steam generated
Coal (01), Oil (02), Gas (03).
All
All
All
All
All
All
All
_HeaJth_services
All
4.4 Other Combustion
L5Solvents
_AN
_AN
AN
.A-Z_Np_n_-j;pa_d_ Sources
4.8 Fugitive Dust
Natural Sources (13)
Miscellaneous (14)
Geogenic [(02), wind erosion only]
Agriculture & Forestry [(01),
agricultural crops and livestock
only]
Fugitive dust (07)
NOTE: Numbers in parentheses after Tier name are the Tier codes.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-3
1985-1996 Methodology
Introduction
-------
Table 4.1-2. Major Source Categories
Tier I
Code Category
Tier II
Code Category
01 FUEL COMBUSTION-ELECTRIC UTILITIES
02 FUEL COMBUSTION-INDUSTRIAL
03 FUEL COMBUSTION-OTHER
04 CHEMICAL & ALLIED PRODUCT MFG.
05 METALS PROCESSING
06 PETROLEUM & RELATED INDUSTRIES
07 OTHER INDUSTRIAL PROCESSES
08 SOLVENT UTILIZATION
01 Coal
02 Oil
03 Gas
04 Other
05 Internal Combustion
01 Coal
02 Oil
03 Gas
04 Other
05 Internal Combustion
01 Commercial / Institutional Coal
02 Commercial / Institutional Oil
03 Commercial / Institutional Gas
04 Misc. Fuel Combustion (except residential)
05 Residential Wood
06 Residential Other
01 Organic Chemical Mfg.
02 Inorganic Chemical Mfg.
03 Polymer & Resin Mfg.
04 Agricultural Chemical Mfg.
05 Paint, Varnish, Lacquer, Enamel Mfg.
06 Pharmaceutical Mfg.
07 Other Chemical Mfg.
01 Nonferrous
02 Ferrous
03 Not elsewhere classified (NEC)
01 Oil & Gas Production
02 Petroleum Refineries & Related Industries
03 Asphalt Manufacturing
01 Agriculture, Food, & Kindred Products
02 Textiles, Leather, & Apparel Products
03 Wood, Pulp & Paper, & Publishing Products
04 Rubber & Miscellaneous Plastic Products
05 Mineral Products
06 Machinery Products
07 Electronic Equipment
08 Transportation Equipment
09 Construction
10 Miscellaneous Industrial Processes
01 Degreasing
02 Graphic Arts
03 Dry Cleaning
04 Surface Coating
05 Other Industrial
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-4
1985-1996 Methodology
Introduction
-------
Tier I
Code Category
Table 4.1-2. (continued)
Tier II
Code Category
09 STORAGE & TRANSPORT
10 WASTE DISPOSAL & RECYCLING
11 ON-ROAD VEHICLES
12 NON-ROAD ENGINES AND VEHICLES
13 NATURAL SOURCES
14 MISCELLANEOUS
06 Nonindustrial
07 Solvent Utilization NEC
01 Bulk Terminals & Plants
02 Petroleum & Petroleum Product Storage
03 Petroleum & Petroleum Product Transport
04 Service Stations: Stage I
05 Service Stations: Stage II
06 Service Stations: Breathing & Emptying
07 Organic Chemical Storage
08 Organic Chemical Transport
09 Inorganic Chemical Storage
10 Inorganic Chemical Transport
11 Bulk Materials Storage
12 Bulk Materials Transport
01 Incineration
02 Open Burning
03 Publicly Owned Treatment Works
04 Industrial Waste Water
05 Treatment Storage and Disposal Facility
06 Landfills
07 Other
01 Light-Duty Gas Vehicles & Motorcycles
02 Light-Duty Gas Trucks
03 Heavy-Duty Gas Vehicles
04 Diesels
01 Non-road Gasoline
02 Non-road Diesel
03 Aircraft
04 Marine Vessels
05 Railroads
01 Biogenic
02 Geogenic
03 Miscellaneous (lightning, freshwater, saltwater)
01 Agriculture & Forestry
02 Other Combustion (forest fires)
03 Catastrophic/Accidental Releases
04 Repair Shops
05 Health Services
06 Cooling Towers
07 Fugitive Dust
NOTE(S): For the purposes of this report, forest fires are considered anthropogenic sources although many fires do occur naturally.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-5
1985-1996 Methodology
Introduction
-------
Table 4.1-3. Tier I and Tier II Match-up with Source Classification Codes
Tier I: 01 FUEL COMB. ELEC. UTIL.
Tier II: 01 Coal
- 10100306
- 2101003000
Oil
- 10100505
10100101
2101001000
Tier II: 02
10100401
2101004000
2101004001
2101005000
Tier II: 03 Gas
10100601 - 10100702
2101006000
2101006001
2101010000
Tier II: 04 Other
10100801 - 10101302
2101007000 - 2101009000
External Combustion Boilers Electric Generation
Stationary Source Fuel Combustion Electric Utility
External Combustion Boilers Electric Generation
Stationary Source Fuel Combustion Electric Utility Distillate Oil Total:
Stationary Source Fuel Combustion Electric Utility Distillate Oil All Bo
Stationary Source Fuel Combustion Electric Utility Residual Oil Total: A
External Combustion Boilers Electric Generation
Stationary Source Fuel Combustion Electric Utility Natural Gas Total: Bo
Stationary Source Fuel Combustion Electric Utility Natural Gas All Boile
Stationary Source Fuel Combustion Electric Utility Process Gas Total: Al
External Combustion Boilers Electric Generation
Stationary Source Fuel Combustion Electric Utility
Tier II: 05 Internal Combustion
20100101 - 20101031 Internal Combustion Engines Electric Generation
2101004002 Stationary Source Fuel Combustion Electric Utility Distillate Oil All I.
2101006002 Stationary Source Fuel Combustion Electric Utility Natural Gas All I.C.
Tier I: 02 FUEL COMB. INDUSTRIAL
Tier II: 01 Coal
Industrial Anthracite Coal Pulverized Coal
Space Heaters Industrial Coal **
Stationary Source Fuel Combustion Industrial Anthracite Coal Total: All
Stationary Source Fuel Combustion Industrial Bituminous/Subbituminous Coa
Industrial Processes In-Process Fuel Use Anthracite Coal Total
Industrial Processes In-Process Fuel Use Bituminous/Subbituminous Coal T
In-process Fuel Use In-process Fuel Use General
10200101
10500102
2102001000
2102002000
2390001000
2390002000
39000189
Tier II: 02 Oil
10200401
10201403
10201404
10500105
2102004000
2102005000
2390004000
2390005000
30190001
30190002
30190011
30190012
30290001
30290002
30390001
30390002
30390011
30390012
30390021
30390022
30490001
30490002
30490011
30490012
30490021
30490022
30490031
30490032
30500207
30500208
30590001
30590002
30590011
Industrial Residual Oil Grade 6 Oil
Industrial CO Boiler Distillate Oil
Industrial CO Boiler Residual Oil
Space Heaters Industrial Distillate Oil
Stationary Source Fuel Combustion Industrial Distillate Oil Total: Boile
Stationary Source Fuel Combustion Industrial Residual Oil Total: All Boi
Industrial Processes In-Process Fuel Use Distillate Oil Total
Industrial Processes In-Process Fuel Use Residual Oil Total
Chemical Manufacturing Fuel Fired Equipment Distillate Oil (No. 2): Distillate Hea
Chemical Manufacturing Fuel Fired Equipment Residual Oil: Process Heaters
Chemical Manufacturing Fuel Fired Equipment Distillate Oil (No. 2): Incinerators
Chemical Manufacturing Fuel Fired Equipment Residual Oil: Incinerators
Food and Agriculture Fuel Fired Equipment Distillate Oil (No. 2)
Food and Agriculture Fuel Fired Equipment Residual Oil
Primary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Process Heat
Primary Metal Production Fuel Fired Equipment Residual Oil: Process Heaters
Primary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Incinerators
Primary Metal Production Fuel Fired Equipment Residual Oil: Incinerators
Primary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Flares
Primary Metal Production Fuel Fired Equipment Residual Oil: Flares
Secondary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Process He
Secondary Metal Production Fuel Fired Equipment Residual Oil: Process Heaters
Secondary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Incinerate
Secondary Metal Production Fuel Fired Equipment Residual Oil: Incinerators
Secondary Metal Production Fuel Fired Equipment Distillate Oil (No.2)
Secondary Metal Production Fuel Fired Equipment Residual Oil
Secondary Metal Production Fuel Fired Equipment Distillate Oil: Furnaces
Secondary Metal Production Fuel Fired Equipment Residual Oil: Furnaces
Mineral Products Asphalt Concrete Asphalt Heater: Residual Oil (Use 3-05-050-21 fo
Mineral Products Asphalt Concrete Asphalt Heater: Distillate Oil (Use 3-05-050-22
Mineral Products Fuel Fired Equipment Distillate Oil (No. 2): Process Heaters
Mineral Products Fuel Fired Equipment Residual Oil: Process Heaters
Mineral Products Fuel Fired Equipment Distillate Oil (No. 2): Incinerators
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-6
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30590012
30600101
30600103
30600111
30600901
30600902
30609901
30609902
30790001
30790002
30790011
30790012
30790021
30790022
30890001
30890002
30890011
30890012
30990001
30990002
30990011
30990012
31000401
31000411
31390001
31390002
39000402
39990001
39990002
39990011
39990012
39990021
39990022
40201002
40201003
40290011
40290012
49090011
49090012
49090021
49090022
50390005
Tier II: 03 Gas
10200601
10201401
10201402
10500106
2102006000
2102006001
2102010000
2390006000
2390010000
30190003
30190004
30190013
30290003
30390003
30390004
30390013
30390014
30390023
30390024
30490003
30490004
30490013
Mineral Products Fuel Fired Equipment Residual Oil: Incinerators
Petroleum Industry Process Heaters Oil-fired **
Petroleum Industry Process Heaters Oil-fired
Petroleum Industry Process Heaters Oil-fired (No. 6 Oil) > 100 Million Btu Capacit
Petroleum Industry Flares Distillate Oil
Petroleum Industry Flares Residual Oil
Petroleum Industry Incinerators Distillate Oil (No. 2)
Petroleum Industry Incinerators Residual Oil
Pulp and Paper and Wood Products Fuel Fired Equipment Distillate Oil (No. 2): Proc
Pulp and Paper and Wood Products Fuel Fired Equipment Residual Oil: Process Heater
Pulp and Paper and Wood Products Fuel Fired Equipment Distillate Oil (No. 2): Inci
Pulp and Paper and Wood Products Fuel Fired Equipment Residual Oil: Incinerators
Pulp and Paper and Wood Products Fuel Fired Equipment Distillate Oil (No. 2)
Pulp and Paper and Wood Products Fuel Fired Equipment Residual Oil
Rubber and Miscellaneous Plastics Products Process Heaters Distillate Oil (No. 2)
Rubber and Miscellaneous Plastics Products Process Heaters Residual Oil
Rubber and Miscellaneous Plastics Products Process Heaters Distillate Oil (No. 2):
Rubber and Miscellaneous Plastics Products Process Heaters Residual Oil: Incinerat
Fabricated Metal Products Fuel Fired Equipment Distillate Oil (No. 2): Process Hea
Fabricated Metal Products Fuel Fired Equipment Residual Oil: Process Heaters
Fabricated Metal Products Fuel Fired Equipment Distillate Oil (No. 2): Incinerator
Fabricated Metal Products Fuel Fired Equipment Residual Oil: Incinerators
Oil and Gas Production Process Heaters Distillate Oil (No. 2)
Oil and Gas Production Process Heaters Distillate Oil (No. 2): Steam Generators
Electrical Equipment Process Heaters Distillate Oil (No. 2)
Electrical Equipment Process Heaters Residual Oil
In-process Fuel Use In-process Fuel Use Cement Kiln/Dryer
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Dist
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Resi
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Dist
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Resi
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Dist
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Resi
Surface Coating Operations Coating Oven Heater Distillate Oil
Surface Coating Operations Coating Oven Heater Residual Oil
Surface Coating Operations Fuel Fired Equipment Distillate Oil: Incinerator/Afterb
Surface Coating Operations Fuel Fired Equipment Residual Oil: Incinerator/Afterbur
Organic Solvent Evaporation Fuel Fired Equipment Distillate Oil (No. 2): Incinerat
Organic Solvent Evaporation Fuel Fired Equipment Residual Oil: Incinerators
Organic Solvent Evaporation Fuel Fired Equipment Distillate Oil (No. 2): Flares
Organic Solvent Evaporation Fuel Fired Equipment Residual Oil: Flares
Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Distillate Oil
Industrial Natural Gas > 100 Million Btu/hr
Industrial CO Boiler Natural Gas
Industrial CO Boiler Process Gas
Space Heaters Industrial Natural Gas
Stationary Source Fuel Combustion Industrial Natural Gas Total: Boilers
Stationary Source Fuel Combustion Industrial Natural Gas All Boiler Type
Stationary Source Fuel Combustion Industrial Process Gas Total: All Boil
Industrial Processes In-Process Fuel Use Natural Gas Total
Industrial Processes In-Process Fuel Use Process Gas Total
Chemical Manufacturing Fuel Fired Equipment Natural Gas: Distillate Heaters
Chemical Manufacturing Fuel Fired Equipment Process Gas
Chemical Manufacturing Fuel Fired Equipment Natural Gas: Incinerators
Food and Agriculture Fuel Fired Equipment Natural Gas
Primary Metal Production Fuel Fired Equipment Natural Gas: Process Heaters
Primary Metal Production Fuel Fired Equipment Process Gas: Process Heaters
Primary Metal Production Fuel Fired Equipment Natural Gas: Incinerators
Primary Metal Production Fuel Fired Equipment Process Gas: Incinerators
Primary Metal Production Fuel Fired Equipment Natural Gas: Flares
Primary Metal Production Fuel Fired Equipment Process Gas: Flares
Secondary Metal Production Fuel Fired Equipment Natural Gas
Secondary Metal Production Fuel Fired Equipment Process Gas: Process Heaters
Secondary Metal Production Fuel Fired Equipment Natural Gas: Incinerators
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-7
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30490014
30490023
30490024
30490033
30490034
30490035
30500206
30590003
30590013
30590023
30600102
30600104
30600108
30600903
30600904
30609903
30609904
30790003
30790013
30790023
30890003
30890013
30890023
30990003
30990013
30990023
31000205
31000404
31000405
31000414
31000415
31390003
39000602
39900601
39990003
39990004
39990013
39990014
39990023
39990024
40201001
40290013
40290023
49090013
49090023
50390006
Tier II: 04
10200801
10500110
2102007000
2390007000
30290005
30500209
30600107
30600199
30600905
30600999
30609905
30890004
39000801
40201004
50390010
Tier II: 05
20180001
20200101
Other
- 10201302
- 10500114
- 2102009000
- 2390009000
Secondary Metal Production Fuel Fired Equipment Process Gas: Incinerators
Secondary Metal Production Fuel Fired Equipment Natural Gas
Secondary Metal Production Fuel Fired Equipment Process Gas: Flares
Secondary Metal Production Fuel Fired Equipment Natural Gas: Furnaces
Secondary Metal Production Fuel Fired Equipment Process Gas: Furnaces
Secondary Metal Production Fuel Fired Equipment Propane
Mineral Products Asphalt Concrete Asphalt Heater: Natural Gas (Use 3-05-050-20 for
Mineral Products Fuel Fired Equipment Natural Gas: Process Heaters
Mineral Products Fuel Fired Equipment Natural Gas: Incinerators
Mineral Products Fuel Fired Equipment Natural Gas: Flares
Petroleum Industry Process Heaters Gas-fired **
Petroleum Industry Process Heaters Gas-fired
Petroleum Industry Process Heaters Landfill Gas-fired
Petroleum Industry Flares Natural Gas
Petroleum Industry Flares Process Gas
Petroleum Industry Incinerators Natural Gas
Petroleum Industry Incinerators Process Gas
Pulp and Paper and Wood Products Fuel Fired Equipment Natural Gas: Process Heaters
Pulp and Paper and Wood Products Fuel Fired Equipment Natural Gas: Incinerators
Pulp and Paper and Wood Products Fuel Fired Equipment Natural Gas: Flares
Rubber and Miscellaneous Plastics Products Process Heaters Natural Gas
Rubber and Miscellaneous Plastics Products Process Heaters Natural Gas: Incinerate
Rubber and Miscellaneous Plastics Products Process Heaters Natural Gas: Flares
Fabricated Metal Products Fuel Fired Equipment Natural Gas: Process Heaters
Fabricated Metal Products Fuel Fired Equipment Natural Gas: Incinerators
Fabricated Metal Products Fuel Fired Equipment Natural Gas: Flares
Oil and Gas Production Natural Gas Production Flares
Oil and Gas Production Process Heaters Natural Gas
Oil and Gas Production Process Heaters Process Gas
Oil and Gas Production Process Heaters Natural Gas: Steam Generators
Oil and Gas Production Process Heaters Process Gas: Steam Generators
Electrical Equipment Process Heaters Natural Gas
In-process Fuel Use In-process Fuel Use Cement Kiln/Dryer
Miscellaneous Manufacturing Industries Process Heater/Furnace Natural Gas
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Natu
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Proc
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Natu
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Proc
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Natu
Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries Proc
Surface Coating Operations Coating Oven Heater Natural Gas
Surface Coating Operations Fuel Fired Equipment Natural Gas: Incinerator/Afterburn
Surface Coating Operations Fuel Fired Equipment Natural Gas: Flares
Organic Solvent Evaporation Fuel Fired Equipment Natural Gas: Incinerators
Organic Solvent Evaporation Fuel Fired Equipment Natural Gas: Flares
Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Natural Gas
External Combustion Boilers Industrial
External Combustion Boilers Space Heaters Industrial
Stationary Source Fuel Combustion Industrial
Industrial Processes In-Process Fuel Use
Food and Agriculture Fuel Fired Equipment Process Heaters: LPG
Mineral Products Asphalt Concrete Asphalt Heater: LPG (Use 3-05-050-23 for MACT)
Petroleum Industry Process Heaters LPG-fired
Petroleum Industry Process Heaters Other Not Classified
Petroleum Industry Flares Liquified Petroleum Gas
Petroleum Industry Flares Not Classified **
Petroleum Industry Incinerators Liquified Petroleum Gas
Rubber and Miscellaneous Plastics Products Process Heaters Liquified Petroleum Gas
- 39001399 In-Process Fuel Use In-Process Fuel Use
Surface Coating Operations Coating Oven Heater Liquified Petroleum Gas (LPG)
Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Liquified Petroleum
Internal Combustion
Electric Generation Equipment Leaks Equipment Leaks
- 20201002 Internal Combustion Engines Industrial
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-8
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
2102006002
27501001
27501014
27501015
27502001
27502011
27505001
27505011
27601014
27601015
28000211
28000212
28000213
28000216
28000217
28000218
Stationary Source Fuel Combustion Industrial Natural Gas All I.C. Engine
Fixed Wing Aircraft L & TO Exhaust Military Piston Engine: Aviation Gas
Fixed Wing Aircraft L & TO Exhaust Military Jet Engine: JP-4
Fixed Wing Aircraft L & TO Exhaust Military Jet Engine: JP-5
Fixed Wing Aircraft L & TO Exhaust Commercial Piston Engine: Aviation Gas
Fixed Wing Aircraft L & TO Exhaust Commercial Jet Engine: Jet A
Fixed Wing Aircraft L & TO Exhaust Civil Piston Engine: Aviation Gas
Fixed Wing Aircraft L & TO Exhaust Civil Jet Engine: Jet A
Rotary Wing Aircraft L & TO Exhaust Military Jet Engine: JP-4
Rotary Wing Aircraft L & TO Exhaust Military Jet Engine: JP-5
Diesel Marine Vessels Commercial Crew Boats: Main Engine Exhaust: Idling
Diesel Marine Vessels Commercial Crew Boats: Main Engine Exhaust: Maneuvering
Diesel Marine Vessels Commercial Crew Boats: Auxiliary Generator Exhaust: Hotellin
Diesel Marine Vessels Commercial Supply Boats: Main Engine Exhaust: Idling
Diesel Marine Vessels Commercial Supply Boats: Main Engine Exhaust: Maneuvering
Diesel Marine Vessels Commercial Supply Boats: Auxiliary Generator Exhaust: Hotell
Tier I: 03 FUEL COMB. OTHER
Tier II: 01 Commercial/Institutional Coal
10300101
10500202
2103001000
2103002000
2199001000
Tier II: 02
10300401
10500205
20300101
20300102
20300107
2103004000
2103005000
2199004000
50190005
50290005
Tier II:
10300601
10500206
20300201
2103006000
2199006000
27300320
50190006
50290006
03
- 10300309 External Combustion Boilers Commercial/Institutional
Space Heaters Commercial/Institutional Coal **
Stationary Source Fuel Combustion Commercial/Institutional Anthracite Coa
Stationary Source Fuel Combustion Commercial/Institutional Bituminous/Sub
- 2199003000 Stationary Source Fuel Combustion Total Area Source Fuel Combustion
Commercial/Institutional Oil
- 10300504 External Combustion Boilers Commercial/Institutional
Space Heaters Commercial/Institutional Distillate Oil
Commercial/Institutional Distillate Oil (Diesel) Reciprocating
Commercial/Institutional Distillate Oil (Diesel) Turbine
Commercial/Institutional Distillate Oil (Diesel) Reciprocating: Exhaust
Stationary Source Fuel Combustion Commercial/Institutional Distillate Oil
Stationary Source Fuel Combustion Commercial/Institutional Residual Oil
- 2199005000 Stationary Source Fuel Combustion Total Area Source Fuel Combustion
Solid Waste Disposal - Government Auxiliary Fuel/No Emissions Distillate Oil
Solid Waste Disposal - Commercial/Institutional Auxiliary Fuel/No Emissions Distil
Commercial/Institutional Gas
- 10300799 External Combustion Boilers Commercial/Institutional
Space Heaters Commercial/Institutional Natural Gas
- 20300702 Internal Combustion Engines Commercial/Institutional
Stationary Source Fuel Combustion Commercial/Institutional Natural Gas T
- 2199006002 Stationary Source Fuel Combustion Total Area Source Fuel Combustion Natural Gas
Non-road Sources LPG-fueled Engines Industrial Equipment Industrial Fork Lift: Liquifie
Solid Waste Disposal - Government Auxiliary Fuel/No Emissions Natural Gas
Solid Waste Disposal - Commercial/Institutional Auxiliary Fuel/No Emissions Natura
Tier II: 04 Misc. Fuel Comb. (Except Residential)
10300901 - 10301303 External Combustion Boilers Commercial/Institutional
10500209 - 10500214 External Combustion Boilers Space Heaters Commercial-Institutional
20190099 Electric Generation Flares Heavy Water
20301001 - 20400402 Internal Combustion Engines
2103007000 - 2103011010 Stationary Source Fuel Combustion Commercial/Institutional
2199007000 Stationary Source Fuel Combustion Total Area Source Fuel Combustion Liqui
2199009000 - 2199011000 Stationary Source Fuel Combustion Total Area Source Fuel Combustion
28888801 - 28888803 Internal Combustion Engines Fugitive Emissions Other Not ClassifiedSpecify in Co
50190010 Solid Waste Disposal - Government Auxiliary Fuel/No Emissions Liquified Petroleum
50290010 Solid Waste Disposal - Commercial/Institutional Auxiliary Fuel/No Emissions Liquif
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-9
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
Tier II: 05 Residential Wood
2104008000 - 2104008053 Stationary Source Fuel Combustion Residential Wood
2199008000 Stationary Source Fuel Combustion Total Area Source Fuel Combustion Wood
Tier II: 06 Residential Other
2104001000 - 2104007000 Stationary Source Fuel Combustion Residential
2104011000 Stationary Source Fuel Combustion Residential Kerosene Total: All Heater
Tier I: 04 CHEMICAL & ALLIED PRODUCT MFC
Tier II: 01 Organic Chemicals
2301000000 Industrial Processes Chemical Manufacturing: SIC 28 All Process Total
2301040000 Industrial Processes Chemical Manufacturing: SIC 28
30100101 Chemical Manufacturing Adipic Acid General
30100103 - 30100105 Chemical Manufacturing Chemical Manufacturing Adipic Acid
30100107 - 30100199 Chemical Manufacturing Chemical Manufacturing Adipic Acid
30100601 - 30100699 Chemical Manufacturing Chemical Manufacturing Charcoal Manufacture
30101901 - 30101907 Chemical Manufacturing Chemical Manufacturing Phthalic Anhydride
30103101 - 30103104 Chemical Manufacturing Chemical Manufacturing Terephthalic Acid/DimethylTerephth
30103180 Chemical Manufacturing Terephthalic Acid/Dimethyl Terephthalate Fugitive Emissions
30103199 Chemical Manufacturing Terephthalic Acid/Dimethyl Terephthalate Other Not Classifi
30103402 - 30103499 Chemical Manufacturing Chemical Manufacturing
30104201 - 30104203 Chemical Manufacturing Lead Alkyl Mfg. Na/Pb Alloy Process
30104301 Chemical Manufacturing Lead Alkyl Manufacturing (Electrolytic Process) General
30109101 - 30110099 Chemical Manufacturing Chemical Manufacturing
30112001 - 30112780 Chemical Manufacturing Chemical Manufacturing
30113201 - 30121009 Chemical Manufacturing
30121080 - 30130107 Chemical Manufacturing Chemical Manufacturing
30130110 - 30181001 Chemical Manufacturing Chemical Manufacturing
30184001 Chemical Manufacturing General Processes Distillation Units
Tier II: 02 Inorganic Chemicals
2301010000 Industrial Processes Chemical Manufacturing: SIC 28 Industrial Inorganic
2301010010 Industrial Processes Chemical Manufacturing: SIC 28 Industrial Inorganic
30100801 Chemical Manufacturing Chloro-alkali Production Liquefaction (Diaphragm Cell Proc
30100802 Chemical Manufacturing Chloro-alkali Production Liquefaction (Mercury Cell Proces
30100805 Chemical Manufacturing Chloro-alkali Production Air Blowing of Mercury Cell Brine
30100899 Chemical Manufacturing Chloro-alkali Production Other Not Classified
30101101 Chemical Manufacturing Hydrochloric Acid By-product Process
30101199 - 30101203 Chemical Manufacturing Chemical Manufacturing
30101206 Chemical Manufacturing Hydroflouric Acid Tail Gas Vent
30101299 Chemical Manufacturing Hydroflouric Acid Other Not Classified
30102101 - 30102319 Chemical Manufacturing
30102322 Chemical Manufacturing Sulfuric Acid (Contact Process) Process Equipment Leaks
30102399 Chemical Manufacturing Sulfuric Acid (Contact Process) Other Not Classified
30103201 - 30103299 Chemical Manufacturing Chemical Manufacturing Elemental Sulfur Production
30103501 - 30103553 Chemical Manufacturing Chemical Manufacturing Inorganic Pigments
30103599 - 30103903 Chemical Manufacturing Chemical Manufacturing
30107001 Chemical Manufacturing Inorganic Chemical Manufacturing (General) Fugitive Leaks
30111201 - 30111401 Chemical Manufacturing Chemical Manufacturing
Tier II: 03 Polymers & Resins
2301020000 Industrial Processes Chemical Manufacturing: SIC 28
30101801 - 30101807 Chemical Manufacturing Plastics Production Specific Products
30101809 Chemical Manufacturing Plastics Production Extruder
30101812 - 30101814 Chemical Manufacturing Plastics Production Specific Products
30101817 - 30101820 Chemical Manufacturing Plastics Production Specific Products
30101822 - 30101839 Chemical Manufacturing Plastics Production Specific Products
30101842 - 30101863 Chemical Manufacturing
30101870 - 30101882 Chemical Manufacturing Chemical Manufacturing
30101885 - 30101892 Chemical Manufacturing
30101899 Chemical Manufacturing Plastics Production Others Not Specified
30102401 -30102424 Chemical Manufacturing Syn. Org. Fiber Mfg.
30102426 Chemical Manufacturing Synthetic Organic Fiber Manufacturing Equipment Cleanup (Us
30102499 - 30102611 Chemical Manufacturing
30102613 - 30102699 Chemical Manufacturing
64520011 Miscellaneous Resins Alkyd Resin Production, Solvent Process Polymerization Reacti
64630001 Vinyl-based Resins Polyvinyl Chloride and Copolymers Production - Suspension Proce
64630052 Vinyl-based Resins Polyvinyl Chloride and Copolymers Production - Suspension Proce
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-10
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
64920030 Fibers Production Processes Rayon Fiber Production Fiber Finishing
Tier II: 04 Agricultural Chemicals
30100305 - 30100399 Chemical Manufacturing Chemical Manufacturing Ammonia Production
30101301 - 30101399 Chemical Manufacturing Chemical Manufacturing Nitric Acid
30101601 Chemical Manufacturing Phosphoric Acid: Wet Process Reactor
30101603 - 30101799 Chemical Manufacturing Chemical Manufacturing
30102701 - 30102708 Chemical Manufacturing Chemical Manufacturing Ammonium Nitrate Production
30102710 - 30102801 Chemical Manufacturing Chemical Manufacturing
30102806 - 30102820 Chemical Manufacturing Chemical Manufacturing Normal Superphosphate
30102822 - 30102825 Chemical Manufacturing Chemical Manufacturing Normal Superphosphate
30102906 - 30102920 Chemical Manufacturing Chemical Manufacturing Triple Superphosphate
30102922 - 30103002 Chemical Manufacturing Chemical Manufacturing
30103004 - 30103099 Chemical Manufacturing Chemical Manufacturing Ammonium Phosphates
30103301 - 30103399 Chemical Manufacturing Chemical Manufacturing Pesticides
30104001 - 30104006 Chemical Manufacturing Chemical Manufacturing Urea Production
30104008 - 30104013 Chemical Manufacturing Chemical Manufacturing Urea Production
30104501 Chemical Manufacturing Organic Fertilizer General: Mixing/Handling
30113004 Chemical Manufacturing Ammonium Sulfate (Use 3-01-210 for Caprolactum Production)
30113005 Chemical Manufacturing Ammonium Sulfate (Use 3-01-210 for Caprolactum Production)
Tier II: 05 Paints, Varnishs, Lacquers, Enamels
30101401 - 30101403 Chemical Manufacturing Chemical Manufacturing Paint Manufacture
30101415 Chemical Manufacturing Paint Manufacture Premix/Preassembly
30101430 Chemical Manufacturing Paint Manufacture Pigment Grinding/Milling
30101450 Chemical Manufacturing Paint Manufacture Product Finishing
30101451 Chemical Manufacturing Paint Manufacture Product Finishing, Tinting: Mix Tank and
30101470 Chemical Manufacturing Paint Manufacture Equipment Cleaning
30101498 Chemical Manufacturing Paint Manufacture Other Not Classified
30101499 - 30101599 Chemical Manufacturing Chemical Manufacturing
Tier II: 06 Pharmaceuticals
2301030000 Industrial Processes Chemical Manufacturing: SIC 28
30106001 - 30106009 Chemical Manufacturing Chemical Manufacturing Pharmaceutical Preparations
30106011 - 30106099 Chemical Manufacturing Chemical Manufacturing Pharmaceutical Preparations
Tier II: 07 Other Chemicals
30100501 - 30100507 Chemical Manufacturing Chemical Manufacturing Carbon Black Production
30100509 Chemical Manufacturing Carbon Black Production Furnace Process: Fugitive Emissions
30100599 Chemical Manufacturing Carbon Black Production Other Not Classified
30100701 - 30100799 Chemical Manufacturing Chemical Manufacturing
30100901 - 30101014 Chemical Manufacturing
30101021 Chemical Manufacturing Explosives (Trinitrotoluene) Continuous Process: Nitration
30101022 Chemical Manufacturing Explosives (Trinitrotoluene) Continuous Process: Nitration
30101099 Chemical Manufacturing Explosives (Trinitrotoluene) Other Not Classified
30102001 - 30102099 Chemical Manufacturing Chemical Manufacturing Printing Ink Manufacture
30104101 - 30104199 Chemical Manufacturing Chemical Manufacturing Nitrocellulose
30105001 Chemical Manufacturing Adhesives General/Compound Unknown **
30111103 Chemical Manufacturing Asbestos Chemical Brake Line/Grinding **
30111199 Chemical Manufacturing Asbestos Chemical Not Classified **
30188801 - 30188805 Chemical Manufacturing Chemical Manufacturing Fugitive Emissions Specify inComme
30196099 Chemical Manufacturing
30199998 Chemical Manufacturing Other Not Classified Specify in Comments Field
30199999 Chemical Manufacturing Other Not Classified Specify in Comments Field
Tier I: 05 METALS PROCESSING
Tier II: 01 Non-Ferrous Metals Processing
2304050000 Industrial Processes Secondary Metal Production: SIC 33 Nonferrous Foundr
30300001 Primary Metal Production Aluminum Ore (Bauxite) Crushing/Handling
30300002 Primary Metal Production Aluminum Ore (Bauxite) Drying Oven
30300101 - 30300201 Primary Metal Production Primary Metal Production
30300502 - 30300518 Primary Metal Production Primary Metal Production Primary Copper Smelting
30300521 - 30300599 Primary Metal Production Primary Metal Production Primary Copper Smelting
30301001 - 30301010 Primary Metal Production Primary Metal Production Lead Production
30301014 Primary Metal Production Lead Production Sintering Charge Mixing
30301015 Primary Metal Production Lead Production Sinter Crushing/Screening
30301017 - 30301025 Primary Metal Production Primary Metal Production Lead Production
30301099 - 30301499 Primary Metal Production Primary Metal Production
30303002 - 30303008 Primary Metal Production Primary Metal Production Zinc Production
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-11
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30303010
30303011
30303014
30400101
30400401
30400801
30401001
30404001
36000101
30303099
30400299
30400699
30400899
30401099
Primary Metal Production Zinc Production Sinter Breaking and Cooling
Primary Metal Production Zinc Production Zinc Casting
Primary Metal Production Primary Metal Production Zinc Production
Secondary Metal Production
Secondary Metal Production Secondary Metal Production
Secondary Metal Production Secondary Metal Production Nickel Production
Secondary Metal Production Lead Cable Coating General
Printing and Publishing Typesetting (Lead Remelting) Remelting (Lead Emissions Onl
Tier II: 02 Ferrous Metals Processing
2303020000 Industrial Processes Primary Metal Production: SIC 33 Iron & Steel Foundr
30300302 - 30300304 Primary Metal Production Primary Metal Production By-Product Coke Manufacturing
30300306 - 30300308 Primary Metal Production Primary Metal Production By-Product Coke Manufacturing
30300310 - 30300315 Primary Metal Production Primary Metal Production By-Product Coke Manufacturing
30300331 - 30300401 Primary Metal Production Primary Metal Production
30300601 - 30300611 Primary Metal Production Ferroalloy Open Furnace
30300615 - 30300802 Primary Metal Production
30300808 Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
30300813 - 30300819 Primary Metal Production Iron Production Sintering
30300824 - 30300826 Primary Metal Production Iron Production Blast Furnaces
30300899 - 30300914 Primary Metal Production
30300916 - 30300999 Primary Metal Production Primary Metal Production Steel Production
30302301 - 30302303 Primary Metal Production Primary Metal Production Taconite Iron Ore Processing
30302306 Primary Metal Production Taconite Iron Ore Processing Dry Grinding/Milling
30302308 Primary Metal Production Taconite Iron Ore Processing Bentonite Blending
30302311 - 30302315 Primary Metal Production Primary Metal Production Taconite Iron Ore Processing
30400301 - 30400355 Secondary Metal Production Secondary Metal Production Gray Iron Foundries
30400358 - 30400399 Secondary Metal Production Secondary Metal Production Gray Iron Foundries
30400701 - 30400720 Secondary Metal Production Secondary Metal Production Steel Foundries
30400722 Secondary Metal Production Steel Foundries Muller
30400724 - 30400799 Secondary Metal Production Secondary Metal Production Steel Foundries
30400901 Secondary Metal Production Malleable Iron Annealing
30400999 Secondary Metal Production Malleable Iron Other Not Classified
30405001 Secondary Metal Production Miscellaneous Casting Fabricating Other Not Classified
30405099 Secondary Metal Production Miscellaneous Casting Fabricating Other Not Classified
Tier II: 03 Metals Processing NEC
2303000000 Industrial Processes Primary Metal Production: SIC 33 All Processes Tola
2304000000 Industrial Processes Secondary Metal Production: SIC 33 All Processes To
30302401 - 30302411 Primary Metal Production Metal Mining General Processes
30388801 - 30388805 Primary Metal Production Primary Metal Production Fugitive Emissions SpecifyiCom
30399999 Primary Metal Production Other Not Classified Other Not Classified
30402001 - 30402211 Secondary Metal Production Secondary Metal Production
30404901 - 30404999 Secondary Metal Production Secondary MetalProductsMiscellaneous Castingand
30488801 - 30488805 Secondary Metal Production Secondary Metal Production Fugitive Emissions Specif
30499999 Secondary Metal Production Other Not Classified Specify in Comments Field
Tier I: 06 PETROLEUM & RELATED INDUSTRIES
Tier II: 01 Oil & Gas Production
2310000000 - 2310030000 Industrial Processes Oil & Gas Production: SIC 13
31000101 - 31000103 Oil and Gas Production Oil and Gas Production Crude Oil Production
31000160 Oil and Gas Production Crude Oil Production Flares
31000199 - 31000204 Oil and Gas Production Oil and Gas Production
31000206 - 31000299 Oil and Gas Production Oil and Gas Production Natural Gas Production
31000301 Oil and Gas Production Natural Gas Processing Facilities Glycol Dehydrators: Reboi
31000302 Oil and Gas Production Natural Gas Processing Facilities Glycol Dehydrators: Reboi
31000303 Oil and Gas Production Natural Gas Processing Facilities Glycol Dehydrators: Phase
31000304 Oil and Gas Production Natural Gas Processing Facilities Glycol Dehydrators: Ethyl
31000305 Oil and Gas Production Natural Gas Processing Facilities Gas Sweeting: Amine Proce
31000306 Oil and Gas Production Natural Gas Processing Facilities Process Valves
31000309 Oil and Gas Production Natural Gas Processing Facilities Compressor Seals
31000310 Oil and Gas Production Natural Gas Processing Facilities Pump Seals
31000311 Oil and Gas Production Natural Gas Processing Facilities Flanges and Connections
31000406 Oil and Gas Production Process Heaters Propane/Butane
31088801 - 31088805 Oil and Gas Production Oil and Gas ProductionFugitive EmissionsSpecify in Comment
Tier II: 02 Petroleum Refineries & Related Industries
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-12
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
2306000000 Industrial Processes Petroleum Refining: SIC 29 All Processes Total
30600201 - 30600822 Petroleum Industry Petroleum Industry
30601001 - 30601599 Petroleum Industry Petroleum Industry
30610001 - 30699999 Petroleum Industry Petroleum Industry
Tier II: 03 Asphalt Manufacturing
2306010000 Industrial Processes Petroleum Refining: SIC 29 Asphalt Paving/Roofing Ma
30500101 - 30500202 Mineral Products Mineral Products
30500204 Mineral Products Asphalt Concrete Cold Aggregate Handling
30500205 Mineral Products Asphalt Concrete Drum Dryer: Hot Asphalt Plants
30500211 Mineral Products Asphalt Concrete Rotary Dryer Conventional Plant with Cyclone
30500212 Mineral Products Asphalt Concrete Heated Asphalt Storage Tanks: Drum Mix
30500213 Mineral Products Asphalt Concrete Storage Silo
30500214 Mineral Products Asphalt Concrete Truck Load-out
30500221 Mineral Products Asphalt Concrete Elevators: Continuous Process
30500290 Mineral Products Asphalt Concrete Haul Roads: General
30500298 Mineral Products Asphalt Concrete Other Not Classified
30500299 Mineral Products Asphalt Concrete See Comment **
Tier I: 07 OTHER INDUSTRIAL PROCESSES
Tier II: 01 Agriculture, Food, & Kindred Products
2302000000 - 2302080000 Industrial Processes Food & Kindred Products: SIC 20
2801600000 Miscellaneous Area Sources Agriculture Production - Crops Country Grain E
30200101 - 30200504 Food and Agriculture Food and Agriculture
30200512 - 30200604 Food and Agriculture Food and Agriculture
30200611 - 30200705 Food and Agriculture Food and Agriculture
30200712 - 30200714 Food and Agriculture Food and Agriculture Durum Milling
30200722 - 30200730 Food and Agriculture Food and Agriculture
30200732 - 30200734 Food and Agriculture Food and Agriculture Wheat Milling
30200740 Food and Agriculture Grain Millings Dry Corn Milling: Silo Storage
30200742 - 30200745 Food and Agriculture Food and Agriculture Corn: Dry Milling
30200748 Food and Agriculture Grain Millings Dry Corn Milling: Grinding
30200752 - 30200754 Food and Agriculture Food and Agriculture Corn: Wet Milling
30200756 Food and Agriculture Grain Millings Wet Corn Milling: Milling
30200760 Food and Agriculture Grain Millings Oat: General
30200763 Food and Agriculture Grain Millings Gluten Feed Drying: Direct-fired Dryer - Produ
30200772 - 30200774 Food and Agriculture Food and Agriculture Rice Milling
30200782 - 30200790 Food and Agriculture Food and Agriculture Soybean Mills
30200799 Food and Agriculture Grain Millings See Comments **
30200801 Food and Agriculture Feed Manufacture General **
30200804 - 30201919 Food and Agriculture
30201945 Food and Agriculture Vegetable Oil Processing Oil Refining: Oil Stripping Column
30201998 Food and Agriculture Vegetable Oil Processing Soybean Oil Production: Complete Pro
30201999 - 30203104 Food and Agriculture
30203201 - 30288805 Food and Agriculture
30299998 Food and Agriculture Other Not Specified Other Not Classified
30299999 Food and Agriculture Other Not Specified Other Not Classified
Tier II: 02 Textiles, Leather, & Apparel Products
32099997 - 33088805 Textiles, Leather, & Apparel Products
Tier II: 03 Wood, Pulp & Paper, & Publishing Products
2307000000 Industrial Processes Wood Products: SIC 24 All Processes Total
2307020000 - 2307060000 Industrial Processes Wood Products: SIC 24
30700101 - 30702099 Pulp & Paper and Wood Products Pulp & Paper and Wood Products
30703003 - 30788898 Pulp & Paper and Wood Products Pulp & Paper and Wood Products
30799901 Pulp and Paper and Wood Products Other Not Classified Battery Separators
30799998 Pulp and Paper and Wood Products Other Not Classified Other Not Classified
30799999 Pulp and Paper and Wood Products Other Not Classified See Comment **
Tier II: 04 Rubber & Miscellaneous Plastic Products
2308000000 Industrial Processes Rubber/Plastics: SIC 30 All Processes Total
30800101 - 30800108 Rubber and Miscellaneous Plastics Products Rubber and Miscellaneous Plastics Prod
30800120 - 30800802 Rubber and Miscellaneous Plastics Products Rubber and Miscellaneous Plastics Prod
30800901 Rubber and Miscellaneous Plastics Products Plastic Miscellaneous Products Polystyr
30899999 Rubber and Miscellaneous Plastics Products Other Not Specified Other Not Classifie
Tier II: 05 Mineral Products
2305000000 - 2305080000 Industrial Processes Mineral Processes: SIC 32
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-13
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30500231
30500301
30500302
30500304
30500499
30500609
30500613
30500614
30500617
30500623
30500624
30500626
30500627
30500629
30500699
30500706
30500709
30500714
30500717
30500799
30500806
30500810
30500907
30500915
30501010
30501012
30501013
30501017
30501022
30501034
30501035
30501099
30501101
30501112
30501113
30501120
30501223
30501505
30501511
30501515
30501519
30501609
30501611
30501612
30501616
30501905
30502008
30502012
30502201
30502508
30503108
30503109
30503199
30504024
30504030
30504099
30515001
30599999
Tier II: 06
2309000000
30900198
30988806
30999997
Tier II: 07
31303502
- 30500405
- 30500606
- 30500611
- 30500711
- 30500802
- 30500904
- 30500909
- 30501007
- 30501215
- 30501503
- 30501507
- 30501513
- 30501517
- 30501606
- 30501902
- 30502006
- 30502010
- 30502105
- 30502501
- 30503103
- 30504010
- 30504034
- 30509101
- 30588805
Machinery
- 230910026C
- 30988805
- 30999999
Electronic
Mineral Products Asphalt Concrete Hot Bins and Screens: Continuous Process
Mineral Products Brick Manufacture Raw Material Drying
Mineral Products Brick Manufacture Raw Material Grinding
Mineral Products Mineral Products
Mineral Products Mineral Products
Mineral Products Mineral Products Cement Manufacturing: Dry Process
Mineral Products Cement Manufacturing (Dry Process) Raw Material Grinding and Dryi
Mineral Products Cement Manufacturing (Dry Process) Clinker Cooler
Mineral Products Cement Manufacturing (Dry Process) Clinker Grinding
Mineral Produc s Cement Manufacturing (Dry Process) Preheater/Precalciner Kiln
Mineral Produc s Cement Manufacturing (Dry Process) Raw Mill Feed Belt
Mineral Products Cement Manufacturing (Dry Process) Raw Mill Air Separator
Mineral Produc s Cement Manufacturing (Dry Process) Finish Grinding Mill Feed Belt
Mineral Produc s Cement Manufacturing (Dry Process) Finish Grinding Mill Air Separ
Mineral Produc s Cement Manufacturing (Dry Process) Other Not Classified
Mineral Produc s Cement Manufacturing (Wet Process) Kilns
Mineral Produc s Mineral Products Cement Manufacturing: Wet Process
Mineral Produc s Cement Manufacturing (Wet Process) Clinker Cooler
Mineral Produc s Cement Manufacturing (Wet Process) Clinker Grinding
Mineral Products Mineral Products
Mineral Products Ceramic Clay/Tile Manufacture Raw Material Handling and Transfer
Mineral Products Mineral Products
Mineral Products Mineral Products Clay & Fly Ash Sintering
Mineral Products
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Crushin
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Screeni
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Air Tab
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Seconda
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Drillin
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Coal Se
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Blastin
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Other N
Mineral Products Concrete Batching General (Non-fugitive)
Mineral Products Concrete Batching Mixing: Wet
Mineral Products Concrete Batching Mixing: Dry
Mineral Products
Mineral Products
Mineral Products Mineral Products Gypsum Manufacture
Mineral Products Mineral Products Gypsum Manufacture
Mineral Products Mineral Products Gypsum Manufacture
Mineral Products Mineral Products
Mineral Products Lime Manufacture Hydrator: Atmospheric
Mineral Products Lime Manufacture Product Cooler
Mineral Products Lime Manufacture Pressure Hydrator
Mineral Products Mineral Products
Mineral Products Mineral Products
Mineral Products Mineral Products Stone Quarrying/Processing
Mineral Products Mineral Products
Mineral Products Mineral Products
Mineral Products Mineral Products
Mineral Products Asbestos Mining Overburden Stripping
Mineral Products Asbestos Mining Ventilation of Process Operations
Mineral Products Mineral Products
Mineral Products Mining and Quarrying of Nonmetallic Minerals Overburden Stripping
Mineral Products Mineral Products Mining & Quarrying of Nonmetallic Minerals
Mineral Products Mineral Products
Mineral Products Mineral Products
Mineral Products Other Not Defined Specify in Comments Field
Products
Industrial Processes Fabricated Metals: SIC 34
Fabricated Metal Products Fabricated Metal Products
Fabricated Metal Products Fugitive Emissions Other Not Classified
Fabricated Metal Products Fabricated Metal Products Other Not Classified
Equipment
Electrical Equipment Manufacturing - General Processes Cleaning
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-14
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
31306500 Electrical Equipment Semiconductor Manufacturing Integrated Circuit Manufacturing:
31306530 Electrical Equipment Semiconductor Manufacturing Etching Process: Wet Chemical: Sp
31399999 Electrical Equipment Other Not Classified Other Not Classified
Tier II: 08 Transportation Equipment
31400901
31401101 - 31499999
Tier II: 09 Construction
2311000020
Transportation Equipment Automobiles/Truck Assembly Operations Solder Joint Grindi
Transportation Equipment Transportation Equipment
Industrial Processes Construction: SIC 15 - 17 All Processes Demolition
2311000030 Industrial Processes Construction: SIC 15 - 17 All Processes Blasting
2311000080 Industrial Processes Construction: SIC 15 - 17 All Processes Welding Ope
2311010020 Industrial Processes Construction: SIC 15 - 17 General Building Construct
2311010030 Industrial Processes Construction: SIC 15 - 17 General Building Construct
2311010080 Industrial Processes Construction: SIC 15 - 17 General Building Construct
2311020020 Industrial Processes Construction: SIC 15 - 17 Heavy Construction Demoli
2311020030 Industrial Processes Construction: SIC 15 - 17 Heavy Construction Blasti
2311020080 Industrial Processes Construction: SIC 15 - 17 Heavy Construction Weldin
2311030020 Industrial Processes Construction: SIC 15 - 17 Road Construction Demolit
2311030030 Industrial Processes Construction: SIC 15 - 17 Road Construction Blastin
2311030080 Industrial Processes Construction: SIC 15 - 17 Road Construction Welding
2311040080 Industrial Processes Construction: SIC 15 - 17 Special Trade Construction
31100199 - 31100202 Building Construction Building Construction
31100299 Building Construction Demolitions/Special Trade Contracts Other Not Classified: Co
Tier II: 10 Miscellaneous Industrial Processes
2312000000 Industrial Processes Machinery: SIC 35 All Processes Total
2312050000 Industrial Processes Machinery: SIC 35 Metalworking Machinery: Tool & Die
2399000000 Industrial Processes Industrial Processes: NEC Industrial Processes: NEC
31299999 Machinery, Miscellaneous Miscellaneous Machinery Other Not Classified
31501002 Photographic Equipment Photocopying Equipment Manufacturing Toner Classification
31501003 Photographic Equipment Photocopying Equipment Manufacturing Toner (Carbon Black) G
39999989 - 39999999 Miscellaneous Manufacturing Industries Miscellaneous Manufacturing Industries
Tier I: 08 SOLVENT UTILIZATION
Tier II: 01 Degreasing
2415000000 - 2415365999 Solvent Utilization Degreasing
Organic Solvent Evaporation Degreasing
Organic Solvent Evaporation Degreasing Fugitive Emissions Specify in Comments F
40100201 - 40100399
40188801 - 40188898
Tier II: 02 Graphic Arts
2425000000 - 2425040999
40500101 - 40500601
40500801 - 40588805
Tier II: 03 Dry Cleaning
Solvent Utilization Graphic Arts
Printing/Publishing Printing Process
Printing/Publishing Printing Process
2420000000
40100101
41000102
41000201
41000202
68241030
Tier II: 04
2401001000
2440020000
40200101
40200710
40201101
40201103
40201105
40201305
40201405
40201505
40201605
40201705
40201805
40201999
40202005
40202105
- 2420020999
- 40100199
Solvent Utilization Dry Cleaning
Organic Solvent Evaporation Dry Cleaning Dry Cleaning
Dry Cleaning Petroleum Solvent - Industrial Stoddard
Dry Cleaning Petroleum Solvent - Commercial Stoddard
Dry Cleaning Petroleum Solvent - Commercial Stoddard
Miscellaneous Processes Paint Stripper Users - Non-chemical Strippers Media Blasti
Surface Coating
- 2401990999
- 40200706
- 40200998
- 40201303
- 40201403
- 40201503
- 40201603
- 40201703
- 40201803
- 40201903
- 40202003
- 40202103
- 40202203
Solvent Utilization Surface Coating
Solvent Utilization Miscellaneous Industrial Adhesive (Industrial) Applic
Surface Coating Operations Surface Coating Operations Surface Coating Applicatio
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Fabric Coating/Printing Coating Operation (Also See Spe
Surface Coating Operations Fabric Coating/Printing Coating Mixing (Also See Specif
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Surface Coating Operations
Surface Coating Operations Surface Coating Operations
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-15
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
40202205 - 40202303 Surface Coating Operations Surface Coating Operations
40202305 - 40202403 Surface Coating Operations Surface Coating Operations
40202405 - 40202503 Surface Coating Operations Surface Coating Operations
40202505 - 40202603 Surface Coating Operations Surface Coating Operations
40202605 - 40288805 Surface Coating Operations
40288822 Surface Coating Operations Fugitive Emissions Coating
40288823 Surface Coating Operations Fugitive Emissions Cleartop Coat
40288824 Surface Coating Operations Fugitive Emissions Clean-up
40299995 - 40299999 Surface Coating Operations Surface Coating Operations Surface Coating - Miscella
Tier II: 05 Other Industrial
- 2440000999
2430000000
40100401
40100499
49000101
49000202
49000206
49099998
49099999
Tier II: 06 Nonindustrial
2460000000 - 2465900000
- 49000199
- 49000599
Solvent Utilization
Organic Solvent Evaporation Knit Fabric Scouring with Chlorinated Solvent Perchlor
Organic Solvent Evaporation Knit Fabric Scouring with Chlorinated Solvent Other No
Organic Solvent Evaporation Miscellaneous Solvent Extraction Processes
Organic Solvent Evaporation Waste Solvent Recovery Operations Condenser Vent
Organic Solvent Evaporation Miscellaneous
Organic Solvent Evaporation Miscellaneous Volatile Organic Compound Evaporation Id
Organic Solvent Evaporation Miscellaneous Volatile Organic Compound Evaporation Id
Solvent Utilization
Tier II: 07 Solvent Utilization NEC
2495000000 - 2495000999 Solvent Utilization All Solvent User Categories All Processes
Tier I: 09 STORAGE & TRANSPORT
Tier II: 01 Bulk Terminals & Plants
2501050000 - 2501050900 Storage & Transport Petroleum & Petroleum Product Storage Bulk Stations/Terminal
40400101 - 40400271 Bulk Terminals/Plants Petroleum Storage Tanks
40400272 Bulk Terminals/Plants Bulk Plants Gasoline RVP 10: Standing Loss - Int. Floating R
40400278 Bulk Terminals/Plants Bulk Plants Gasoline RVP 10/13/7: Withdrawal Loss - Int. Flo
40400279 Bulk Terminals/Plants Bulk Plants Specify Liquid: Internal Floating Roof (Primary/
40400401 - 40400498 Bulk Terminals/Plants Petroleum Storage Tanks Underground Tanks
Tier II: 02 Petroleum & Petroleum Product Storage
- 2275900102
- 2501010900
- 2501995180
40399999
40400305
Mobile Sources Aircraft Refueling: All Fuels
Mobile Sources Aircraft Refueling: All Fuels Underground Tank: Total
Storage & Transport Petroleum & Petroleum Product Storage
Storage & Transport Petroleum & Petroleum Product Storage Gasoline Servic
Storage & Transport Petroleum & Petroleum Product Storage Gasoline Servic
Storage & Transport Petroleum & Petroleum Product Storage Diesel Service
Storage & Transport Petroleum & Petroleum Product Storage Diesel Service
Storage & Transport Petroleum & Petroleum Product Storage All Storage Types: Wor
Oil and Gas Production Crude Oil Production Crude Oil Sumps
Oil and Gas Production Crude Oil Production Crude Oil Pits
Oil and Gas Production Crude Oil Production Evaporation from Liquid Leaks into Oil
Oil and Gas Production Crude Oil Production Atmospheric Wash Tank (2nd Stage of Ga
Petroleum Product Storage (Refineries Oil and Gas Fie
Bulk Terminals/Plants Petroleum Storage Tanks Oil Field Storage of Crude Oil
Bulk Terminals/Plants Oil Field Storage of Crude External Floating Roof Tank: With
Bulk Terminals/Plants Oil Field Storage of Crude Internal Floating Roof Tank: With
Petroleum & Petroleum Product Transport
- 2505040180 Storage & Transport Petroleum & Petroleum Product Transport
- 40600299 Transportation and Marketing of Petroleum Products
- 40688805 Transportation and Marketing of Petroleum Products Fugitive Emissions Specify in
Tier II: 04 Service Stations: Stage I
2501060050 - 2501060053 Storage & Transport Petroleum & Petroleum Product Storage Gasoline Service Stati
2501070050 - 2501070053 Storage & Transport Petroleum & Petroleum Product Storage Diesel Service Station
40600301 - 40600399 Transportation and Marketing of Petroleum Products Gasoline Retail Operations St
40600503 Transportation and Marketing of Petroleum Products Pipeline Petroleum Transport -
40600706 Transportation and Marketing of Petroleum Products Consumer (Corporate) Fleet Refu
Tier II: 05 Service Stations: Stage II
2501060100 - 2501060103 Storage & Transport Petroleum & Petroleum Product Storage Gasoline Service Stati
2501070100 - 2501070103 Storage & Transport Petroleum & Petroleum Product Storage Diesel Service Station
40600401 - 40600499 Transportation and Marketing of Petroleum Products Filling Vehicle Gas Tanks Sta
40600501 Transportation and Marketing of Petroleum Products Pipeline Petroleum Transport -
40600601 Transportation and Marketing of Petroleum Products Consumer (Corporate) Fleet Refu
2275900000
2275900201
2501000000
2501060000
2501060200
2501070000
2501070200
2501995000
31000104
31000105
31000108
31000132
40300101
40400301
40400306
40400307
Tier II: 03
2505000000
40600101
40688801
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-16
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
Tier II: 06 Service Stations: Breathing & Emptying
2275900202 Mobile Sources Aircraft Refueling: All Fuels Underground Tank: Breathing
2501060201 Storage & Transport Petroleum & Petroleum Product Storage Gasoline Servic
2501070201 Storage & Transport Petroleum & Petroleum Product Storage Diesel Service
42500101 Fixed Roof Tanks (210 Bbl Size) Breathing Loss
42500102 Fixed Roof Tanks (210 Bbl Size) Working Loss
Tier II: 07 Organic Chemical Storage
2510000000 -2510995405 Storage & Transport Organic Chemical Storage
30100102 Chemical Manufacturing Adipic Acid Raw Material Storage
30100106 Chemical Manufacturing Adipic Acid Drying, Loading, and Storage
30100508 Chemical Manufacturing Carbon Black Production Bagging/Loading
30101404 Chemical Manufacturing Paint Manufacture Raw Material Storage
30101602 Chemical Manufacturing Phosphoric Acid: Wet Process Gypsum Pond
30101808 Chemical Manufacturing Plastics Production Monomer and Solvent Storage
30101810 Chemical Manufacturing Plastics Production Conveying
30101811 Chemical Manufacturing Plastics Production Storage
30101815 Chemical Manufacturing Plastics Production Pellet Silo
30101816 Chemical Manufacturing Plastics Production Transferring/Handling/Loading/Packing
30101821 Chemical Manufacturing Plastics Production Extruding/Pelletizing/Conveying/Storage
30101840 Chemical Manufacturing Plastics Production Resin Storage Tank ** (Use 6-45-200-23
30101864 Chemical Manufacturing Plastics Production Pellet Silo/Storage
30101865 Chemical Manufacturing Plastics Production Transferring/Conveying
30101883 Chemical Manufacturing Plastics Production Transferring/Conveying/Storage (Polyure
30101893 Chemical Manufacturing Plastics Production Raw Material Storage
30101894 Chemical Manufacturing Plastics Production Solvent Storage
30102425 Chemical Manufacturing Synthetic Organic Fiber Manufacturing Fiber Storage (Use 6-
30102427 Chemical Manufacturing Synthetic Organic Fiber Manufacturing Solvent Storage (Use
30102612 Chemical Manufacturing Synthetic Rubber (Manufacturing Only) Pre-storage Tank
30102709 Chemical Manufacturing Ammonium Nitrate Production Bulk Loading (General)
30103003 Chemical Manufacturing Ammonium Phosphates Screening/Transfer
30103105 Chemical Manufacturing Terephthalic Acid/Dimethyl Terephthalate Product Transfer V
30104007 Chemical Manufacturing Urea Production Bulk Loading
30106010 Chemical Manufacturing Pharmaceutical Preparations Storage/Transfer
30130108 Chemical Manufacturing Chlorobenzene DCB Crystal Handling/Loading
30183001 Chemical Manufacturing General Processes Storage/Transfer
30201920 Food and Agriculture Vegetable Oil Processing Solvent Storage (Use 4-07-016-15 & -
30800109 Rubber and Miscellaneous Plastics Products Tire Manufacture Solvent Storage ** (Us
30800110 Rubber and Miscellaneous Plastics Products Tire Manufacture Solvent Storage (Use 4
30800803 Rubber and Miscellaneous Plastics Products Plastic Foam Products Bead Storage
31501001 Photographic Equipment Photocopying Equipment Manufacturing Resin Transfer/Storage
40200707 Surface Coating Operations Surface Coating Application - General Adhesive: Solvent
40201104 Surface Coating Operations Fabric Coating/Printing Coating Storage (Also See Speci
40201304 Surface Coating Operations Paper Coating Coating Storage
40201404 Surface Coating Operations Large Appliances Coating Storage
40201504 Surface Coating Operations Magnet Wire Surface Coating Coating Storage
40201604 Surface Coating Operations Automobiles and Light Trucks Coating Storage
40201704 Surface Coating Operations Metal Can Coating Coating Storage
40201804 Surface Coating Operations Metal Coil Coating Solvent Storage (Use 4-07-004-01 thr
40201904 Surface Coating Operations Wood Furniture Surface Coating Coating Storage
40202004 Surface Coating Operations Metal Furniture Operations Coating Storage
40202104 Surface Coating Operations Flatwood Products Coating Storage
40202204 Surface Coating Operations Plastic Parts Coating Storage
40202304 Surface Coating Operations Large Ships Coating Storage
40202404 Surface Coating Operations Large Aircraft Coating Storage
40202504 Surface Coating Operations Miscellaneous Metal Parts Coating Storage
40202604 Surface Coating Operations Steel Drums Coating Storage
40500701 Printing/Publishing General Solvent Storage
40700401 - 40799998 Organic Chemical Storage
42500201 Fixed Roof Tanks (500 Bbl Size) Breathing Loss
49000201 Organic Solvent Evaporation Waste Solvent Recovery Operations Storage Tank Vent
49000204 Organic Solvent Evaporation Waste Solvent Recovery Operations Solvent Spillage
49000205 Organic Solvent Evaporation Waste Solvent Recovery Operations Solvent Loading
Tier II: 08 Organic Chemical Transport
2515000000 - 2515040405 Storage & Transport Organic Chemical Transport
30101866 Chemical Manufacturing Plastics Production Packing/Shipping
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-17
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30101884 Chemical Manufacturing Plastics Production Packing/Shipping (Polyurethane)
40899995 - 40899999 Organic Chemical Transportation Organic Chemical Transportation Specify Liquid
Tier II: 09 Inorganic Chemical Storage
2520000000 - 2520995040 Storage & Transport Inorganic Chemical Storage
30100804 Chemical Manufacturing Chloro-alkali Production Chlorine Loading: Storage Car Ven
30101198 Chemical Manufacturing Hydrochloric Acid Handling and Storage (99.9% Removal)
30101204 Chemical Manufacturing Hydroflouric Acid Fluorspar Handling Silos
30101205 Chemical Manufacturing Hydroflouric Acid Fluorspar Transfer
30102321 Chemical Manufacturing Sulfuric Acid (Contact Process) Storage Tank Vent
30102803 - 30102805 Chemical Manufacturing Chemical Manufacturing Normal Superphosphate
30102821 Chemical Manufacturing Normal Superphosphates Den
30102903 - 30102905 Chemical Manufacturing Chemical Manufacturing Triple Superphosphate
30102921 Chemical Manufacturing Triple Superphosphate Den
30103554 Chemical Manufacturing Inorganic Pigments Conveying/Storage/Packing
30104204 Chemical Manufacturing Lead Alkyl Manufacturing (Sodium/Lead Alloy Process) Sludge
30107002 Chemical Manufacturing Inorganic Chemical Manufacturing (General) Storage/Transfer
30121010 Chemical Manufacturing Caprolactum (Use 3-01-130 for Ammonium Sulfate By-product P
30187001 -30188599 Chemical Manufacturing Inorganic Chemical Storage
Tier II: 10 Inorganic Chemical Transport
2525000000 - 2525040040 Storage & Transport Inorganic Chemical Transport
30100803 Chemical Manufacturing Chloro-alkali Production Chlorine Loading: Tank Car Vent
30102320 Chemical Manufacturing Sulfuric Acid (Contact Process) Tank Car and Truck Unloadin
Tier II: 11 Bulk Materials Storage
2530000000 -2530050120 Storage & Transport Bulk Materials Storage
2650000004 Waste Disposal, Treatment, & Recovery Scrap & Waste Materials Scrap & Was
30200505 - 30200511 Food and Agriculture Food and Agriculture Feed and Grain Terminal Elevators
30200605 - 30200610 Food and Agriculture Food and Agriculture Feed and Grain Country Elevators
30200751 Food and Agriculture Grain Millings Wet Corn Milling: Grain Receiving
30200755 Food and Agriculture Grain Millings Wet Corn Milling: Bulk Loading
30200771 Food and Agriculture Grain Millings Rice: Grain Receiving
30200781 Food and Agriculture Grain Millings Soybean: Grain Receiving
30200791 Food and Agriculture Grain Millings Soybean: Bulk Loading
30200802 Food and Agriculture Feed Manufacture Grain Receiving
30200803 Food and Agriculture Feed Manufacture Shipping
30203105 - 30203111 Food and Agriculture Food and Agriculture Export Grain Elevators
30300003 Primary Metal Production Aluminum Ore (Bauxite) Fine Ore Storage
30300305 Primary Metal Production By-product Coke Manufacturing Coal Unloading
30300309 Primary Metal Production By-product Coke Manufacturing Coal Conveying
30300316 Primary Metal Production By-product Coke Manufacturing Coal Storage Pile
30300613 Primary Metal Production Ferroalloy, Open Furnace Raw Material Storage
30300614 Primary Metal Production Ferroalloy, Open Furnace Raw Material Transfer
30300804 Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
30300805 Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
30300809 - 30300812 Primary Metal Production Iron Production
30300820 - 30300823 Primary Metal Production Iron Production
30300827 Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
30300841 Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
30300842 Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
30300915 Primary Metal Production Steel Manufacturing (See 3-03-015 for Integrated Iron & S
30301011 - 30301013 Primary Metal Production Primary Metal Production Lead Production
30301016 Primary Metal Production Lead Production Sinter Transfer
30301026 Primary Metal Production Lead Production Sinter Dump Area
30302304 Primary Metal Production Taconite Iron Ore Processing Ore Transfer
30302305 Primary Metal Production Taconite Iron Ore Processing Ore Storage
30302307 Primary Metal Production Taconite Iron Ore Processing Bentonite Storage
30302309 Primary Metal Production Taconite Iron Ore Processing Traveling Grate Feed
30302310 Primary Metal Production Taconite Iron Ore Processing Traveling Grate Discharge
30302316 Primary Metal Production Taconite Iron Ore Processing Pellet Transfer
30303009 Primary Metal Production Zinc Production Raw Material Handling and Transfer
30303012 Primary Metal Production Zinc Production Raw Material Unloading
30400356 Secondary Metal Production Grey Iron Foundries Sand Silo
30400357 Secondary Metal Production Grey Iron Foundries Conveyors/Elevators
30400721 Secondary Metal Production Steel Foundries Sand Silo
30400723 Secondary Metal Production Steel Foundries Conveyors/Elevators
30500203 Mineral Products Asphalt Concrete Storage Piles
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-18
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30500303
30500406
30500607
30500608
30500612
30500615
30500616
30500618
30500619
30500707
30500708
30500712
30500715
30500716
30500718
30500719
30500803
30500905
30500906
30500910
30501008
30501009
30501011
30501014
30501021
30501023
30501030
30501032
30501033
30501036
30501040
30501048
30501106
30501114
30501115
30501221
30501222
30501504
30501508
30501514
30501518
30501607
30501608
30501610
30501613
30501903
30501904
30502007
30502106
30502502
30502503
30502505
30503104
30503110
30503111
30504020
30504025
30504036
30510001
30510604
30703001
30703002
Tier II: 12
2535000000
30200711
Mineral Products Brick Manufacture Storage of Raw Materials
Mineral Products Calcium Carbide Circular Charging: Conveyor
Mineral Products Cement Manufacturing (Dry Process) Raw Material Unloading
Mineral Products Cement Manufacturing (Dry Process) Raw Material Piles
Mineral Products Cement Manufacturing (Dry Process) Raw Material Transfer
Mineral Products Cement Manufacturing (Dry Process) Clinker Piles
Mineral Products Cement Manufacturing (Dry Process) Clinker Transfer
Mineral Products Cement Manufacturing (Dry Process) Cement Silos
Mineral Products Cement Manufacturing (Dry Process) Cement Load Out
Mineral Products Cement Manufacturing (Wet Process) Raw Material Unloading
Mineral Products Cement Manufacturing (Wet Process) Raw Material Piles
Mineral Products Cement Manufacturing (Wet Process) Raw Material Transfer
Mineral Products Cement Manufacturing (Wet Process) Clinker Piles
Mineral Products Cement Manufacturing (Wet Process) Clinker Transfer
Mineral Products Cement Manufacturing (Wet Process) Cement Silos
Mineral Products Cement Manufacturing (Wet Process) Cement Load Out
Mineral Products Ceramic Clay/Tile Manufacture Raw Material Storage
Mineral Products Clay and Fly Ash Sintering Raw Clay/Shale Transfer/Conveying
Mineral Products Clay and Fly Ash Sintering Raw Clay/Shale Storage Piles
Mineral Products Clay and Fly Ash Sintering Expanded Shale Storage
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Unloadi
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Raw Coa
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Coal Tr
Mineral Products Coal Cleaning Material Handling
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Overbur
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Loading
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Topsoil
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Topsoil
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Overbur
Mineral Produc
Mineral Produc
Mineral Produc
Mineral Produc
Mineral Produc
Mineral Produc
Mineral Produc
s Mineral Products Surface Mining Operations
s Mineral Products Surface Mining Operations
ts Coal Mining, Cleaning, and Material Handling (See 305310) Overbur
s Mineral Products Concrete Batching
s Concrete Batching Transferring: Conveyors/Elevators
s Concrete Batching Storage: Bins/Hoppers
s Fiberglass Manufacturing Raw Material: Unloading/Conveying
- 30501016
- 30501038
- 30501043
- 30501111
Mineral Products Fiberglass Manufacturing Raw Material: Storage Bins
Mineral Products Gypsum Manufacture Conveying
- 30501510 Mineral Products Mineral Products Gypsum Manufacture
Mineral Products Gypsum Manufacture Storage Bins: Stucco
Mineral Products Gypsum Manufacture Mixers/Conveyors
Mineral Products Lime Manufacture Raw Material Transfer and Conveying
Mineral Products Lime Manufacture Raw Material Unloading
Mineral Products Lime Manufacture Raw Material Storage Piles
- 30501615 Mineral Products Mineral Products Lime Manufacture
Mineral Products Phosphate Rock Transfer/Storage
Mineral Products Phosphate Rock Open Storage
Mineral Products Stone Quarrying - Processing (See also 305320) Open Storage
Mineral Products Salt Mining Conveying
Mineral Products Construction Sand and Gravel Aggregate Storage
Mineral Products Construction Sand and Gravel Material Transfer and Conveying
- 30502507 Mineral Products Mineral Products Sand/Gravel
- 30503107 Mineral Products Mineral Products Asbestos Mining
Mineral Products Asbestos Mining Stockpiling
Mineral Products Asbestos Mining Tailing Piles
- 30504023 Mineral Products Mineral Products Mining & Quarrying of Nonmetallic Minerals
Mineral Products Mining and Quarrying of Nonmetallic Minerals Stockpiling
Mineral Products Mining and Quarrying of Nonmetallic Minerals Tailing Piles
- 30510599 Mineral Products Mineral Products
Mineral Products Bulk Materials Screening/Size Classification Coke
Pulp and Paper and Wood Products Miscellaneous Wood Working Operations Wood Waste
Pulp and Paper and Wood Products Miscellaneous Wood Working Operations Wood Waste
Bulk Materials Transport
- 2535030140 Storage & Transport Bulk Materials Transport
Food and Agriculture Grain Millings Durum Milling: Grain Receiving
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-19
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30200721
30200731
30200741
30501044
31100203
31100204
Food and Agriculture Grain Millings Rye: Grain Receiving
Food and Agriculture Grain Millings Wheat: Grain Receiving
Food and Agriculture Grain Millings Dry Corn Milling: Grain Receiving
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Train L
Building Construction Demolitions/Special Trade Contracts Debris Loading
Building Construction Demolitions/Special Trade Contracts Debris Loading
Tier I: 10 WASTE DISPOSAL & RECYCLING
Tier II: 01 Incineration
2601000000 - 2601030000
30101015
30101023
31307001
31307002
31401001
31401002
49000203
50100101 - 50100103
50100104
50100105
50100505 - 50100517
50200101 - 50200105
50200205
50200301 - 50200507
50300101 - 50300109
50300501
50300503
50300505
50300506
Tier II: 02 Open Burning
2610000000
50100201
50100202
50200201
50200202
50300201
- 2610030000
- 50300205
Tier II: 03 POTW
2630000000
2630020000
50100701
50100793
- 50100704
Waste Disposal, Treatment, & Recovery On-Site Incineration
Chemical Manufacturing Explosives (Trinitrotoluene) Batch Process: Red Water Incin
Chemical Manufacturing Explosives (Trinitrotoluene) Continuous Process: Red Water
Electrical Equipment Electrical Windings Reclamation Single Chamber Incinerater/Ov
Electrical Equipment Electrical Windings Reclamation Multiple Chamber Incinerator/
Transportation Equipment Brake Shoe Debonding Single Chamber Incinerator
Transportation Equipment Brake Shoe Debonding Multiple Chamber Incinerator
Organic Solvent Evaporation Waste Solvent Recovery Operations Incinerator Stack
Solid Waste Disposal Government Municipal Incineration
Solid Waste Disposal - Government Municipal Incineration Mass Burn Refractory Wall
Solid Waste Disposal - Government Municipal Incineration Mass Burn Waterwall Combu
Solid Waste Disposal Government Other Incineration
Solid Waste Disposal Commercial/Institutional Incineration: General
Solid Waste Disposal - Commercial/Institutional Open Burning Weeds
Solid Waste Disposal Commercial/Institutional
Solid Waste Disposal Industrial Incineration
Solid Waste Disposal - Industrial Incineration Hazardous Waste
Solid Waste Disposal - Industrial Incineration Hazardous Waste Incinerators: Liqu
Solid Waste Disposal - Industrial Incineration Hazardous Waste Incinerators: Mult
Solid Waste Disposal - Industrial Incineration Sludge
Waste Disposal, Treatment, & Recovery Open Burning
Solid Waste Disposal - Government Open Burning Dump General Refuse
Solid Waste Disposal - Government Open Burning Dump Vegetation Only
Solid Waste Disposal - Commercial/Institutional Open Burning Wood
Solid Waste Disposal - Commercial/Institutional Open Burning Refuse
Solid Waste Disposal Industrial Open Burning
Waste Disposal, Treatment, & Recovery Wastewater Treatment All Categories
Waste Disposal, Treatment, & Recovery Wastewater Treatment Public Owned
Solid Waste Disposal Government Sewage Treatment
Solid Waste Disposal - Government Sewage Treatment POTW: Sludge Drying Bed
Tier II: 04 Industrial Waste Water
2630010000
30182001 - 30182003
31000506
50300702
68182599
68282599
Tier II: 05 TSDF
2640000000 - 2640020004
50300801 - 50300899
Tier II: 06 Landfills
2620000000 - 2620030000
50100401
50100410
50200601
50200602
50300601 - 50300603
Tier II: 07 Other
2630030000
2650000000 - 2650000003
2660000000
50100402
50100601 - 50100604
Waste Disposal, Treatment, & Recovery Wastewater Treatment Industrial To
Chemical Manufacturing Chemical Manufacturing General Processes
Oil and Gas Production Liquid Waste Treatment Oil-Water Separation Wastewater Hold
Solid Waste Disposal - Industrial Liquid Waste Waste Treatment: General
Consumer Product Manufacturing Facilities Wastewater, Points of Generation Specify
Miscellaneous Processes Wastewater, Points of Generation Specify Point of Generati
Waste Disposal, Treatment, & Recovery TSDFs
Solid Waste Disposal Industrial Treatment, Storage, Disposal Facilities
Waste Disposal, Treatment, & Recovery Landfills
Solid Waste Disposal - Government Landfill Dump Unpaved Road Traffic
Solid Waste Disposal - Government Landfill Dump Waste Gas Destruction: Waste Gas
Solid Waste Disposal - Commercial/Institutional Landfill Dump Waste Gas Flares **
Solid Waste Disposal - Commercial/Institutional Landfill Dump Municipal: Fugitive
Solid Waste Disposal Industrial Landfill Dump
Waste Disposal, Treatment, & Recovery Wastewater Treatment Residential/Su
Waste Disposal, Treatment, & Recovery Scrap & Waste Materials Scrap & Waste
Waste Disposal, Treatment, & Recovery Leaking Underground Storage Tanks L
Solid Waste Disposal - Government Landfill Dump Fugitive Emissions
Solid Waste Disposal Government Fire Fighting
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-20
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
50200901 Solid Waste Disposal - Commercial/Institutional Asbestos Removal General
50282599 Solid Waste Disposal - Commercial/Institutional Wastewater, Points of Generation S
50300701 Solid Waste Disposal - Industrial Liquid Waste General
50300901 Solid Waste Disposal - Industrial Asbestos Removal General
50390002 Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Coal
50400101 Site Remediation General Processes Fixed Roof Tanks: Breathing Loss
50400102 Site Remediation General Processes Fixed Roof Tanks: Working Loss
50400103 Site Remediation General Processes Float Roof Tanks: Standing Loss
50400104 Site Remediation General Processes Float Roof Tanks: Withdrawal Loss
50400150 Site Remediation General Processes Storage Bins
50400151 Site Remediation General Processes: Liquid Waste: General: Transfer
50400301 Site Remediation General Processes Open Refuse Stockpiles : General
50400320 Site Remediation General Processes Storage Bins - Solid Waste
50410310 Site Remediation In Situ Venting/Venting of Soils Active Aeration
50410311 Site Remediation In Situ Venting/Venting of Soils Active Aeration: Vacuum
50410312 Site Remediation In Situ Venting/Venting of Soils Active Aeration, Vacuum: Vapor
50410313 Site Remediation In Situ Venting/Venting of Soils Active Aeration, Vacuum: Vacuum
50410405 Site Remediation Air Stripping of Groundwater Oil/Water Separator
50410408 Site Remediation Air Stripping of Groundwater Treatment Tanks
50410420 Site Remediation Air Stripping of Groundwater Air Stripping Tower
50410530 Site Remediation Thermal Destruction Combustion Unit
50410562 Site Remediation Thermal Destruction Waste Disposal: Chemical Stabilization
50410610 Site Remediation Thermal Desorption Pretreatment
50410622 Site Remediation Thermal Desorption Thermal Desorber: Kiln
50410645 Site Remediation Thermal Desorption Wastes: Containers
50490004 Site Remediation General Processes Incinerators: Process Gas
Tier I: 11 ON-ROAD VEHICLES
Tier II: 01 Light-Duty Gas Vehicles & Motorcycles
2201001000 - 2201001334 Mobile Sources On-road Vehicles - Gasoline Light Duty Gasoline Vehicles (LDGV)
2201080000 - 2201080334 Mobile Sources On-road Vehicles - Gasoline Motorcycles (MC)
Tier II: 02 Light-Duty Gas Trucks
2201020000 - 2201060334 Mobile Sources On-road Vehicles - Gasoline
Tier II: 03 Heavy-Duty Gas Vehicles
2201070000 - 2201070334 Mobile Sources On-road Vehicles - Gasoline (HDGV)
Tier II: 04 Diesels
2230001000 - 2230070334 Mobile Sources On-road Vehicles - Diesel
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-21 Introduction
-------
Table 4.1-3 (continued)
Tier I: 12 NON-ROAD SOURCES
Tier II: 01 Non-Road Gasoline
2260000000 - 2265008010 Mobile Sources
2282005000 - 2282020025 Mobile Sources Marine Vessels, Recreational
26000320 Non-road Sources 2-stroke Gasoline Engines Industrial Equipment Industrial Fork Lift: G
Tier II: 02 Non-Road Diesel
2270000000 - 2270008010 Mobile Sources Non-road Sources Vehicle Diesel
Tier II: 03 Aircraft
2275000000 - 2275070000 Mobile Sources Aircraft
Tier II: 04 Marine Vessels
2280001000 -2280004040 Mobile Sources Marine Vessels, Commercial
2283000000 - 2283004020 Mobile Sources Marine Vessels, Military
Tier II: 05 Railroads
2285002000 - 2285002010 Mobile Sources Railroads Diesel
Tier I: 13 NATURAL SOURCES
Tier II: 01 Biogenic
2701000000 - 2701480000 Natural Sources Biogenic
2740020000 -2740040010 Natural Sources Miscellaneous
Tier II: 02 Geogenic
2730001000 - 2730100001 Natural Sources Geogenic
Tier II: 03 Miscellaneous
2740001000 Natural Sources Miscellaneous Lighting Total
Tier I: 14 MISCELLANEOUS
Tier II: 01 Agriculture & Forestry
2307010000 Industrial Processes Wood Products: SIC 24 Logging Operations Total
2801000001 - 2801000008 Miscellaneous Area Sources Agriculture Production - Crops Agriculture - Crops
2805000000 - 2805015001 Miscellaneous Area Sources Agriculture Production - Livestock
Tier II: 02 Other Combustion
2801500000 Miscellaneous Area Sources Agriculture Production - Crops Agricultural Fi
2801520000 Miscellaneous Area Sources Agriculture Production - Crops Orchard Heaters
2810001000 - 2810050000 Miscellaneous Area Sources Other Combustion
30101030 Chemical Manufacturing Explosives (Trinitrotoluene) Open Burning: Waste
Tier II: 03 Catastrophic/Accidental Releases
2275900103 Mobile Sources Aircraft Refueling: All Fuels Spillage
2830000000 - 2830010000 Miscellaneous Area Sources Catastrophic/Accidential Releases
Tier II: 04 Repair Shops
2840000000 - 2841010050 Miscellaneous Area Sources
Tier II: 05 Health Services
2850000000 - 2850000030 Miscellaneous Area Sources Health Services Hospitals
31502001 - 31502089 Health Services Health Services Hospitals
Tier II: 06 Cooling Towers
2820000000 - 2820020000 Miscellaneous Area Sources Cooling Towers
38500101 - 38500210 Cooling Tower Cooling Tower
Tier II: 07 Fugitive Dust
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-22 Introduction
-------
4.2 FUEL COMBUSTION - ELECTRIC UTILITY
The point and area source categories under the "Electric Utility" heading include the following Tier I
and Tier II categories:
Tier I Category Tier II Category
(01) FUEL COMBUSTION - ELECTRIC UTILITY (01) Coal
(02) Oil
(03) Gas
The emissions from the combustion of fuel by electric utilities have been divided into two
classifications: (1) steam generated fossil-fuel units (boiler) and (2) nonsteam generated fossil-fuel units
such as gas turbines (GT) and internal combustion (1C) engines. Two very different methodologies have
been used to estimate the emissions for these two classes; each is described separately in this report. The
fossil-fuel steam generated methodology is described in this section; the GT and 1C methodology is
described in section 4.3.
The emissions from fossil-fuel steam electric utility units for the years 1985 through 1995 have been
based on five basic factors: (1) fuel consumption, (2) emission factor, which relates the quantity of fuel
consumed to the quantity of pollutant emitted, (3) fuel characteristics, such as sulfur content, ash content,
and heating value of fuels, (4) control efficiency, which indicates the percent of pollutant emissions not
removed through control methods, and (5) rule effectiveness (which, according to EPA, is the measure of
the ability of a regulatory program to achieve all the emissions reductions that could be achieved by full
compliance with the applicable regulations at all sources at all times). The fuel consumption
characteristics and control efficiencies are obtained at the boiler-level, while the emission factors are
specified at the SCC-level. The 1996 emissions and heat input are extrapolated from the 1995 boiler-
level emissions based on the ratio of plant-level 1996 fuel consumption to 1995 fuel consumption.
The fossil-fuel steam electric utility emissions that are reported in the Trends Data Bases include
VOC, NOX, CO, SO2, PM-10, and PM-2.5. Since there are no known utility emission factors for either
NH3 or sulfates (SO4), they are not estimated. It should also be noted that these estimates do not include
emissions from the combustion of anthracite coal because it accounts for a very small percentage
(< 1 percent) of the overall emissions from fuel combustion by fossil-fuel steam electric utility units.
4.2.1 1985-1995 Steam Electric Utility Emission Inventories
The Energy Information Administration (EIA) of the Department of Energy (DOE) collects monthly
boiler-level data on a yearly basis using Form EIA-767 (Steam-Electric Plant Operation and Design
Report^}. The EIA also collects plant-level fossil-fuel steam data from all electric utility plants filing
Form EIA-759 (Monthly Power Plant Report2}. Currently, Form EIA-767 data are available for the years
1985 through 1995, while Form EIA-759 data are available through the year 1996. The fossil-fuel steam
electric utility component of the Trends emission inventories for 1985 through 1996 includes data derived
from these two forms. These steam components include data from fossil-fuel steam boilers and not data
from GT or 1C engines (which account for a very small share of electric utility fuel use and corresponding
emissions) unless they report it to EIA.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-23 Electric Utilities
-------
The steam emission inventory data for 1985 through 1995 are initially based on the aggregated
monthly electric utility steam boiler-level data from Form EIA-767. All plants of at least 10 megawatts
(MW) that have at least one operating boiler are required to provide this information to EIA, although
the amount of data required from plants with less than 100 MW of steam-electric generating capacity is
not as extensive as the amount required by those plants of at least 100 MW. For plants with a nameplate
rating from 10 MW to less than 100 MW, only selected pages of the Form EIA-767, with ID, boiler fuel
quantity and quality, and flue gas desulfurization (FGD) information, must be completed. Other sources
of data for NOX, SO2 and heat input are used in place of the EIA/AP-42 calculated data when the data are
known to be better; the sources are summarized in Table 4.2-1.
NOX and SO2 emissions as well as heat input are also available for affected acid rain utility boilers
beginning in 1995 (the data are also available for Phase 1 units for 1994) from the Emissions Tracking
System/Continuous Emissions Monitoring (ETS/CEM).3 These data are also included in the 1994
through 1996 Trends fossil-fuel steam electric utility components.
4.2.1.1 Processing Computerized Raw Data
The basis for the fossil-fuel-fired steam electric utility component of the Emission Trends inventory
is the reported primary utility data collected by EIA. The data from these EIA forms are transferred to
data tapes that are not initially serviceable to the public. E.H. Pechan & Associates, Inc. (Pechan) has
developed customized computer code to process these data and to account for the various characteristics
of the data tapes.
4.2.1.1.1 Form EIA-767 —
Form EIA-767 data are reported by the operating utility for each plant with fossil-fuel steam boilers
of 10 MW or greater. The written form is designed so that information for each plant is reported on
separate pages that relate to different levels of data. The relevant data levels are as follows:
• Plant-level: One page for delineating the plant configuration, which establishes the number of
boilers and the IDs for each boiler, as well as the associated generator(s), FGD unit(s) (SO2
scrubbers), flue gas particulate collectors, flue(s) and stack(s). These do not necessarily have a
one-to-one correspondence.
• Boiler-level: One page per boiler for monthly fuel consumption and quality data (for coal, oil,
gas, and other), one page for regulatory data, and one page for design parameters.
• Generator-level: One page for generation and capacity data relating to up to five generators.
• FGD-level: One page for up to five FGD units for annual operating data and one page for each
FGD unit for design parameter data.
• Flue gas particulate collector-level: One page each for (up to five) collectors with annual
operating data and design specifications.
• Flue- and stack-level: One page per flue-stack for design parameter data.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-24 Electric Utilities
-------
Processing Form EIA-767 is accomplished in a series of steps aimed at converting the computerized
data into data base form. Each "page" format is reproduced on the computer file exactly as it appears on
the written page of the form. The data from each "page" must be extracted from the computer file,
associated with the correct boiler, and combined with all corresponding data from the other pages for that
boiler.
For example, fuel-related boiler data — monthly values for each fuel burned, along with the fuel's
associated sulfur, ash, and heat content — are reported on page six. However, only coal, oil, and gas
data are processed. These data must be aggregated for each fuel in order to produce annual estimates for
each boiler before they are combined with the other data (such as control devices and efficiencies, plant
location data, associated generator generation, and associated stack parameters).
After SCCs are assigned to each boiler's (possible three) reported fuels in a given plant, the SCC-
specific data are then separated so that each data base record is on the plant-boiler-SCC level.
4.2.1.1.2 Form EIA-759 —
Form EIA-759 data are also processed in a series of steps, using a less intricate method, since the
data for each plant are not reported at the boiler level, but instead are reported by prime mover (e.g.,
steam, hydro, 1C, GT, combined cycle) and fuel type.
For each plant-prime mover combination (in this case, for the steam prime mover), plant ID data, as
well as monthly fuel-specific generation and consumption data, are reported. The monthly plant steam
prime mover data are aggregated to annual estimates for each fuel (that has been categorized as coal,
residual oil, distillate oil, natural gas, or other) and combined to produce a single annual steam plant-level
data observation. (Beginning in 1996, only annual, not monthly data, are collected for small plants, so
the intermediate aggregation of monthly data is unnecessary.)
Since no actual 1996 data are presently available, these Form EIA-759 data were used to "grow" the
1995 fuel and emissions data for 1996, as described later in Section 4.2.2.
4.2.1.2 Emissions Algorithms
Data that were not obtained directly from the computerized data files (or converted to other
measurement units) were developed by Pechan using algorithms that have been utilized since the 1980s.
These variables include boiler capacity, SCC, heat input, pollutant emissions, and NOX control efficiency.
Although generator nameplate capacity is reported on Form EIA-767, when there is not a one-to-
one correspondence between boiler and generator (a multiheader situation — for example, if one boiler is
associated with two or more generators or if several boilers are reciprocally associated with several
generators), this information in its present form cannot be used to represent the boiler size. Thus, a boiler
design capacity variable (in MMBtu/hr) has been developed based on the reported maximum continuous
steam flow at 100 percent load (in thousand pounds per hour) by multiplying the steam flow value by a
units conversion of 1.25 to obtain boiler capacity,.
Emission factors from AP-424 were used in calculating emissions. The emission factor used depends
upon the SCC and pollutant, as explained below.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-25 Electric Utilities
-------
• The appropriate SCC is assigned to each source based on its fuel and boiler characteristics. For
sources using coal, the SCC is based on the American Society for Testing and Materials
(ASTM) criteria for moisture, mineral-free matter basis (if greater than 11,500 Btu/lb, coal type
is designated to be bituminous; if between 8,300 and 11,500 Btu/lb, coal type is designated to
be subbituminous; and if less than 8,300 Btu/lb, coal type is designated to be lignite) and the
boiler type (firing configuration and bottom type) as specified by AP-42. If both coal and oil
were burned in the same boiler, it is assumed that the oil is distillate; otherwise, it is assumed to
be residual. Based on the fuel and boiler type, the SCC is assigned. See Table 4.2-2 for a
complete list of the relationships among fuel type, firing type, bottom type, and SCC.
Since the control efficiencies for NOX, PM-10, and PM-2.5 were not available from the EIA-767
form, control efficiencies were derived using the following methods:
• NOX control efficiency is based on the assumption that the unit would be controlled so that its
emission rate would equal its emission limit, expressed on an annual equivalent basis. After
calculating the heat input, controlled emissions assuming compliance with the applicable
standard is back-calculated. After calculating the uncontrolled NOX emissions, the presumed
net control efficiency is calculated.
• Since only TSP control efficiency is reported on Form EIA-767, the PM-10 Calculator5 was
used to derive PM-10 and PM-2.5 control efficiencies. (The PM-10 Calculator estimates
PM-10 and PM-2.5 control efficiencies based on the SCC and the primary and secondary
control devices. The control efficiencies from the PM-10 Calculator are based on data from
AP-42 for specific SCCs, where available).
The SO2 emissions were computed as controlled emissions assuming 100 percent rule effectiveness
and using the sulfur content of the fuel as specified in the EIA-767 data. The PM-10 and PM-2.5
emissions were computed as controlled emissions assuming 100 percent rule effectiveness. The ash
content of the fuel used to calculate uncontrolled PM-10 and PM-2.5 emissions was also specified in the
EIA-767 data. The NOX emissions were computed as controlled emissions assuming 80 percent rule
effectiveness from 1985-1994; beginning with 1995, NOX rule effectiveness is assumed to be
100 percent. The CO and VOC emissions were calculated as uncontrolled emissions. The algorithms to
compute emissions are presented in Table 4.2-3.
Since there are fewer required data elements (identification data, boiler fuel quantity and quality
data, and FGD data, if applicable) for those plants with a total capacity between 10 MW and 100 MW,
many values are missing for these situations. Most data elements are assigned a default value of zero;
however, if variables for boiler firing and bottom type were missing (these are needed in the SCC
assignment) the default values for wall-fired and dry bottom types are assigned. In the past, there have
been discrepancies in the boiler bottom and firing type data as reported to EIA and EPA/Acid Rain
Division (ARD). Based on a coordinated effort in 1996, all differences in bottom and firing types for coal
boilers have been resolved and updated in the files for the years beginning with 1985.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-26 Electric Utilities
-------
4.2.1.3 National Allowance Data Base (NADB) SO2 Emissions and Heat Input
The 1985 SO2 emissions and heat input that were calculated from 1985 Form EIA-767 data were
replaced by the corresponding boiler-level data (and disaggregated to the SCC level) from the National
Allowance Data Base Version 2.11 (NADBV211).6 These data underwent two public comment periods
in 1991 and 1992 and are considered the best available data for 1985. Aggregations at the fuel levels
(Tier III) are approximations only and are based on the methodology described in Section 4.2.1.
4.2.1.4 1985-1994 Acid Rain Division (ARD) NOX Rates
In 1996, ARD completed research on utility coal boiler-level NOX rates. Most (about 90 percent) of
the rates were based on relative accuracy tests performed in 1993 and 1994 as a requirement for
continuous emissions monitor (CEM) certification, while the remaining boilers' rates were obtained from
utility stack tests from various years. These coal boiler-specific NOX rates are considered, on the whole,
to be significantly better than those calculated by using EPA's NOX AP-42 factors, which are SCC-
category averages.
Thus, whenever the new NOX rates were available, NOX coal emissions were recalculated, at the coal
SCC level, using the heat input (EIA's 767 fuel throughput multiplied by the fuel heat content) and
adjusting units, according to the following equation:
NOXCOALSCC = NOXRTcoal x HTISCC x -L- (Eq. 4.2-1)
where: NOXCOAL = NOX emissions for the boiler coal SCC (in tons)
NOXRT = ARD's coal NOX rate for the given boiler (in Ibs/MMBtu)
HTI = heat input for the boiler's coal SCC (in MMBtu)
These new NOX SCC-level coal emissions replaced the AP-42 calculated emissions for most of the coal
SCCs in the 1985-1994 data bases.
4.2.1.5 1994 and 1995 ETS/CEMData
Beginning January 1, 1994, under Title IV (Acid Deposition Control) of the Clean Air Act
Amendments of 1990 (CAAA) Phase I affected utility units were required to report heat input, SO2 and
NOX data to EPA. Beginning January 1, 1995, all affected units were required to report heat input and
SO2 emissions; most also had to report NOX emissions, although some units received extensions until July
1, 1995 or January 1, 1996 for NOX reporting.
Since the ETS/CEM data are actual, rather than estimated, data, if there were a complete set of
annual SO2 and/or NOX emissions and/or heat input data available for 1994 and 1995 from ETS/CEM,
those data values replaced the data estimated from EIA-767 data. This process involved the following
steps:
• Aggregation of ETS/CEM hourly or quarterly data to annual data.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-27 Electric Utilities
-------
• Assignment of ETS/CEM data, reported on a monitoring stack or pipe level, to the boiler level.
• Matching the ETS/CEM boiler-level annual data to the processed EIA-767 annual data.
• Disaggregating the boiler-level ETS/CEM data to the boiler SCC level based on each SCC's
fractional share of the boiler heat input, SO2, and NOX, respectively. The algorithms used are
included in Table 4.2-4.
For those records in which the ETS/CEM heat input replaces the EIA-calculated value, the heat input will
not equal the product of the EIA-reported fuel throughput and heat content.
4.2.1.6 Ozone Season Daily Emissions Data
The ozone season daily (OSD) emissions for 1990-1995 are estimated by considering the day to be a
typical or average summer July day. These emissions for VOC, NOX, CO, SO2, PM-10, and PM-2.5
(ammonia and sulfates are zero) are calculated at the SCC level using the ratio of the Form EIA-767 July
monthly to annual heat input, dividing it by 31, and then multiplying this value by the already calculated
annual emissions, according to the following equation:
HTIJUL-rr
EOSD,CC = —— x EANN,CC (Eq 4 2-2)
scc 31 x HTIANNSCC scc l 4" ;
where: EOSD = Ozone season daily emissions for a given pollutant at the SCC level (in tons)
HTIJUL = July monthly Form EIA-767 calculated heat input for the given boiler's SCC
(in MMBtu)
HTIANN = annual Form EIA-767 calculated heat input for the given boiler's SCC (in
MMBtu)
EANN = Trends annual emissions for a given pollutant at the SCC level (in tons) for
that year
For the OSD for 1996, the 1996 projected annual Trends emissions is used, but the Form EIA-767
calculated 1995 July to annual heat input are used in the above equation (since the 1996 data are
unknown).
4.2.2 1996 Steam Emission Inventory
The 1996 computerized fossil-fuel plant-level data from Form EIA-759 are used in conjunction with
the 1995 fossil-fuel steam electric utility component to develop the 1996 steam emission inventory file,
since the 1996 Form EIA-767 data are not available. The fuel quantity, heat input, and emissions values
are grown by a factor based on the ratio of the 1996 Form EIA-759 plant-level, fuel-specific data to the
data for 1995.
The 1996 steam inventory includes the same records that are in the 1995 file. That is, no new plants
are added or subtracted from the 1995 steam inventory to produce the 1996 steam inventory. However,
the 1996 Form EIA-759 plant-level data would reflect boiler retirement or additions for plants in 1996
and their fuel data would be incorporated in the growth ratios and would be reflected in the 1996 data for
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-28 Electric Utilities
-------
the other boilers in the plant. As a result, the 1996 figures should be considered to be preliminary
estimates only.
4.2.3 Augmentation Process
The VOC emissions required an additional adjustment due to the underestimation of aldehydes
which are not accounted for in the VOC emission factors for the following SCCs: 10100401, 10100404,
10100501, 10100601, and 10100604. The VOC emissions were augmented according to the
methodology used in the Hydrocarbon Preprocessor (HCPREP) of the Flexible Regional Emissions Data
System (FREDS).7 This augmentation was performed on steam emission inventory for the years 1985
through 1995.
4.2.4 Sample Calculation
• 1995 boiler SCC data:
SCC thruput heatcon sulfcon coneff4
10100212 1300000 23.18 (really 23.1849046) 3.17 (really 3.1716) 89.30 (10.7)
emiss4 __ htinpt __ eiahti __ eiaso2 emf4 so2ets __ htiets
93325590 31782453.38 30140376.00 8602.9316 39 9332.5590 31782453.38
• algorithm:
cv>-> _ co°l tons * emission factor * sulfur content * (\-control efficiency)
S02coal = - — - (Eq. 4.2-3)
• calculation:
SQ2 = (1300000) (39) (3.1716) (1-.893)
coal
• result:
SO2coal = 8602 to nearest integer
But replace by 1995 ETS/CEM 9332.5590
Therefore EIAS02 = 8603 and EMISS4 (SO2coal) = 9333 in the Inventory
Please note that only the EMISS4 (SO2coal) value is available in the QUICREPTS or NET96 inventory
files. The field variable EIASO2 is available by request from internal Pechan files.
4.2.5 References
1 . Monthly Power Plant Report, Form EIA-759, data files for 1990 - 1996, U.S. Department of
Energy, Energy Information Administration, Washington, DC, 1997.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-29 Electric Utilities
-------
2. Steam-Electric Plant Operation and Design Report, Form EIA-767, data files for 1985-1995, U.S.
Department of Energy, Energy Information Administration, Washington, DC, 1997.
3. Acid Rain Program CEMS Submissions Instructions for Monitoring Plans, Certification Test
Notifications, and Quarterly Reports, U.S. Environmental Protection Agency, Washington, DC,
May 1995.
4. Compilation of Air Pollutant Emission Factors, Volume I: Stationary Point and Area Sources,
Supplement D, AP-42, U.S. Environmental Protection Agency, Research Triangle Park, NC,
September 1991.
5. Dean, T. A. and P. Carlson, PM-10 Controlled Emissions Calculator. E.H. Pechan & Associates,
Inc. Contract No. 68-DO-0120 Work Assignment No. 11-81. Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. April 27, 1993.
(TTN CHIEF BBS)
6. The National Allowance Data Base Version 2.11: Technical Support Document, Acid Rain
Division, Office of Atmospheric Programs, U.S. Environmental Protection Agency, Washington,
DC, March 1993.
7. The Flexible Regional Emissions Data System (FREDS) Documentation for the 1985 NAPAP
Emission Inventory: Preparation for the National Acid Precipitation Assessment Program.
Appendix A. EPA-600/9-89-047. U.S. Environmental Protection Agency, Office of Research and
Development, Air and Energy Engineering Research Laboratory, Research Triangle Park, NC, May
1989.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-30 Electric Utilities
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Table 4.2-1. Boiler Emissions Data Sources for NOX and SO2 by Year
Year NOY SO2
1985 Overlaid ARD coal NOX rate calculations NADBV311 data
when possible
1986 Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
1987 Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
1988 Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
1989 Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
1990 Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
1991 Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
1992 Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
1993 Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
1994 Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible; overlaid ETS/CEM data
when possible
1995 Overlaid ETS/CEM data when possible Overlaid ETS/CEM data when possible
1996 Grew from 1995 data using EIA-759 data Grew from 1995 data using EIA-759
data
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-31 Electric Utilities
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Table 4.2-2. Steam Electric Utility Unit Source Classification Code Relationships
Fossil-Fuel
Firing Type Bottom Type SCC
Coal
Bituminous No data
Wall*
Opposed
Tangential
Stoker
Cyclone
Fluidized
Bed
Subbituminous No data
Wall
Opposed
Tangential
Stoker
Cyclone
No data
Wet
Dry
No data
Wet
Dry
No data
Wet
Dry
No data
Wet
Dry
All
All
N/A
No data
Wet
Dry
No data
Wet
Dry
No data
Wet
Dry
No data
Wet
Dry
All
All
10100202
10100201
10100202
10100202
10100201
10100202
10100202
10100201
10100202
10100212
10100201
10100212
10100204
10100203
10100217
10100222
10100221
10100222
10100222
10100221
10100222
10100222
10100221
10100222
10100226
10100221
10100226
10100224
10100223
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-32
1985-1996 Methodology
Electric Utilities
-------
Table 4.2-2. (continued)
Fossil-Fuel
Lignite
Residual Oil
Distillate Oil
Natural Gas
Firing Type
No data
Wall
Opposed
Tangential
Stoker
Cyclone
No data
Wall
Opposed
Tangential
Stoker
Cyclone
No data
Wall
Opposed
Tangential
Stoker
Cyclone
No data
Wall
Opposed
Tangential
Stoker
Cyclone
Bottom Type
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
sec
10100301
10100301
10100301
10100302
10100306
10100303
10100401
10100401
10100401
10100404
10100401
10100401
10100501
10100501
10100501
10100501
10100501
10100501
10100601
10100601
10100601
10100604
10100601
10100601
*Wall firing includes front, arch, concentric, rear, side, vertical, and duct
burner firing.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-33
1985-1996 Methodology
Electric Utilities
-------
Table 4.2-3. Algorithms Used to Estimate Emissions from Electric Utility Boilers
= FC_ x EFwn _ * (1 - (RENQ * CENO >6)) x c/CF
'SCC NOr,SCC
= FC x EF
f-i 1 ^ o^v-< J^J r
) X
where:
E
FC
EF
S
A
RE
CE
b
/
UCF
unitcoal
unitoa
unit,
gas
estimated emission (in tons)
fiiel consumption (in unitf)
emission factor (in lbs/unitf)
sulfur content (expressed as a decimal)
ash content (expressed as a decimal)
rule effectiveness (expressed as a decimal)
control efficiency (expressed as a decimal)
boiler
fuel type (coal, oil, gas)
units conversion factor (1 ton/2000 Ibs)
tons burned
1000 gallons burned
million cubic feet burned
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-34
1985-1996 Methodology
Electric Utilities
-------
Table 4.2-4. Algorithms Used to Disaggregate ETS/CEM Boiler Data to the Boiler-SCC Level
scc
161SO2SCCJL
767SO2,
X CEMSO2,
CEMNOX,
sec
767NOX,
SCC,b
767NOX,
X CEMNOX,
CEMHTL^ =
767HTL
767HTL
X CEMHTL
where: b = boiler
CEMSO2, CEMNOx, CEMHTI = ETS/CEM annual boiler data for given parameter
767SO2, 767NO*, 767HTI = Form EIA-767-based calculated data for given parameter
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-35
1985-1996 Methodology
Electric Utilities
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4.3 INDUSTRIAL
The point and area source categories under the "Industrial" heading include the following Tier I and
Tier II categories:
Tier I Category Tier II Category
(01) FUEL COMBUSTION - ELECTRIC UTILITY (05) Gas Turbines and Internal
Combustion
(02) FUEL COMBUSTION - INDUSTRIAL All
(03) CHEMICAL & ALLIED PRODUCT MANUFACTURING All
(05) METALS PROCESSING All
(06) PETROLEUM & RELATED INDUSTRIES All
(07) OTHER INDUSTRIAL PROCESSES All
(09) STORAGE & TRANSPORT All
(10) WASTE DISPOSAL & RECYCLING All
(13) NATURAL SOURCES (01) Biogenic
(14) MISCELLANEOUS (05) Health Services
Since the publication of the last version of this report,1 EPA has made major changes to the 1990
emissions. The revised emissions are referred to in this document as the 1990 National Emission Trends
(NET) emissions and are for the most part based on State submitted data and used as the base year
inventory for the post-1990 emission inventory. Emission estimates for pre-1990 are based mainly on the
"old" 1990 emissions which are referred to in this document as the Interim Inventory 1990 emissions.
For most source categories, the methodology for the Interim Inventory 1990 emissions is the same as that
previously published in the Procedures document.
The 1990 Interim Inventory emissions for these source categories were generated from both the
non-utility point source and non-solvent area source portions of the 1985 National Acid Precipitation
Assessment Program (NAPAP) Emissions Inventory. These 1990 emissions served as the base year from
which the emissions for the years 1985 through 1989 were estimated. The emissions for the years 1985
through 1989 were estimated using historical data compiled by the Bureau of Economic Analysis (BEA)2
or historic estimates of fuel consumption based on the DOE's State Energy Data System (SEDS).3
The 1990 NET emissions were revised to incorporate as much state- supplied data as possible.
Sources of state data include the OTAG emission inventory, the GCVTC emission inventory, and
AIRS/FS. For most non-utility point and non-mobile sources, these emissions were projected from the
revised 1990 NET inventory to the years 1991 through 1996 using BEA and SEDS data. States were
surveyed to determine whether EPA should project their 1990 non-utility point source emissions or
extract them from AIRS/FS. For all states that selected AIRS/FS option, the emissions in the NET
inventory reflect their AIRS/FS data for the years 1991 through 1995. Additional controls were added to
the projected (or grown) emissions for the years 1995 and 1996.
This section describes the methods used to estimate both base year 1990 emission inventories and
the emission estimates for the years 1985 through 1989 and 1991 through 1996. Emission estimates for
PM-2.5 and NH3 were only estimated for the years 1990 through 1996.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-36 Industrial
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4.3.1 1990 Interim Inventory
The 1990 Interim Inventory is based on the 1985 NAPAP Inventory. The database includes annual
and average summer day emission estimates for 48 States and the District of Columbia. Five pollutants
(CO, NOX, VOC, SO2, and PM-10) were estimated for 1990.
The 1985 NAPAP Emission Inventory estimates for the point sources have been projected to the
year 1990 based on the growth in BEA historic earnings for the appropriate state and industry, as
identified by the two-digit SIC code. In order to remove the effects of inflation, the earnings data were
converted to 1982 constant dollars using the implicit price deflator for personal consumption
expenditures (PCE).4 State and SIC-level growth factors were calculated as the ratio of the 1990
earnings data to the 1985 earnings data. Additional details on point source growth indicators are
presented in section 4.3.2.1.
The area source emissions from the 1985 NAPAP Emission Inventory have been projected to the
year 1990 based on BEA historic earnings data, BEA historic population data, DOE SEDS data, or other
growth indicators. The specific growth indicator was assigned based on the source category. The BEA
earnings data were converted to 1982 dollars as described above. The 1990 SEDS data were
extrapolated from data for the years 1985 through 1989. All growth factors were calculated as the ratio
of the 1990 data to the 1985 data for the appropriate growth indicator. Additional details on area source
growth indicators are presented in section 4.3.2.2.
When creating the 1990 emission inventory, changes were made to emission factors, control
efficiencies, and emissions from the 1985 inventory for all sources. The PM-10 control efficiencies were
obtained from the PM-10 Calculator.5 In addition, rule effectiveness, which was not applied in the 1985
NAPAP Emission Inventory, was applied to the 1990 emissions estimated for the point sources. The CO,
NOX, and VOC point source controls were assumed to be 80 percent effective; PM-10 and SO2 controls
were assumed to be 100 percent effective.
The 1990 emissions for CO, NOX, SO2, and VOC were calculated using the following steps:
(1) projected 1985 controlled emissions to 1990 using the appropriate growth factors, (2) calculated the
uncontrolled emissions using control efficiencies from the 1985 NAPAP Emission Inventory, and
(3) calculated the final 1990 controlled emissions using revised control efficiencies and the appropriate
rule effectiveness. The 1990 PM-10 emissions were calculated using the TSP emissions from the 1985
NAPAP Emission Inventory. The 1990 uncontrolled TSP emissions were estimated in the same manner
as the other pollutants. The 1990 uncontrolled PM-10 estimates were calculated from these TSP
emissions by applying SCC-specific uncontrolled particle size distribution factors.6 The controlled PM-10
emissions were estimated in the same manner as the other pollutants. Because the majority of area source
emissions for all pollutants represented uncontrolled emissions, the second and third steps were not
required to estimate the 1990 area source emissions.
4.3.1.1 Control Efficiency Revisions
In the 1985 NAPAP point source estimates, control efficiencies for VOC, NOX, CO, and SO2
sources in Texas were judged to be too high for their process/control device combination. These high
control efficiencies occurred because Texas did not ask for control efficiency information, and simply
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-37 Industrial
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applied the maximum efficiency for the reported control device.7 High control efficiencies lead to high
future growth in modeling scenarios based on uncontrolled emissions (which are based on the control
efficiency and reported actual emissions). High control efficiencies also lead to extreme increases in
emissions when rule effectiveness is incorporated.
Revised VOC control efficiencies were developed for Texas from the Emission Reduction and Cost
Analysis Model for VOC (ERCAM-VOC).8 For this analysis, revised efficiencies were also developed by
SCC and control device combination for NOX, SO2, and CO using engineering judgement. These revised
control efficiencies were applied to sources in Texas. A large number of point sources outside of Texas
had VOC and CO control efficiencies that were also judged to be too high. The VOC and CO control
efficiencies used for Texas were also applied to these sources.
Control efficiencies not applied in the 1985 NAPAP Emission Inventory were incorporated in the
data files for VOC emissions from gasoline marketing (Stage I and vehicle refueling) and bulk gasoline
plants and terminals, since many areas already have regulations in place for controlling Stage I and Stage
II gasoline marketing emissions. Many current state regulations require the use of Stage I controls
(except at small volume service stations) to reduce emissions by 95 percent. Emissions were revised to
reflect these controls in areas designated as having these requirements as part of their SIPs.9 Stage II
vapor recovery systems are estimated to reduce emissions by 84 percent.10 Stage II controls are already
in place in the District of Columbia, St. Louis, Missouri, and parts of California. Stage II controls also
reduce underground tank breathing/emptying losses. Emissions in these area were revised to reflect these
controls.
Gasoline bulk plants and terminals are covered by existing Control Techniques Guidelines (CTGs)
and are included in many state regulations. Emissions were revised to reflect these controls in areas with
regulations.9 Control efficiencies assumed for these area source categories were 51 percent for gasoline
bulk plants and terminals. 1985 NAPAP area source estimates have control levels built into these
emissions. These control levels were first backed out of the emissions. In areas with no controls, the
emissions remained at uncontrolled levels. In areas with regulation, the uncontrolled emissions were
reduced to reflect the above efficiencies.
4.3.1.2 Rule Effectiveness Assumptions
Controlled emissions for each inventory year were recalculated, assuming that reported VOC, NOX,
and CO controls were 80 percent effective. Sulfur dioxide and PM-10 controls were assumed to be
100 percent effective. The 80 percent rule effectiveness assumption was judged to be unreasonable for
several VOC and CO source categories. The VOC rule effectiveness was changed to 100 percent for
bulk storage tank sources that had VOC control devices codes 90, 91, or 92. These three codes
represent conversion to variable vapor space tank, conversion to floating roof tank, and conversion to
pressurized tank, respectively. These controls were judged to be irreversible process modifications (there
are SCCs which represent these type of tanks), and therefore 100 percent rule effectiveness was applied.
VOC and CO rule effectiveness was changed to 100 percent for all Petroleum Industry - Fluid Catalytic
Cracking Units (FCCs), SCC 30600201. AP-42 lists CO waste heat boilers as a control for these units
with both CO and hydrocarbon emissions reduced to negligible levels. Since these boilers handle VOC
and CO as fuels rather than as emissions, they are treated as a process instead of as control device, and
therefore are not subject to rule effectiveness.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-38 Industrial
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There is no control device code for CO boilers in the 1985 NAPAP Inventory. To implement this
set of revisions, all FCCs were assumed to have CO boilers. In addition, the CO rule effectiveness was
changed to 100 percent for sources in five other SCCs that burn CO as a fuel. The CO rule effectiveness
was also changed to 100 percent for sources with In-Process Fuel Use SCCs. According to AP-42, there
should be no CO emissions from these sources. Emissions were not deleted from the inventory, however
applying 80 percent rule effectiveness resulted in CO emissions of up to 36,000 short tons from some In-
Process Fuel Use sources. Changing the rule effectiveness to 100 percent for sources in these SCCs
retains the emissions, but at more reasonable levels. Table 4.3-1 lists the SCCs for which the CO rule
effectiveness was changed to 100 percent.
Rule effectiveness was also adjusted for all chemical and allied product point sources from 80 to
100 percent.
4.3.1.3 Emission Factor Changes
The VOC emission factors for vehicle refueling were updated to reflect changes in gasoline Reid
vapor pressure (RVP). The 1985 NAPAP gasoline marketing service station emissions were divided into
two components: evaporative losses from underground tanks (Stage I) and Stage II vehicle refueling
(including spillage). The 1985 NAPAP emissions were derived based on gasoline usage combined with
the following uncontrolled emissions factors from AP-42:
Stage I: 7.3 lbs/1,000 gallons
Stage II: 11.0 lbs/1,000 gallons
Spillage: 0.7 lbs/1,000 gallons
These emission factors were used to calculate the fraction of total emissions attributable to each of the
components above. The total percentage is 38.4 percent for Stage I emissions and 61.6 percent for Stage
II emissions, plus spillage.
The Stage II emissions were also revised to reflect changes in emission factors. Stage II emission
factors are a function of gasoline RVP and temperature. Gasoline RVPs have decreased since 1985 in
response to the phase I and phase II RVP regulations. MOBILES was used to calculate Stage II
emission factors for five sample states (Maryland, Illinois, New York, Texas, and North Carolina).
Factors for each season were calculated based on the seasonal RVP and temperature (see Tables 4.3-2 to
4.3-4) based on engineering judgement. The national average annual factors for each inventory year are
shown in Table 4.3-5. The 1987 value was used to estimate the 1985 and 1986 emissions.
In addition to updating the emission factor for Stage II, underground tank breathing/emptying losses
were also added to the inventory. The AP-42 emission factor of 1.0 lbs/1,000 gallons was used to
estimate emissions for each inventory year. Gasoline usage was back-calculated from the Stage II VOC
emissions and emission factor.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-39 Industrial
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4.3.1.4 Emissions Calculations
A three-step process was used to calculate emissions incorporating rule effectiveness. First, base
year controlled emissions are projected to the inventory year using the following formula
(Equation 4.3-1):
CE. = CEM + (CEBY x EG} (Eq. 4.3-1)
where: CE; = controlled emissions for inventory year i
CEBY = controlled emissions for base year
EG; = earnings growth for inventory year i
Earnings growth (EG) is calculated using Equation 4.3-2:
DAT.
EGi = 1 " ^IT (Eq- 4-3'2)
UA1BY
where: DAT; = earnings data for inventory year i
DATBY = earnings data in the base year
Second, uncontrolled emissions in the inventory year are back-calculated from the controlled emissions
based on the control efficiency with the following formula (Equation 4.3-3):
CE.
UE. =
1 _ CEFF} (Eq. 4.3-3)
I 100 J
where: UE; = uncontrolled emissions for inventory year i
CE; = controlled emissions for inventory year I
CEFF = control efficiency (%)
Third, controlled emissions are recalculated incorporating rule effectiveness using the following equation
(Equation 4.3-4):
^™ TT^ 1 1 ( REFF\ ( CEFF\
CER. = UC. x 1- - x -
EF
x
100 100 EFBT
where: CEI^ = controlled emissions incorporating rule effectiveness
UQ = uncontrolled emissions
REFF = rule effectiveness (%)
CEFF = control efficiency (%)
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1 900-1 996 4-40 Industrial
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EF; = emission factor for inventory year i
EFBY = emission factor for base year
In many cases, the PM-10 emissions calculated based on the particle size distribution and PM-10
control efficiency were higher than the total suspended particulate (TSP) emissions. The source problem
is inconsistency between the TSP control efficiencies from the 1985 NAPAP inventory and the control
efficiencies determined using the PM-10 calculator. This error may have been compounded in the
following steps with the values selected for particle size distribution and efficiency. In the instances
where the controlled PM-10 emissions were calculated to be higher than the controlled TSP emissions,
the controlled PM-10 emissions were replaced with the controlled TSP emissions. The uncontrolled
PM-10 was then recalculated using the revised PM-10 emissions and the control efficiency from the
PM-10 calculator. In other words, it is assumed that in these instances, virtually all of the particles above
10 microns are being controlled and that particles emitted after the control device are all particles of 10
microns or less.
The basis for replacing the PM-10 emissions with the TSP emissions in these cases is the assumption
that the controlled TSP emissions from the 1985 NAPAP inventory are the best data that are available as
a measure of point source particulate emissions. If it is assumed that the uncontrolled emissions were the
best data available, then an adjustment to the TSP control efficiency (resulting in an increase to actual
TSP emissions) would be performed rather than replacing the PM-10 emissions.
4.3.1.5 Revised Emissions
Hazardous waste treatment, storage, and disposal facility (TSDF) emissions were updated using an
April 1989 file from EPA's Emission Standards Division (ESD).lla This file provided estimates of TSDF
emissions with longitude and latitude as the geographical indicator for each facility. The longitude and
latitude were used to match each emission to the appropriate state and county. The emissions were
generated by using the Hazardous Waste Data Management System (HWDMS)nb which includes data on
facility-specific process descriptions, waste characterization and quantities, and VOC speciation.
HWDMS generated national emissions estimates by summing emissions from each plant process at a
TSDF. Speciated emissions from each plant process were calculated as the quantity of a specific waste
handled, multiplied by a process-specific emission factor. Emission factors were taken from the
Background Information Documents for TSDFs.llc The emission estimates displayed in Table 4.3-6 for
eight counties were removed based on comments EPA has received during the last year from various
State and Regional Emission Inventory personnel.
Area source petroleum refinery fugitive emissions were re-estimated based on a revised estimate of
national petroleum refinery emissions. The national petroleum refinery emissions used to estimate area
source emission in the 1985 NAPAP were obtained from the Emissions Trends report.12 The emissions
for blowdown systems were revised to reflect the high level of control as shown in the point source
inventory.
The area source petroleum refinery fugitive emissions were re-estimated using the revised national
emission total by applying the methodology used to develop the 1985 NAPAP estimate.13 Total county
fugitive petroleum refinery emissions were determined by distributing the revised Emission Trends
estimate (excluding process heaters and catalytic cracking units) based on 1985 county refinery capacity
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-41 Industrial
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from the DOE Petroleum Supply Annual.14 Refinery capacity from this publication was allocated to
counties based on the designated location of the refinery. The 1985 NAPAP Emission Inventory was
used to aid in the matching of refineries to location.
Total area source petroleum refinery fugitive emissions were then estimated by subtracting the point
source emissions (SCCs 3-06-004 through 3-06-888) from the total county-level emissions. Negative
values (indicating higher point source emissions than the totals shown for the county), were re-allocated
to counties exhibiting positive emission values based on the proportion of total refinery capacity for each
county to avoid double-counting of emissions. This resulted in an estimate of 351 thousand short tons
for 1985 compared with the earlier 1985 NAPAP estimate of 728 thousand short tons (area source
refinery fugitives). This revised 1985 estimate was projected to the inventory years, as described in
section 4.3.2.1.
The SO2 emissions for 1987 through 1989 were adjusted to correct for the permanent closing of the
Phelps Dodge copper smelter in Arizona in January 1987. This adjustment was made by subtracting the
1985 emissions for State=04, County=003, and NEDS ID =0013 from the inventory for 1987 through
1989.
4.3.2 Emissions, 1985 to 1989
As described in section 4.3.1.4, the 1990 Interim Inventory controlled emissions were projected
from the 1985 NAPAP Emissions Inventory using Equations 4.3-1 through 4.3-4. For all other years
(1985 to 1989) the emissions were projected from the 1990 Interim Inventory emissions using Equations
4.3-1 and 4.3-2. Therefore, the 1985 emissions estimated by this method do not match the 1985 NAPAP
Emission Inventory due to the changes made in control efficiencies and emission factors and the addition
of rule effectiveness when creating the 1990 Interim Inventory. For refueling sources, the emissions were
adjusted to account for the updated emission factors for all years as described in section 4.3.1.3.
4.3.2.1 Point Source Growth
The changes in the point source emissions were equated with the changes in historic earnings by
state and industry. Emissions from each point source in the 1985 NAPAP Emissions Inventory were
projected to the years 1985 through 1991 based on the growth in earnings by industry (2-digit SIC code).
Historical annual state and industry earnings data from BEA's Table SA-52 were used to represent growth
in earnings from 1985 through 1990.
The 1985 through 1990 earnings data in Table SA-5 are expressed in nominal dollars. To be used to
estimate growth, these values were converted to constant dollars to remove the effects of inflation.
Earnings data for each year were converted to 1982 constant dollars using the implicit price deflator for
PCE.4 The PCE deflators used to convert each year's earnings data to 1982 dollars are:
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-42 Industrial
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Year 1982 PCE Deflator
1985 111.6
1987 114.3
1988 124.2
1989 129.6
1990 136.4
Several BEA categories did not contain a complete time series of data for the years 1985 through
1990. Because the SA-5 data must contain 1985 earnings and earnings for each inventory year (1985
through 1990) to be useful for estimating growth, a log linear regression equation was used where
possible to fill in missing data elements. This regression procedure was performed on all categories that
were missing at least one data point and which contained at least three data points in the time series.
Each record in the point source inventory was matched to the BEA earnings data based on the state
and the 2-digit SIC. Table 4.3.7 shows the BEA earnings category used to project growth for each of the
2-digit SICs found in the 1985 NAPAP Emission Inventory. No growth in emissions was assumed for all
point sources for which the matching BEA earnings data were not complete. Table 4.3.7 also shows the
national average growth and earnings by industry from Table SA-5.
4.3.2.2 Area Source Growth
Emissions from the 1985 NAPAP Inventory were grown to the Emission Trends years based on
historical BEA earnings data (section 4.3.2.1), historical estimates of fuel consumption, or other
category-specific growth indicators. Table 4.3-8 shows the growth indicators used for each area source
by 1985 NAPAP category.
The SEDS data were used as an indicator of emissions growth for the area source fuel combustion
categories and for the gasoline marketing categories shown in Table 4.3-9. (SEDS reports fuel
consumption by sector and fuel type.) Since fuel consumption was the activity level used to estimate
emissions for these categories, fuel consumption was a more accurate predictor of changes in emissions,
compared to other surrogate indicators such as earnings or population. SEDS fuel consumption data
were available through 1989 at the time the emission estimates were developed. The 1990 values were
extrapolated from the 1985 through 1989 data using a log linear regression technique. In addition to
projecting 1990 data for all fuel consumption categories, the regression procedure was used to fill in
missing data points for fuel consumption categories if at least three data points in the time series (1985 to
1989) were available.
The last step in the creation of the area source inventory was matching the 1985 NAPAP categories
to the new Area and Mobile Source Subsystem (AMS) categories. This matching is provided in
Table 4.3-10. Note that there is not always a one-to-one correspondence between 1985 NAPAP and
AMS categories. For example, the gasoline marketing NAPAP category was split into two separate
AMS categories representing Stage I and Stage II emissions. In addition, three 1985 NAPAP SCCs are
not included in the AMS system of codes. Therefore, AMS codes were created for process emissions
from pharmaceutical manufacture and synthetic fiber manufacture and for SOCMI fugitive emissions.
National Air Pollutant Emission Trends 1985-1996 Methodology
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4.3.3 1990 National Emission Trends
The 1990 National Emission Trends is based primarily on state data, with the 1990 interim data
filling in the gaps. The database houses U.S. annual and average summer day emission estimates for the
50 states and the District of Columbia. Seven pollutants (CO, NOX, VOC, SO2, PM-10, PM-2.5, and
NH3) were estimated in 1990. The state data were extracted from three sources, the OTAG inventory,
the GCVTC inventory, and AIRS/FS. Sections 4.3.3.1, 4.3.3.2, and 4.3.3.3 give brief descriptions of
these efforts. Section 4.3.3.4 describes the efforts necessary to supplement the inventory gaps that are
either temporal, spacial, or pollutant.
Since EPA did not receive documentation on how these inventories were developed, this section
only describes the effort to collect the data and any modifications or additions made to the data.
4.3.3.1 OTAG
The OTAG inventory for 1990 was completed in December 1996. The database houses emission
estimates for those states in the Super Regional Oxidant A (SUPROXA) domain. The estimates were
developed to represent average summer day emissions for the ozone pollutants (VOC, NOX, and CO).
This section gives a background of the OTAG emission inventory and the data collection process.
4.3.3.1.1 Inventory Components —
The OTAG inventory contains data for all states that are partially or fully in the SUPROXA
modeling domain. The SUPROXA domain was developed in the late 1980s as part of the EPA regional
oxidant modeling (ROM) applications. EPA had initially used three smaller regional domains (Northeast,
Midwest, and Southeast) for ozone modeling, but wanted to model the full effects of transport in the
eastern United States without having to deal with estimating boundary conditions along relatively high
emission areas. Therefore, these three domains were combined and expanded to form the Super Domain.
The western extent of the domain was designed to allow for coverage of the largest urban areas in the
eastern United States without extending too far west to encounter terrain difficulties associated with the
Rocky Mountains. The Northern boundary was designed to include the major urban areas of eastern
Canada. The southern boundary was designed to include as much of the United States as possible, but
was limited to latitude 26 °N, due to computational limitations of the photochemical models. (Emission
estimates for Canada were not extracted from OTAG for inclusion in the NET inventory.)
The current SUPROXA domain is defined by the following coordinates:
North: 47.00°N East: 67.00°W
South: 26.00°N West: 99.00°W
Its eastern boundary is the Atlantic Ocean and its western border runs from north to south through North
Dakota, South Dakota, Nebraska, Kansas, Oklahoma, and Texas. In total, the OTAG Inventory
completely covers 37 states and the District of Columbia.
The OTAG inventory is primarily an ozone precursor inventory. It includes emission estimates of
VOC, NOX, and CO for all applicable source categories throughout the domain. It also includes a small
amount of SO2 and PM-10 emission data that was sent by states along with their ozone precursor data.
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No quality assurance (QA) was performed on the SO2 and PM-10 emission estimates for the OTAG
inventory effort.
Since the underlying purpose of the OTAG inventory is to support photochemical modeling for
ozone, it is primarily an average summer day inventory. Emission estimates that were submitted as
annual emission estimates were converted to average summer day estimates using operating schedule data
and default temporal profiles and vice versa.
The OTAG inventory is made up of three major components: (1) the point source component,
which includes segment/pollutant level emission estimates and other relevant data (e.g., stack parameters,
geographic coordinates, and base year control information) for all stationary point sources in the domain;
(2) the area source component, which includes county level emission estimates for all stationary area
sources and non-road engines; and (3) the on-road vehicle component, which includes county/roadway
functional class/vehicle type estimates of VMT and MOBILESa input files for the entire domain. Of
these three components, the NET inventory extracted all but the utility emissions. (See section 4.2 for a
description of the utility NET emissions and section 4.6 for the on-road mobile NET emissions.)
4.3.3.1.2 Interim Emissions Inventory (OTAG Default) —
The primary data sources for the OTAG inventory were the individual states. Where states were
unable to provide data, the 1990 Interim Inventory 15 was used for default inventory data. A more
detailed description of the 1990 Interim Inventory is presented in section 4.3.1.
4.3.3.1.3 State Data Collection Procedures —
Since the completion of the Interim Inventory in 1992, many states had completed 1990 inventories
for ozone nonattainment areas as required for preparing SIPs. In addition to these SIP inventories, many
states had developed more comprehensive 1990 emission estimates covering their entire state. Since
these state inventories were both more recent and more comprehensive than the Interim Inventory, a new
inventory was developed based on state inventory data (where available) in an effort to develop the most
accurate emission inventory to use in the OTAG modeling.
On May 5, 1995, a letter from John Seitz (Director of EPA's Office of Air Quality Planning and
Standards [OAQPS]) and Mary Gade (Vice President of ECOS) to State Air Directors, states were
requested to supply available emission inventory data for incorporation into the OTAG inventory.16
Specifically, states were requested to supply all available point and area source emissions data for VOC,
NOX, CO, SO2, and PM-10, with the primary focus on emissions of ozone precursors. Some emission
inventory data were received from 36 of the 38 states in the OTAG domain. To minimize the burden to
the states, there was no specified format for submitting State data. The majority of the state data was
submitted in one of three formats:
1) an Emissions Preprocessor System Version 2.0 (EPS2.0) Workfile
2) an ad hoc report from AIRS/FS
3) data files extracted from a state emission inventory database
The origin of data submitted by each state is described in section 4.3.3.1.4.1 for point sources and
4.3.3.1.4.2 for area sources.
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4.3.3.1.4. State Data Incorporation Procedures/Guidelines —
The general procedure for incorporating state data into the OTAG Inventory was to take the data
"as is" from the state submissions. There were two main exceptions to this policy. First, any inventory
data for years other than 1990 was backcast to 1990 using BEA Industrial Earnings data by state and
two-digit SIC code.2 This conversion was required for five states that submitted point source data for the
years 1992 through 1994. All other data submitted were for 1990.
Second, any emission inventory data that included annual emission estimates but not average
summer day values were temporally allocated to produce average summer day values. This temporal
allocation was performed for point and area data supplied by several states. For point sources, the
operating schedule data, if supplied, were used to temporally allocate annual emissions to average
summer weekday using the following equation:
EMISSIONSASD = EMISSIONSANNUAL * SUMTHRU * 1/(13 * DPW) (Eq. 4.3-5)
where:
EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
SUMTHRU = summer throughput percentage
DPW = days per week in operation
If operating schedule data were not supplied for the point source, annual emissions were temporally
allocated to an average summer weekday using EPA's default Temporal Allocation file. This computer
file contains default seasonal and daily temporal profiles by SCC. The following equation was used:
EMISSIONSASD = EMISSIONSANNUAL I (SUMFACSCC * WDFACSCC) (Eq. 4.3-6)
where:
EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
SUMFACSCC = default summer season temporal factor for SCC
WDFACSCC = default summer weekday temporal factor for SCC
There were a small number of SCCs that were not in the Temporal Allocation file. For these SCCs,
average summer weekday emissions were assumed to be the same as those for an average day during the
year and were calculated using the following equation:
EMISSIONSASD = EMISSIONSANNUAL I 365 (Eq. 4.3-7)
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where:
EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
4.3.3.1.4.1 Point. For stationary point sources, 36 of the 38 states in the OTAG domain supplied
emission estimates covering the entire state. Data from the Interim Inventory were used for the two
states (Iowa and Mississippi) that did not supply data. Most states supplied 1990 point source data,
although some states supplied data for later years because the later year data reflected significant
improvements over their 1990 data. Inventory data for years other than 1990 were backcast to 1990
using BEA historical estimates of industrial earnings at the 2-digit SIC level. Table 4.3-11 provides a
brief description of the point source data supplied by each state. Figure 4.3-1 shows the states that
supplied point source data and whether the data were for 1990 or a later year.
4.3.3.1.4.2 Area. For area sources, 17 of the 38 states in the OTAG domain supplied 1990 emission
estimates covering the entire state, and an additional nine states supplied 1990 emission estimates
covering part of their state (partial coverage was mostly in ozone nonattainment areas). Interim
Inventory data were the sole data source for 12 states. Where the area source data supplied included
annual emission estimates, the default temporal factors were used to develop average summer daily
emission estimates. Table 4.3-12 provides a brief description of the area source data supplied by each
state. Figure 4.3-2 shows the states that supplied area source data.
4.3.3.1.4.3 Rule Effectiveness. For the OTAG inventory, states were asked to submit their best
estimate of 1990 emissions. There was no requirement that state-submitted point source data include rule
effectiveness for plants with controls in place in that year. States were instructed to use their judgment
about whether to include rule effectiveness in the emission estimates. As a result, some states submitted
estimates that were calculated using rule effectiveness, while other states submitted estimates that were
calculated without using rule effectiveness.
The use of rule effectiveness in estimating emissions can result in emission estimates that are much
higher than estimates for the same source calculated without using rule effectiveness, especially for
sources with high control efficiencies (95 percent or above). Because of this problem, there was concern
that the OTAG emission estimates for states that used rule effectiveness would be biased to larger
estimates relative to states that did not include rule effectiveness in their computations.
To test if this bias existed, county level maps of point source emissions were developed for the
OTAG domain. If this bias did exist, one would expect to see sharp differences at state borders between
states using rule effectiveness and states not using rule effectiveness. Sharp state boundaries were not
evident in any of the maps created. Based on this analysis, it was determined that impact of rule
effectiveness inconsistencies was not causing large biases in the inventory.
4.3.3.2 Grand Canyon Visibility Transport Commission Inventory
The GCVTC inventory includes detailed emissions data for eleven states: Arizona, California,
Colorado, Idaho, Montana, Nevada, New Mexico, Oregon, Utah, Washington, and Wyoming.17 This
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inventory was developed by compiling and merging existing inventory databases. The primary data
sources used were state inventories for California and Oregon, AIRS/FS for VOC, NOX, and SO2 point
source data for the other nine states, the 1990 Interim Inventory for area source data for the other nine
states, and the 1985 NAPAP inventory for NH3 and TSP data. In addition to these existing data, the
GCVTC inventory includes newly developed emission estimates for forest wildfires and prescribed
burning.
After a detailed analysis of the GCVTC inventory, it was determined that the following portions of
the GCVTC inventory would be incorporated into the PM inventory:
• complete point and area source data for California
• complete point and area source data for Oregon
• forest wildfire data for the entire eleven state region
• prescribed burning data for the entire eleven state region
State data from California and Oregon were incorporated because they are complete inventories
developed by the states and are presumably based on more recent, detailed and accurate data than the
Interim Inventory (some of which is still based on the 1985 NAPAP inventory). The wildfire data in the
GCVTC inventory represent a detailed survey of forest fires in the study area and are clearly more
accurate than the wildfire data in the Interim Inventory. The prescribed burning data in the GCVTC
inventory are the same as the data in the Interim Inventory at the state level, but contain more detailed
county-level data.
Non-utility point source emission estimates in the GCVTC inventory from states other than
California and Oregon came from AIRS/FS. Corrections were made to this inventory to the VOC and
PM emissions. The organic emissions reported in GCVTC inventory for California are total organics
(TOG). These emissions were converted to VOC using the profiles from EPA's SPECIATE18 database.
Since the PM emissions in the GCVTC were reported as both TSP and PM-2.5, EPA estimated PM-10
from the TSP in a similar manner as described in section 4.3.1.4.
4.3.3.3 AIRS/FS
SO2 and PM-10 (or PM-10 estimated from TSP) sources of greater than 250 tons per year as
reported to AIRS/FS that were not included in either the OTAG or GCVTC inventories were appended
to the NET inventory. The data were extracted from AIRS/FS using the data criteria set listed in table
4.3-13. The data elements extracted are also listed in Table 4.3-13. The data were extracted in late
November 1996. It is important to note that estimated emissions were extracted.
4.3.3.4 Data Gaps
As stated above, the starting point for the 1990 NET inventory is the OTAG, GCVTC, AIRS, and
1990 Interim inventories. Data added to these inventories include estimates of SO2, PM-10, PM-2.5, and
NH3, as well as annual or ozone season daily (depending on the inventory) emission estimates for all
pollutants. This section describes the steps taken to fill in the gaps from the other inventories.
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4.3.3.4.1 SO2 and PM Emissions —
For SO2 and PM-10, state data from OTAG were used where possible. (The GCVTC inventory
contained SO2 and PM annual emissions.) In most cases, OTAG data for these pollutants were not
available. For point sources, data for plants over 250 tons per year for SO2 and PM-10 were added from
AIRS/FS. The AIRS/FS data were also matched to the OTAG plants and the emissions were attached to
existing plants from the OTAG data where a match was found. Where no match was found to the plants
in the OTAG data, new plants were added to the inventory. For OTAG plants where there were no
matching data in AIRS/FS and for all area sources of SO2 and PM-10, emissions were calculated based
on the emission estimates for other pollutants.
The approach to developing SO2 and PM-10 emissions from unmatched point and area sources
involved using uncontrolled emission factor ratios to calculate uncontrolled emissions. This method used
SO2 or PM-10 ratios to NOX. NOX was the pollutant utilized to calculate the ratio because (1) the types
of sources likely to be important SO2 and PM-10 emitters are likely to be similar to important NOX
sources and (2) the generally high quality of the NOX emissions data. Ratios of SO2/NOX and PM-10/NOX
based on uncontrolled emission factors were developed. These ratios were multiplied by uncontrolled
NOX emissions to determine either uncontrolled SO2 or PM-10 emissions. Once the uncontrolled
emissions were calculated, information on VOC, NOX, and CO control devices was used to determine if
they also controlled SO2 and/or PM-10. If this review determined that the control devices listed did not
control SO2 and/or PM-10, plant matches between the OTAG and Interim Inventory were performed to
ascertain the SO2 and PM-10 controls applicable for those sources. The plant matching component of
this work involved only simple matching based on information related to the state and county FIPS code,
along with the plant and point IDs.
There was one exception to the procedures used to develop the PM-10 point source estimates. For
South Carolina, PM-10 emission estimates came from the Interim Inventory. This was because South
Carolina had no PM data in AIRS/FS for 1990 and using the emission factor ratios resulted in
unrealistically high PM-10 emissions.
There were no PM-2.5 data in either OTAG or AIRS/FS. Therefore, the point and area PM-2.5
emission estimates were developed based on the PM-10 estimates using source-specific uncontrolled
particle size distributions and particle size specific control efficiencies for sources with PM-10 controls.
To estimate PM-2.5, uncontrolled PM-10 was first estimated by removing the impact of any PM-10
controls on sources in the inventory. Next, the uncontrolled PM-2.5 was calculated by multiplying the
uncontrolled PM-10 emission estimates by the ratio of the PM-2.5 particle size multiplier to the PM-10
particle size multiplier. (These particle size multipliers represent the percentage to total particulates
below the specified size.) Finally, controls were reapplied to sources with PM-10 controls by multiplying
the uncontrolled PM-2.5 by source/control device particle size specific control efficiencies.
4.3.3.4.2 NH3 Emissions —
All NH3 emission estimates incorporated into the NET Inventory came directly from EPA's National
Particulate Inventory (NPI).19 This methodology is the same as that reported in section 4.3.1 for the
1990 Interim, with the exception of agricultural sources. The NPI contained the only NH3 emissions
inventory available. (Any NH3 estimates included in the OTAG or AIRS/FS inventory were eliminated
due to sparseness of data.) As with SO2 and PM-10, plant matching was performed for point sources.
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Emissions were attached to existing plants where there was a match. New plants were added for plants
where there was no match.
4.3.3.4.3 Other Modifications —
Additional data were also used to fill data gaps for residential wood combustion and prescribed
burning. Although these categories were in the OTAG inventory, the data from OTAG were not usable
since the average summer day emissions were often very small or zero. Therefore, annual and average
summer day emission estimates for these two sources were taken from the NET.
Additional QA/quality control (QC) of the inventory resulted in the following changes:
• Emissions with SCCs of fewer than eight digits or starting with a digit greater than the number
"6" were deleted because they are invalid codes.
• Area source PM-10 and PM-2.5 utility emissions were deleted.
• A correction was made to a point (state 13/county 313/plant 0084) where the ozone season
daily value had been revised but not the annual value.
• Tier assignments were made for all SCCs.
• Checked and fixed sources with PM-2.5 emissions which were greater than their PM-10
emissions.
• Checked and fixed sources with PM-10 emissions greater than zero and PM-2.5 emissions
equal to zero.
• TSDFs - The 1990 TSDF emission estimates provided by the States through the OTAG effort
were replaced with the 1990 emission estimates modified as described in section 4.3.1.5.
4.3.4 Emissions, 1991 to 1994
The 1991 through 1994 area source emissions were grown in a similar manner as the 1985 through
1989 estimates, except for using a different base year inventory. The base year for the 1991 through
1994 emissions is the 1990 NET inventory. The point source inventory was also grown for those states
that did not want their AIRS/FS data used. (The list of states are detailed in the AIRS/FS subsection,
4.3.4.2.) For those states requesting that EPA extract their data from AIRS/FS, the years 1990 through
1995 were downloaded from the EPA IBM Mainframe. The 1996 emissions were not extracted since
states are not required to have the 1996 data uploaded into AIRS/FS until July 1997.
4.3.4.1 Grown Estimates
The 1991 through 1994 point and area source emissions were grown using the 1990 NET inventory
as the basis. The algorithm for determining the estimates is detailed in section 4.3.1.4. The 1990 through
1996 SEDS and BEA data are presented in Tables 4.3-14 and 4.3-15. The 1996 BEA and SEDS data
were determined based on linear interpretation of the 1988 through 1995 data. Point sources were
projected using the first two digits of the SIC code by state. Area source emissions were projected using
either BEA or SEDS. Table 4.3-16 lists the SCC and the source for growth.
The 1990 through 1996 earnings data in BEA Table SA-5 (or estimated from this table) are
expressed in nominal dollars. In order to be used to estimate growth, these values were converted to
constant dollars to remove the effects of inflation. Earnings data for each year were converted to 1992
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constant dollars using the implicit price deflator for PCE. The PCE deflators used to convert each year's
earnings data to 1992 dollars are:
Year 1992 PCE Deflator
1990 93.6
1991 97.3
1992 100.0
1993 102.6
1994 104.9
1995 107.6
1996 109.7
4.3.4.2 AIRS/FS
Several states responded to EPA's survey and requested that their 1991 through 1995 estimates
reflect their emissions as reported in AIRS/FS. The list of these states, along with the years available in
AIRS/FS is given in Table 4.3-17. As described in section 4.3.3.3, default estimated annual and ozone
season daily emissions (where available) were extracted from AIRS/FS. Some changes were made to
these AIRS/FS files. For example, the default emissions for some states contain rule effectiveness and the
emissions were determined to be too high by EPA. The emissions without rule effectiveness were
extracted from AIRS/FS and replaced the previously high estimates. The changes made to select state
and/or plant AIRS/FS data are listed below.
• Louisiana All VOC source emissions were re-extracted to obtain
emissions without rule effectiveness for the year 1994.
• Colorado - Mastercraft The VOC emissions were reported as ton/year in the initial
download from AIRS. The units were changed to
pounds/year in AIRS.
• Wisconsin - Briggs and Stratton The VOC emissions for two SCCs were changed from with
rule effectiveness to without rule effectiveness for the years
1991, 1993, and 1994.
As noted in Table 4.3-17, several states did not report emissions for all pollutants for all years for
the 1990 to 1995 time period. To fill these data gaps, EPA applied linear interpolation or extrapolated
the closest two years worth of emissions at the plant level. If only one year of emissions data were
available, the emission estimates were held constant for all the years. The segment-SCC level emissions
were derived using the average split for all available years. The non-emission data gaps were filled by
using the most recent data available for the plant.
As described in section 4.3.3.4.1, many states do not provide PM-10 emissions to AIRS. These
states' TSP emissions were converted to PM-10 emissions using uncontrolled particle size distributions
and AP-42 derived control efficiencies. The PM-10 emissions are then converted to PM-2.5 in the same
manner as described in section 4.3.1.4. The State of South Carolina provided its own conversion factor
for estimating PM-10 from TSP.19
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For all sources that did not report ozone season daily emissions, these emissions were estimated
using the algorithm described in section 4.3.3.1.4 and equations 4.3-5 through 4.3-7.
4.3.5 1995 Emissions
The 1995 emission estimates were derived in a similar manner as the 1991 through 1994 emissions.
The estimates were either extracted from AIRS/FS for 1995, estimated using AIRS/FS data for the years
1990 through 1994, or projected using the 1990 NET inventory. The method used depended on states'
responses to a survey conducted by EPA early in 1997. A description of the AIRS/FS methodology is
described in section 4.3.4. The following two subsections describe the projected emissions.
In addition to projecting the 1990 inventory to 1995, EPA has added the source category cotton
ginning. The methodology is detailed in section 4.3.5.4.
4.3.5.1 Grown Estimate
The 1995 point and area source emissions were grown using the 1990 NET inventory as the
basis. The algorithm for determining the estimates is detailed in section 4.3.3.1.4 and equations 4.3-5
through 4.3-7. The 1990 through 1996 SEDS and BEA data are presented in Tables 4.3-14 and 4.3-15.
4.3.5.2 NOXRACT
Major stationary source NOX emitters in marginal and above nonattainment areas and in ozone
transport regions (OTRs) are required to install RACT-level controls under the ozone nonattainment
related provisions of Title I of the CAAA. The definition of major stationary source for NOX differs by
the severity of the ozone problem as shown in Table 4.3-18.
NOX RACT controls for non-utility sources that were modeled for the 1995 NET emissions are
shown in Table 4.3-19. These RACT-level controls were applied to point source emitters with emissions
at or above the major source size definition for each area. The application of NOX RACT controls was
only applied to grown sources.
4.3.5.3 Rule Effectiveness
Rule effectiveness was revised in 1995 for all grown sources using the information in the 1990
database file. If the rule effectiveness value was between 0 and 100 percent in 1990 and the control
efficiency was greater than 0 percent, the uncontrolled emissions were calculated for 1990. The 1995
emissions were calculated by multiplying the growth factor by the 1990 uncontrolled emissions and the
control efficiency and a rule effectiveness of 100 percent. The adjustment for rule effectiveness was only
applied to grown sources.
4.3.5.4 Cotton Ginning
Cotton ginning estimates for 1995 and 1996 were calculated using the following methodology.
Ginning activity occurs from August/September through March, covering parts of two calendar years,20
with the majority of ginning activity occurring between September and January. Ginning activity occurs
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in the 16 states where cotton is grown, i.e., Alabama, Arizona, Arkansas, California, Florida, Georgia,
Louisiana, Mississippi, Missouri, New Mexico, North Carolina, Oklahoma, South Carolina, Tennessee,
Texas, and Virginia. The majority of the ginning facilities are located in Arkansas, California, Louisiana,
Mississippi, and Texas.
The general equation for estimating emissions from this category is given below.
E = (Pc*ff) * EFc + (P*ff) * EF (Eq. 4.3-8)
Where: E = annual county emissions (Ibs/year)
B = number of bales ginned in the county
Pc = fraction of total bales at gins with conventional controls
EFC = emission factor for gins with conventional controls (Ibs/bale)
Pf = fraction of total bales at gins with full controls
EFf = emission factor for gins with full controls (Ibs/bale)
4.3.5.4.1 Activity Indicator —
The activity factor for this category is the number of bales of cotton ginned. The U.S. Department
of Agriculture (USDA) compiles and reports data on the amount of cotton ginned by state, district, and
county for each crop year in its Cotton Ginnings reports.21 (A crop year runs from September through
March.) These reports are published once or twice per month during the crop year and give the amount
of cotton ginned as running totals.
The number of bales ginned in a county can be obtained from Reference 20. However, since these
data are reported as running totals for the growing season (which spans parts of two calendar years), the
number of bales ginned for a calendar year will need to be determined using data from two crop years.
The amount of cotton ginned from January 1 to the end of the season (March) for calendar year x (crop
year x) and the amount of cotton ginned from the beginning of the season (August/ September) for
calendar year x (crop year y) should be summed to get the calendar year x total. To determine the
amount ginned from January 1 to the end of the season, subtract the amount ginned by January 1 (in the
early January Cotton Ginnings report) from the total reported in the March or end of season Cotton
Ginnings report. To determine the amount ginned from the beginning of the season to January 1, use the
total recorded by January 1 in the early January Cotton Ginnings report.
It should be noted that for confidentiality purposes, the Cotton Ginnings report may not show
detailed data for a county, but may include those data in the district, state, or U.S. totals. Data for a gin
may be considered confidential if (1) there are fewer than three gins operating in the county, or (2) more
than 60 percent of the cotton ginned in the county is ginned at one mill. The standard Cotton Ginnings
report lists the following four footnotes to its table of running bales ginned:
I/ withheld to avoid disclosing individual gins
II withheld to avoid disclosing individual gins, but included in state total
3/ excludes some gins' data to avoid disclosing individual gins, but included in the state total
4/ withheld to avoid disclosing individual gins but included in the U.S. total
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The following methodology can be used for estimating the number of bales ginned from those
counties with confidential data.
(1) If all counties in the district show confidentiality, but there is a district total, divide district total by
the number of counties to get individual county estimates.
(2) If some (but not all) counties in a district show confidentiality and there is a district total, subtract
county totals from district total and divide the remainder by the number of counties showing
confidentiality to get estimates for the "confidential" counties.
(3) If both county and district totals are considered confidential within a state, divide the state total by
the number of counties to get individual county estimates.
(4) If some (but not all) districts show confidentiality, subtract recorded district totals from the state
total and divide the remainder by the number of counties showing confidentiality to get estimates for
the "confidential" counties.
Although this method of apportioning is time consuming, it is preferable to using the ginning
distribution from previous years to determine current estimates of number of bales ginned in confidential
counties. The variability of the cotton harvest from year to year, the possibility of past claims of
confidentiality, and the industry trend from numerous small gins to fewer, large gins makes distribution
based on past activity unreliable. In addition, if the estimates generated by the methodology above does
not meet with state approval, the state may submit more accurate data for those counties and the
apportioning methodology can be revised.
The March report, produced at the end of the crop year, contains the final totals (including revisions
and updates) for the crop year. Data in the report may differ from earlier reports for the crop year in both
total number of bales ginned and counties where ginning occurred. In fact, for crop year 1995, the
January reports showed higher totals for some counties than did the final report. Subtracting the January
totals from the March totals for these counties yielded a negative number. In these cases, the activity for
the county for that time period was considered zero. For this methodology, in instances where counties
are recorded in the March final report, but not in earlier (e.g., January) reports, the activity is assumed to
have occurred sometime before January. These counties were then added to the January listing as
confidential counties, and distribution of ginning activity was then performed.
Kansas has only one small gin operating in the state, and this gin does not operate every year. Since
the amount of cotton ginned at this facility is considered insignificant (less than 0.005 percent of the total
cotton ginned in the United States in 1995), no emissions for Kansas were calculated.
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4.3.5.4.2 Emission Factor —
AP-4222 presents total PM and PM-10 emission factors (in Ibs/bale) for gins with high-efficiency
cyclones on all exhaust streams (i.e., full controls) and for gins with screened drums or cages on the lint
cleaners and battery condenser and high-efficiency cyclones on all other exhaust streams (i.e.,
conventional controls). PM-2.5 emissions were assumed to be one percent of the total PM emissions, as
given in Table B.2.2. in AP-42 for Grain Handling. Table 4.3-30 shows the AP-42 emission factors.
Additional information obtained from EPA includes the estimated percent of cotton baled at gins using
each type of control by state. These data were developed by the National Cotton Council and are shown
in Table 4.3-21.23 Emission factors are controlled emissions factors as indicated.
4.3.5.4.3 Sample Calculation —
Using the data for Alabama from the 03/25/96 Cotton Ginnings report:
• District 10 shows data for three counties, confidential data for two counties and a district total.
(1) Subtract District 10 county data from District 10 total.
144,250 - (35,200 + 59,300 + 25,750) = 24,000 bales
(2) Divide the remaining total by two (two counties claimed confidentiality) to estimate amount for
each confidential county.
24,000/2 = 12,000 bales per confidential county
This procedure can also be used for District 40.
• Districts 50 and 60 show district totals only (i.e., all counties within these districts claim
confidentiality). To estimate individual county totals, divide each district total by the number of
counties within that district.
District 50 District 60
122,300/4 = 30,575 bales per county 153,650/6 = 25,608 bales per county
• Districts 20 and 30 claim county and district confidentiality. To estimate county totals,
(1) Subtract available district totals from state total.
491,150 - (144,250 + 34,650 + 122,300 + 153,650) = 36,300 bales
(2) Divide remainder by the number of counties claiming confidentiality in the two remaining
districts.
36,300/8 = 4,538 bales per confidential county
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Using the data in Table 4.3-22 and data from Cotton Ginnings reports, PM-10 emissions can be
calculated for Madison County, Alabama, as shown in the following example.
(1) Determine total running bales ginned in Madison County in 1996
(a) For the period January 1, 1996 until the end of the crop season, subtract the running total as of
January 1, 1996 from the 01/25/96 Cotton Ginnings report from the final crop season total
from the 03/25/96 Cotton Ginnings report.
25,750 bales - 25,700 bales = 50 bales
(b) For the period from the beginning of the 1996 crop year until the end of calendar year 1996, use
the running total as of January 1, 1997 from the 01/24/97 Cotton Ginnings report. Add this to
the total from (a) above to get calendar year 1996 total.
50 bales + 40,500 bales = 40,550 bales ginned in calendar year 1996
(2) Determine the percent of crop ginned by emission control method using Table 4.3-22.
(3) Use the emission factors from AP-42 as shown in Table 4.3-20, the results of (1) and (2) above, and
the general equation to estimate emissions.
E = [(Pc*B) * EFc] + [(PfB) * EFf] (Eq. 4.3-9)
Where: Pc = 0.8
Pf = 0.2
B = 40,550 bales
EFC = 1.21b/balePM-10
EFf = 0.82 Ib/bale PM-10
Emissions = [(0.8 * 40,550 bales) * 1 .2 Ib/bale] + [(0.2 * 40,550 bales) * 0.82 Ib/bale]
= 38,928 Ibs + 6,650 Ibs
= 45,578 Ibs or 23 tons of PM-10
4.3.6 1996 Emissions
The 1996 emission estimates were derived in a similar manner as the 1995 emissions. For the non-
utility point sources, the 1995 AIRS/FS emissions and 1995 emissions grown from 1990 emissions were
merged. The following three subsections describes the projected 1996 emissions.
4.3.6.1 Grown Estimates
The 1996 point and area source emissions were grown using the 1995 NET inventory as the basis.
The algorithm for determining the estimates is detailed in section 4.3.1.4 and is described by the equation
below. The 1990 through 1996 SEDS and BEA data are presented in Tables 4.3-14 and 4.3-15. The
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1 900-1 996 4-56 Industrial
-------
1996 BEA and SEDS data were determined using linear interpretation of the 1988 through 1995 data.
Rule effectiveness was updated to 100 percent as described in section 4.3.5.3 for the AIRS/FS sources
that reported rule effectiveness of less than 100 percent in 1995.
The following equation describes the calculation used to estimate the 1996 emissions:
CEFF\ ( RP\\
— *— (Eq. 4.3-10)
where: CER1996 = controlled emissions incorporating rule effectiveness
UC1995 = uncontrolled emissions
GS = growth surrogate (either BEA or SEDS data)
REFF = rule effectiveness (percent)
CEFF = control efficiency (percent)
RP = rule penetration (percent)
The rule effectiveness for 1996 was always assumed to be 100 percent. The control efficiencies and rule
penetrations are detailed in the following subsections.
4.3.6.2 1996 VOC Controls
This section discusses VOC stationary source controls (except those for electric utilities). These
controls were developed to represent the measures mandated by the CAAA and in place in 1996. Title I
(specifically the ozone nonattainment provisions) affects VOC stationary sources. Title III hazardous air
pollutant regulations will also affect VOC source categories. The discussion for each source category-
specific control measure includes the regulatory authority, CAAA provisions relating to the control
measure, and relevant EPA guidance.
Table 4.3-23 list the point source controls by pod. (A pod is a group of SCCs with similar emissions
and process characteristics for which common control measures, i.e., cost and emission reductions, can
be applied. It is used for control measure application/costing purposes.) Table 4.3-24 lists the POD to
SCC match. Table 4.3-25 lists the area source control efficiencies, and rule effectiveness and rule
penetration if not 100 percent. A description of the controls is detailed below by measure.
4.3.6.2.1 Hazardous Waste Treatment, Storage, and Disposal Facilities —
Control assumptions for TSDF reflect application of Phase I and Phase II standards, as described
below. Regulatory authority for these rules falls under the Resource Conservation and Recovery Act
(RCRA). The Phase I rule for hazardous waste TSDFs restricts emissions from equipment leaks and
process vents.24 Process vent emissions must be below 3 Ib/hr and 3.1 tons per year (tpy) or control
devices must be installed. The control device must reduce emissions by 95 percent from uncontrolled
levels or, if enclosed combustion devices are used, reduce the vent stream to 20 parts per million (ppm)
by volume. The choice of control is not limited; condensers, absorbers, incinerators, and flares are
demonstrated control techniques.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-57 Industrial
-------
The equipment leak standards apply to emissions from valves, pumps, compressors, pressure relief
devices, sampling connection systems, and open-ended valves or lines. Streams with organic
concentrations equal to or greater than ten percent by weight are subject to the standards. Record
keeping and monitoring are required for affected devices, in addition to the equipment standards, such as
dual mechanical seals for compressors.
The Phase II rule will restrict emissions from tanks, containers, and surface impoundments.25 The
rule will affect an estimated 2,300 TSDFs. The proposed rule also requires generators with 90-day
accumulation tanks (tanks holding waste for a period of 90 days or more) to install controls in order to
retain RCRA permit exempt status. An estimated 7,200 generators will be affected. Controls specified
for the Phase II rule are covers vented to a 95 percent destruction device, such as incinerators or carbon
absorbers.
4.3.6.2.2 Municipal Solid Waste Landfills —
Emission reductions for landfills reflect the proposed rule and guidelines published in the Federal
Register.26 Regulatory authority for this control measure falls under RCRA. The proposed rule requires
installation of gas collection systems and combustion (open flare) of the captured gases for all existing
landfills emitting greater than 150 mg/year, or 167 tpy, of nonmethane organic compounds. A new
source performance standard (NSPS) requires the same controls on all new facilities. The control device
efficiency is estimated to be 82 percent. A rule effectiveness of 100 percent was applied. The
penetration rate for existing facilities is estimated at 84 percent. A 100 percent penetration was applied
to new sources.
4.3.6.2.3 New Control Technique Guidelines (CTGs) —
Section 183 of the CAAA mandated EPA to establish 11 new CTGs by November 1993. Controls
following these guidelines must be implemented in moderate, serious, severe, and extreme nonattainment
areas. The majority of these documents are in draft form or still in the analysis stages. Clean-up solvents
will also be regulated through a negotiated rulemaking; however, implementation is not expected by
1996. Both of these control measures would apply nationwide. Control efficiency information was not
available for many of the source categories, so default assumptions have been made.
4.3.6.2.4 Existing CTGs —
EPA has issued three groups of CTG documents to be implemented in ozone nonattainment areas.
These controls should already be included in areas designated as nonattainment prior to 1990. These
controls, however, must also be implemented in newly designated nonattainment areas and over the entire
OTR. Not all CTGs are included in Table 4.3-25 because of the difficulty, in some cases, of matching the
document to the appropriate sources within the inventory. It is assumed that all existing CTGs are
implemented by 1996.
4.3.6.2.5 Reasonably Available Control Technology —
The CAAA direct moderate and above ozone nonattainment areas to require reasonably available
control technology (RACT)-level controls to VOC major stationary sources. The definition of major
source varies, depending on the severity of the ozone nonattainment classification, as listed in
Table 4.3-18.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-58 Industrial
-------
Point source RACT control assumptions are based on EPA documents, including background
documents for New Source Performance Standards (NSPSs) and National Emission Standards for
Hazardous Air Pollutants (NESHAPs), Alternative Control Technology (ACT) documents, and other
compilations of VOC control techniques.
Area source RACT control information was taken from similar sources. The complicating factor for
area source RACT controls is the major stationary source size cutoff. A penetration factor was
developed that accounts for the fraction of emissions within the area source category that are expected to
be emitted from major stationary sources. The penetration rate varies according to the major stationary
source size cutoff and, therefore, the ozone nonattainment classification.
4.3.6.2.6 Vehicle Refueling Controls-Stage II Vapor Recovery —
The CAAA and Title I General Preamble include the following specifications for Stage II vapor
recovery programs.
• Stage II is required in serious and above nonattainment areas. Moderate areas must implement
Stage II if onboard is not promulgated, and are also encouraged to implement Stage II
(regardless of whether onboard is promulgated) in order to achieve early reductions. (Onboard
controls require fleet turnover to become fully effective.)
• Stage II must be installed at facilities that sell more than 10,000 gallons of gasoline per month
(the cutoff is 50,000 gallons per month for independent small business marketers). There is
nothing to preclude states from adopting lower source size cutoffs.27
• A study must be conducted to analyze comparable measures in the OTR. Implementation plans
for OTRs must be modified within one year after issuance of the comparability study to include
Stage II or comparable measures.28
• States must prescribe the use of Stage II systems that are certified to achieve at least 95 percent
control of VOC and that are properly installed and operated.29
EPA has issued two guidance documents related to Stage II:
• Technical Guidance - Stage II Vapor Recovery Systems for Control of Vehicle Refueling
Emissions at Gasoline Dispensing Facilities - Volume 1 (EPA-450/3-91-022, November
1991)30
• Enforcement Guidance for Stage II Vehicle Refueling Programs (December 1991 )3!
Table 4.3-26 list the areas with Stage II programs in place as of January 1996.
4.3.6.2.7 New Source Performance Standards —
For new sources subject to NSPS controls, these standards apply regardless of location.32 New
sources in nonattainment areas are also subject to New Source Review (NSR)/offsets. A 100 percent
rule effectiveness is assumed, consistent with that for other VOC stationary source controls.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-59 Industrial
-------
4.3.6.2.8 Title III—
The source categories affected by Title III maximum achievable control technology (MACT)
standards were identified by using EPA's timetable for regulation development under Title III.33
Applicability of the anticipated regulations in various projection years was also derived from this draft
timetable.
Control technology efficiencies were estimated for the expected MACT standards based on available
information. The information used depended on the status of specific standards in their development
timetable. For standards that have already been proposed or promulgated, efficiencies were estimated
using information presented in preambles to the appropriate regulations.
Rule effectiveness was estimated at 100 percent for all Title III standards, in accordance with current
EPA guidelines for rule effectiveness. Rule penetration is not applicable for any of the MACT categories,
since it is included in the average "control technology efficiency" parameter.
4.3.6.3 NOx Controls
For the 1996 emissions, reductions were made in areas of the country that did not put RACT
controls into place until January 1996. Area combustion sources were reduced in 1996 according to the
control efficiencies and rule penetration values listed in Table 4.3-27.
4.3.7 References
1. National Air Pollutant Emission Trends, Procedures Document 1900-1993, EPA-454/R-95-002,
Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research
Triangle Park, NC. December 1994
2. Table SA-5 — Total Personal Income by Major Sources 1969-1990. Data files. Bureau of
Economic Analysis, U.S. Department of Commerce, Washington. DC. 1991.
3. State Energy Data Report — Consumption Estimates 1960-1989, DOE/EIA-0214(89), U.S.
Department of Energy, Energy Information Administration, Washington, DC. May 1991.
4. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC. 1986, 1987, 1988, 1989, 1990, 1991.
5. Dean, T. A. and P. Carlson, PM-10 Controlled Emissions Calculator. E.H. Pechan & Associates,
Inc. Contract No. 68-DO-0120 Work Assignment No. 11-81. Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. April 27, 1993.
(TTN CHIEF BBS)
6. Barnard, W.R., and P. Carlson, PM-10 Emission Calculation, Tables 1 and 4, E.H. Pechan &
Associates, Inc. Contract No. 68-DO-1020, U.S. Environmental Protection Agency, Emission
Factor and Methodologies Section. June 1992.
7. Gill, W., Texas Air Control Board personal communication with D. Solomon. April 23, 1992.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-60 Industrial
-------
8. E.H. Pechan & Associates, Inc., National Assessment ofVOC, CO, and NOx Controls, Emissions,
and Costs, prepared for Office of Policy Planning and Evaluation, U.S. Environmental Protection
Agency. September 1988.
9. Battye, W., Alliance Technologies Corporation, Chapel Hill, NC, Ozone Cost Study Files,
memorandum and computer files to Jim Wilson, E.H. Pechan & Associates, Inc. April 3, 1987.
10. Shedd, S., U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards,
personal communication. November 13, 1991.
1 la. TSDF Inventory File, computer file transferred to E.H. Pechan & Associates, Inc., from Emission
Standards Division, U.S. Environmental Protection Agency, via Alliance Technologies
Corporation, Research Triangle Park, NC. April 1989.
1 Ib. 1985 Hazardous Waste Data Management System, U.S. Environmental Protection Agency, Office
of Solid Waste, Washington, DC. 1985.
lie. (Draft) Background Information Document for Chapter 1-6, Hazardous Waste Treatment,
Storage and Disposal Facilities, U.S. Environmental Protection Agency, Office of Air Quality
Planning and Standards, Emission Standards and Engineering Division, Research Triangle Park,
NC. February 6, 1986.
12. National Air Pollutant Emission Estimates, 1940-1985, U.S. Environmental Protection Agency,
Office of Air Quality Planning and Standards, Research Triangle Park, NC. 1986.
13. Area Source Documentation for the 1985 National Acid Precipitation Assessment Program
Inventory, EPA-600/8-88-106, U.S. Environmental Protection Agency, Air and Energy
Engineering Research Laboratory, Research Triangle Park, NC. December 1988.
14. 1985 Petroleum Supply Annual, DOE/EIA-0340, U.S. Department of Energy, Energy Information
Administration, Office of Oil and Gas, Washington, DC. May 1986.
15. Regional Interim Emission Inventories (1987-1991), Volume I: Development Methodologies,
EPA-454/R-23-021a, U.S. Environmental Protection Agency, Office of Air Quality Planning and
Standards, Research Triangle Park, NC. May 1993.
16. Seitz, John, U.S. Environmental Protection Agency, Research Triangle Park, NC, Memorandum to
State Air Directors. May 5, 1995.
17. An Emission Inventory for Assessing Regional Haze on the Colorado Plateau, Grand Canyon
Visibility Transport Commission, Denver, CO. January 1995.
18. Volatile Organic Compound (VOC)/Particulate Matter (PM) Speciation Data System
(SPECIATE) User's Manual, Version 1.5, Final Report, Radian Corporation, EPA Contract No.
68-DO-0125, Work Assignment No. 60, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. February 1993.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-61 Industrial
-------
19. Internet E-mail from J. Nuovo to J. Better of the Department of Health and Environmental Control
(DHEC), Columbia, South Carolina, entitled Total Suspended Paniculate (TSP)/PM-10 Ratio.
Copy to P. Carlson, E.H. Pechan & Associates, Inc., Durham, NC. April 10, 1997.
20. Telecon. Sharon Kersteter, E.H. Pechan & Associates, Inc., Durham, NC, with Roger Latham,
U.S. Department of Agriculture, Cotton Statistics. March 6, 1997.
21. Cotton Ginnings, PCG, U.S. Department of Agriculture, National Agricultural Statistics Service,
Agricultural Statistics Board, Washington, DC. (13 issues, mailed approximately twice per month
during August-March ginning season)
22. Compilation of Air Pollutant Emissions Factors and Supplements, Fifth Edition and Supplements,
AP-42, U.S. Environmental Protection Agency, Research Triangle Park, NC. 1997.
23. Memorandum. Fred Johnson, National Cotton Council, Memphis, TN, to Bill Mayfield, U.S.
Department of Agriculture, Memphis, TN, Estimated Percent of Crop by Emission Control
Method, July 23, 1996.
24. 55 FR 25454, 1990 Federal Register, Vol. 55, No. 120, p. 25454, Hazardous Waste TSDFs -
Organic Air Emission Standards for Process Vents and Equipment Leaks. June 21,1990.
25. Lacy, Gail. U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards,
Emission Standards Division, personal communication, June 1991.
26. Federal Register, Vol. 55, No. 104, p. 24468, Standards of Performance for New Stationary
Sources and Guidelines for Control of Existing Sources: Municipal Solid Waste Landfills.
May 30, 1991.
27. Public Law 101-549, Clean Air Act Amendments of 1990, Section 182(b)(3). November 15,
1990.
28. Public Law 101-549, Clean Air Act Amendments of 1990, Section 184(b)(2). November 15,
1990.
29. 57 FR 13498, 1992 Federal Register, General Preamble, Implementation of Title I, Clean Air Act
Amendments of 1990. April 16, 1992.
30. Technical Guidance - Stage II Vapor Recovery Systems for Control of Vehicle Refueling
Emissions at Gasoline Dispensing Facilities - Volume 1, EPA-450/3-91-022a, U.S. Environmental
Protection Agency, Office of Air Quality Planning and Standards, Research Triangle Park, NC,
November 1991.
31. Enforcement Guidance for Stage II Vehicle Refueling Programs, U.S. Environmental Protection
Agency, Office of Air and Radiation, Washington, DC, December 1991.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-62 Industrial
-------
sec
Table 4.3-1. SCCs With 100 Percent CO Rule Effectiveness
Process
30300801 Primary Metals Production - Iron Production - Blast Furnaces
30300913 Primary Metals Production -Steel Production - Basic Oxygen Furnace: Open Hood-Stack
30300914 Primary Metals Production -Steel Production - Basic Oxygen Furnace: Closed Hood-Stack
30500401 Mineral Products - Calcium Carbide - Electric Furnace (Hoods and Main Stack)
30600201 Petroleum Industry - Fluid Catalytic Cracking Units
31000205 Oil and Gas Production - Natural Gas Production - Flares
31000299 Oil and Gas Production - Natural Gas Production - Other Not Classified
39000689 In-Process Fuel Use - Natural Gas - General
39000797 In-Process Fuel Use - Process Gas - General
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-63
1985-1996 Methodology
Industrial
-------
Table 4.3-2. July RVPs Used to Model Motor Vehicle Emission Factors
State Reid Vapor Pressure (psi)
State
AL
AZ
AR
CA
CO
CT
DE
DC
FL
GA
ID
IL
IN
IA
KS
KY
LA
ME
MD
MA
Ml
MN
MS
MO
MT
NE
NV
NH
NJ
NM
NY
NC
ND
OH
OK
OR
PA
Rl
SC
SD
TN
TX
UT
VT
VA
WA
WV
Wl
WY
1987
10.8
8.6
10.2
8.6
9.7
10.9
11.3
11.0
10.2
10.5
10.1
11.1
11.6
10.5
9.8
11.3
10.4
10.8
11.2
10.8
11.7
10.5
10.2
10.0
9.3
10.2
8.6
10.8
11.3
9.0
11.2
10.5
10.5
11.6
9.9
9.7
11.4
10.8
10.5
10.5
10.4
9.8
9.7
10.8
10.9
10.8
11.4
11.4
9.5
1988
10.9
8.3
9.8
8.5
9.4
11.0
10.8
10.8
10.5
10.7
9.9
10.6
11.1
10.3
9.6
10.9
11.0
11.0
10.8
11.0
11.0
10.3
9.8
9.7
9.5
9.9
8.5
11.0
10.9
8.5
11.0
10.7
10.3
11.4
9.7
9.4
10.9
11.0
10.7
10.3
10.5
9.6
9.4
11.0
10.8
10.2
11.2
10.9
9.4
1989
8.9
8.2
9.4
8.4
8.7
8.6
9.2
9.1
9.0
8.6
9.5
9.5
9.6
9.7
9.1
9.5
8.6
8.6
9.1
8.6
9.8
9.7
9.4
9.3
9.3
9.4
8.3
8.6
9.0
8.2
8.7
8.6
9.7
9.8
8.7
9.1
9.3
8.6
8.6
9.7
8.8
8.4
8.7
8.6
9.0
9.7
9.6
9.6
9.0
1990
8.5
8.1
8.7
8.1
8.3
8.3
8.4
8.2
9.1
8.5
9.1
8.6
8.7
9.6
8.5
8.7
8.3
8.3
8.3
8.3
9.1
9.6
8.7
8.6
8.6
9.1
8.2
8.3
8.4
8.1
8.3
8.5
9.6
9.6
8.2
8.9
8.6
8.3
8.5
9.6
8.5
8.0
8.3
8.3
8.3
9.6
9.1
8.8
8.4
1991
8.5
8.2
8.5
8.2
8.4
8.3
8.3
8.1
9.1
8.3
9.4
8.8
9.0
9.8
8.6
8.8
8.4
8.3
8.2
8.3
9.3
9.8
8.5
8.6
9.2
9.2
8.3
8.3
8.3
8.1
8.4
8.3
9.8
9.7
8.4
9.0
8.5
8.3
8.3
9.8
8.3
8.2
8.4
8.3
8.1
9.7
9.1
9.0
8.8
Source: Developed from July MVMA Fuel Volatility Surveys
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-64
1985-1996 Methodology
Industrial
-------
Table 4.3-3. 1990 Seasonal RVP (psi) by State
State Winter Spring Summer Fall
AL
AZ
AR
CA
CO
CT
DE
DC
FL
GA
ID
IL
IN
IA
KS
KY
LA
ME
MD
MA
Ml
MN
MS
MO
MT
NE
NV
NH
NJ
NM
NY
NC
ND
OH
OK
OR
PA
Rl
SC
SD
TN
TX
UT
VT
VA
WA
WV
Wl
WY
Source:
12.8
10.1
13.4
12.3
11.5
13.2
13.9
12.2
11.9
12.5
12.5
13.7
13.8
13.4
12.5
12.9
12.2
13.1
13.4
13.1
13.8
13.4
13.4
12.4
13.1
13.0
10.9
13.1
13.8
11.6
13.4
12.5
13.4
13.9
13.1
12.4
13.9
13.1
12.5
13.0
12.7
12.4
11.5
13.1
12.1
13.6
13.5
13.7
12.2
Based on RVPs from
spring and fall.
10.3
8.5
10.7
10.1
9.6
10.2
10.5
9.1
9.1
10.2
10.5
10.5
10.6
11.2
9.5
9.6
10.0
10.1
10.2
10.1
10.9
11.0
10.7
10.7
10.1
10.5
8.8
10.1
10.5
9.0
10.2
11.0
11.8
11.2
9.6
10.4
10.6
10.1
11.0
10.9
11.1
9.9
10.0
10.1
9.1
11.1
10.8
10.7
9.8
the January and July
9.1
8.1
8.7
8.1
8.5
8.3
8.4
8.2
9.1
9.1
9.1
8.6
8.7
10.0
8.5
8.7
8.9
8.3
8.3
8.3
9.1
9.6
9.4
8.6
8.6
9.1
8.2
8.3
8.4
8.1
8.3
9.1
9.6
9.6
8.2
8.8
8.6
8.3
9.1
9.6
9.1
8.0
8.5
8.3
8.2
9.6
9.1
8.8
8.4
MVMA Fuel Volatility Surveys
9.7
8.3
10.9
8.7
9.3
10.2
9.4
9.1
9.1
9.6
9.5
9.6
9.7
11.2
9.0
9.6
9.4
10.1
9.3
10.1
10.9
10.3
10.0
10.2
10.1
9.5
8.5
10.1
10.5
9.3
10.2
10.4
10.9
10.4
8.9
9.6
10.6
10.1
10.4
10.0
10.5
8.6
9.3
10.1
9.1
10.4
9.9
9.7
8.8
interpolated to
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-65 Industrial
-------
Table 4.3-4. Seasonal Maximum and Minimum Temperatures (°F) by State
State
AL
AK
AZ
AR
CA
CO
CT
DE
DC
FL
GA
HI
ID
IL
IN
IA
KS
KY
LA
ME
MD
MA
Ml
MN
MS
MO
MT
NE
NV
NH
NJ
NM
NY
NC
ND
OH
OK
OR
PA
Rl
SC
SD
TN
TX
UT
VT
VA
WA
WV
Wl
WY
Winter
Min Max
42
20
41
32
45
18
19
25
29
52
34
66
25
17
21
15
23
27
44
14
26
25
14
5
36
22
14
15
21
12
25
24
21
32
1
22
28
35
24
22
34
7
31
37
22
11
31
30
26
15
17
62
31
67
53
61
45
36
42
45
72
54
81
40
33
37
31
44
44
64
33
43
38
30
24
59
40
33
35
47
33
43
49
36
54
23
38
50
47
39
38
58
27
50
61
40
28
49
42
44
29
40
Sprinc
Min
57
32
54
50
50
34
38
42
47
62
50
69
37
39
41
39
44
45
59
33
43
41
33
32
53
44
31
40
31
32
41
40
39
48
30
40
48
42
41
38
51
34
50
54
37
33
47
39
43
35
30
1
Max
78
46
83
73
67
61
59
62
66
77
72
83
61
59
62
59
67
66
78
52
64
56
53
51
77
65
54
62
64
56
61
70
57
72
53
61
71
61
61
57
76
56
71
78
62
52
68
57
66
53
54
Summer
Min Max
72
46
76
70
59
56
60
64
68
73
68
73
56
62
63
64
68
66
73
55
65
63
55
56
70
66
52
64
45
54
62
62
61
67
54
61
69
55
62
61
69
59
69
71
58
56
67
53
62
59
52
91
63
103
92
78
85
83
84
86
89
87
87
86
83
84
84
91
86
90
76
85
79
77
78
92
87
80
86
87
80
82
91
81
88
82
82
91
77
83
80
91
84
89
95
89
78
86
76
84
78
80
Fall
Min
58
36
59
51
54
37
42
47
51
65
52
71
39
43
44
42
47
47
60
38
47
48
39
36
53
52
35
42
31
36
46
43
45
51
31
44
50
45
45
44
52
36
51
55
40
39
51
41
45
41
34
Max
79
47
86
75
73
66
63
66
69
82
73
86
64
63
65
63
69
68
79
59
68
62
57
54
78
67
58
65
69
60
66
71
62
73
57
64
73
64
65
63
76
60
73
79
66
57
71
59
67
59
60
U.S. NOAA "Climatology of the United States", 19821:
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-66
1985-1996 Methodology
Industrial
-------
Table 4.3-5. Average Annual Service Station Stage II VOC Emission Factors
Emission Factor
Year
1985
1986
1987
1988
1989
1990
1991
1992
1993
grams/gallon
4.6
4.6
4.6
4.6
3.9
3.6
3.6
3.6
3.6
lbs/1,000
gallons
10.0
10.0
10.0
10.0
8.5
8.0
8.0
8.0
8.0
Table 4.3-6. TSDF Area Source Emissions Removed from the Inventory (1985-1996)
48
45
54
22
13
54
48
01
State
Texas
South Carolina
West Virginia
Louisiana
Georgia
West Virginia
Texas
Alabama
County
071
005
073
047
051
079
039
129
Chambers
Allendale
Pleasants
Iberville
Chatham
Putnum
Brazoria
Washington
VOC Annual
Emissions
372,295
364,227
252,128
100,299
84,327
60,568
59,951
49,296
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-67 Industrial
-------
Table 4.3-7. Bureau of Economic Analysis's SA-5 National Changes
in Earnings by Industry
Percent Growth from:
Industry
Farm
Agricultural services, forestry,
fisheries, and other
Coal mining
Metal mining
Nonmetallic minerals, except fuels
Construction
Food and kindred products
Textile mill products
Apparel and other textile products
Paper and allied products
Printing and publishing
Chemicals and allied products
Petroleum and coal products
Tobacco manufactures
Rubber and miscellaneous plastic
products
Leather and leather products
Lumber and wood products
Furniture and fixtures
Primary metal industries
Fabricated metal products
Machinery, except electrical
Electric and electronic equipment
Transportation equipment,
excluding motor vehicles
Motor vehicles and equipment
Stone, clay, and glass products
Instruments and related products
Miscellaneous manufacturing
industries
Railroad transportation
Trucking and warehousing
Water transportation
Local and interurban passenger
transit
Transportation by air
Pipelines, except natural gas
Transportation services
Communication
Electric, gas, and sanitary services
SIC
01,02
07, 08, 09
11
10
14
15
20
22
23
26
27
28
29
21
30
31
24
25
33
34
35
36
37
371
32
38
39
40
42
44
41
45
46
47
48
49
1985 to 1987
14.67
23.58
-17.46
-3.03
2.33
7.27
1.67
8.50
-1.72
2.62
7.44
1.75
-10.82
-1.97
5.27
-9.39
10.03
6.82
-9.09
-4.72
-5.72
-3.17
8.44
-6.45
-0.23
-0.04
1.84
-14.13
5.63
-8.92
13.45
12.01
-5.21
15.92
1.94
0.07
1987 to 1988
-2.73
5.43
-6.37
18.01
3.74
4.81
1.34
-0.64
1.25
0.94
5.67
6.94
-3.22
2.43
5.51
-1.64
5.15
2.35
5.32
2.55
6.02
-18.01
-1.57
2.20
-1.61
60.65
6.92
-2.53
3.26
0.07
0.51
4.63
3.67
8.52
0.68
3.05
1988 to 1989
14.58
1.01
-4.16
8.94
-2.79
-1.36
-1.20
-1.39
-1.62
-0.14
-0.81
0.32
-3.02
-2.43
0.68
-3.58
-3.54
-1.46
-0.34
-0.86
-0.32
-1.91
0.55
-2.96
-1.96
-0.82
-2.21
-3.83
-0.20
-1.02
2.14
4.94
-4.93
4.60
-2.81
0.63
1989 to 1990
-3.11
2.48
4.73
4.56
-0.45
-3.80
-0.24
-4.97
-4.22
-0.39
0.43
1.61
1.06
-5.01
-0.14
-2.55
-3.71
-2.98
-3.03
-1.91
-1.92
-3.22
-1.07
-5.43
-3.19
-2.91
-2.54
-6.03
0.99
2.83
1.44
4.36
3.53
4.97
2.07
0.39
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-68
1985-1996 Methodology
Industrial
-------
Table 4.3-8. Area Source Growth Indicators
NAPAP
sec
Category Description
Data
Source
Growth Indicator
13 Industrial Fuel - Anthracite Coal SEDS
14 Industrial Fuel - Bituminous Coal SEDS
15 Industrial Fuel - Coke BEA
16 Industrial Fuel - Distillate Oil SEDS
17 Industrial Fuel - Residual Oil SEDS
18 Industrial Fuel - Natural Gas SEDS
19 Industrial Fuel - Wood BEA
20 Industrial Fuel - Process Gas SEDS
21 On-Site Incineration - Residential BEA
22 On-Site Incineration - Industrial BEA
23 On-Site Incineration-Commercial/lnstitutional BEA
24 Open Burning - Residential BEA
25 Open Burning - Industrial BEA
26 Open Burning - Commercial/Institutional BEA
54 Gasoline Marketed SEDS
63 Frost Control - Orchard Heaters BEA
99 Minor Point Sources BEA
100 Publicly Owned Treatment Works BEA
102 Fugitive Emissions From Synthetic Organic BEA
Chemical Manufacturing
103 Bulk Terminal and Bulk Plants BEA
104 Fugitive Emissions From Petroleum Refinery
105 Process Emissions From Bakeries BEA
106 Process Emissions From Pharmaceutical BEA
Manufacturing
107 Process Emissions From Synthetic Fiber BEA
Manufacturing
108 Crude Oil and Natural Gas Production Fields BEA
109 Hazardous Waste Treatment, Storage, and BEA
Disposal Facilities (TSDFs)
Ind - Anthracite
Ind - Bituminous
Total Manufacturing
Ind - Distillate oil
Ind - Residual oil
Ind - Natural gas
Total Manufacturing
Ind - LPG
Population
Total Manufacturing
Services
Population
Total Manufacturing
Services
Trans - Motor gasoline
Farm
Population
Electric, Gas, and Sanitary Services
Mfg - Chemicals and Allied Products
Trucking and Warehousing
Refinery operating cap
Mfg - Food and Kindred Products
Mfg - Chemicals and Allied Products
Mfg - Textile Mill Products
Oil and Gas Extraction
Total Manufacturing
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-69
1985-1996 Methodology
Industrial
-------
Table 4.3-9. SEDS National Fuel Consumption
Category 1985 1986 1987 1988 1989 1990
Anthracite Coal (thousand short tons)
Industrial 575 470 437 434 392 387
Bituminous Coal (thousand short tons)
Industrial 115,854 111,119 111,695 117,729 117,112 118,322
Distillate Fuel (thousand barrels)
Industrial 203,659 206,108 210,699 209,553 197,035 205,856
Liquefied Petroleum Gases (thousand barrels)
Industrial 437,964 411,451 447,120 453,599 441,784 457,013
Motor Gasoline (thousand barrels)
Transportation 2,433,592 2,507,936 2,570,047 2,627,331 2,617,450 2,703,666
All Sectors 2,493,361 2,567,436 2,630,089 2,685,145 2,674,669 2,760,414
Natural Gas (million cubic feet)
Industrial 6,867 6,502 7,103 7,479 7,887 8,120
Residual Fuel (thousand barrels)
Industrial 120,002 132,249 107,116 105,448 95,646 118,122
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-70 Industrial
-------
Table 4.3-10. AMS to NAPAP Source Category Correspondence
AMS
NAPAP
SCC
Category
SCC
Category
Stationary Source Fuel Combustion
2102001000 Industrial-Anthracite Coal (Total: All Boiler
Types)
2102002000 Industrial - Bituminous/Subbituminous Coal
(Total: All Boiler Types)
2102004000 Industrial - Distillate Oil (Total: Boilers & 1C
Engines)
2102005000 Industrial - Residual Oil (Total: All Boiler
Types)
2102006000 Industrial - Natural Gas (Total: Boilers & 1C
Engines)
2102008000 Industrial - Wood (Total: All Boiler Types)
2102009000 Industrial - Coke (Total: All Boiler Types)
2102010000 Industrial - Process Gas (Total: All Boiler
Types)
Industrial Processes
2301020000 Process Emissions from Pharmaceuticals
(PECHAN)
2301030000 Process Emissions from Synthetic Fiber
(PECHAN)
2301040000 SOCMI Fugitives (PECHAN)
2302050000 Food & Kindred Products: SIC 20 - Bakery
Products (Total)
2306000000 Petroleum Refining: SIC 29 - All Processes
(Total)
2310000000 Oil & Gas Production: SIC 13 - All
Processes (Total)
2399000000 Industrial Processes: NEC
13 Industrial Fuel - Anthracite Coal
14 Industrial Fuel - Bituminous Coal
16 Industrial Fuel-Distillate Oil
17 Industrial Fuel - Residual Oil
18 Industrial Fuel - Natural Gas
19 Industrial Fuel-Wood
15 Industrial Fuel - Coke
20 Industrial Fuel - Process Gas
106 Process Emissions from
Pharmaceutical Manufacturing
107 Process Emissions from
Synthetic Fibers Manufacturing
102 Fugitive Emissions From
Synthetic Organic Chemical
Manufacturing
105 Process Emissions From
Bakeries
104 Fugitive Emissions From
Petroleum Refinery Operations
108 Crude Oil and Natural Gas
Production Fields
99 Minor point sources
Storage & Transport
2501050120 Petroleum & Petroleum Product Storage -
Bulk Stations/Terminals: Breathing Loss
(Gasoline)
2501060050 Petroleum & Petroleum Product Storage -
Gasoline Service Stations (Stage I: Total)
2501060100 Petroleum & Petroleum Product Storage -
Gasoline Service Stations (Stage II: Total)
2501060201 Petroleum & Petroleum Product Storage -
Gasoline Service Stations (Underground
Tank: Breathing & Emptying)
103 Bulk Terminal and Bulk Plants
54 Gasoline Marketed (Stage I)
54 Gasoline Marketed (Stage II)
54 Gasoline Marketed (Breathing &
Emptying)
(continued)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-71
1985-1996 Methodology
Industrial
-------
Table 4.3-10 (continued)
AMS
NAPAP
SCC
Category
SCC
Category
Waste Disposal, Treatment, & Recovery
2601010000 On-Site Incineration - Industrial (Total) 22
2601020000 On-Site Incineration - 23
Commercial/Institutional (Total)
2601030000 On-Site Incineration - Residential (Total) 21
2610010000 Open Burning - Industrial (Total) 25
2610020000 Open Burning - Commercial/Institutional 26
(Total)
2610030000 Open Burning - Residential (Total) 24
2630020000 Wastewater Treatment - Public Owned 100
(Total)
2640000000 TSDFs - All TSDF Types (Total: All 109
Processes)
On-Site Incineration - Industrial
On-Site Incineration -
Commercial/Institutional
On-Site Incineration - Residential
Open Burning - Industrial
Open Burning - Commercial/Institutional
Open Burning - Residential
Publicly-Owned Treatment Works
(POTWs)
Hazardous Waste Treatment, Storage,
and Disposal Facilities (TSDF)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-72
1985-1996 Methodology
Industrial
-------
Table 4.3-11. Point Source Data Submitted
State
Alabama
Arkansas
Connecticut
Delaware
District of Columbia
Florida
Georgia - Atlanta
Urban Airshed (47
counties) domain
Georgia - Rest of
State
Illinois
Indiana
Kansas
Kentucky - Jefferson
County
Kentucky - Rest of
State
Louisiana
Maine
Maryland
Massachusetts
Michigan
Minnesota
Missouri
Nebraska
New Hampshire
New Jersey
New York
North Carolina
North Dakota
Ohio
Oklahoma
Pennsylvania -
Allegheny County
Pennsylvania -
Philadelphia County
Pennsylvania - Rest
of State
Rhode Island
South Carolina
Data Source/Format
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - EPS Workfile
State - EPS Workfile
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State format
AIRS-AFS - Ad hoc retrievals
State - EPS Workfiles
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
Jefferson County - EPS Workfile
State - EPS Workfile
State - State Format
State - EPS Workfile
State - EPS Workfile
State - EPS Workfile
State - State Format
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - EPS Workfile
State - EPS Workfile
State - EPS Workfile
State - EPS Workfiles
AIRS-AFS - Ad hoc retrievals
State - State Format
State - State Format
Allegheny County - County Format
Philadelphia County - County Format
State - EPS Workfile
State - EPS Workfile
AIRS-AFS - Ad hoc retrievals
Temporal
Resolution
Annual
Annual
Daily
Daily
Annual
Annual
Daily
Annual
Daily
Annual
Annual
Daily
Daily
Annual
Daily
Daily
Daily
Annual
Annual
Annual
Annual
Daily
Daily
Daily
Daily
Annual
Annual
Annual
Daily
Daily
Daily
Daily
Annual
Year of Data
1994
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1993
1990
1990
1990
1990
1990
1990
1990
1994
1990
1990
1990
1990
1991
Adjustments to Data
Backcast to 1990 using BEA. Average Summer
Day estimated using methodology described above.
Average Summer Day estimated using default
temporal factors.
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
None
Average Summer Day estimated using default
temporal factors.
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
None
None
Average Summer Day estimated using methodology
described above.
None
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
Backcast to 1990 using BEA. Average Summer
Day estimated using methodology described above.
Average Summer Day estimated using methodology
described above.
None
None
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
Backcast to 1990 using BEA. Average Summer
Day estimated using methodology described above.
None
None
None
None
Average Summer Day estimated using default
temporal factors.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-73
1985-1996 Methodology
Industrial
-------
Table 4.3-11 (continued)
Temporal
South Dakota AIRS-AFS -Ad hoc retrievals
Tennessee AIRS-AFS - Ad hoc retrievals
Texas State - State Format
Vermont State - EPS Workfile
Virginia AIRS-AFS -Ad hoc retrievals
West Virginia AIRS-AFS -Ad hoc retrievals
Wisconsin State - State Format
Annual 1990 Average Summer Day estimated using methodology
described above.
Annual 1990 Average Summer Day estimated using default
temporal factors.
Daily 1992 Backcast to 1990 using BEA.
Daily 1990 None
Annual 1990 Average Summer Day estimated using methodology
described above.
Annual 1990 Average Summer Day estimated using methodology
described above.
Daily _ 1990 None _
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-74
1985-1996 Methodology
Industrial
-------
Table 4.3-12. Area Source Data Submitted
State
Connecticut
Delaware
District of Columbia
Florida
Georgia
Data Source/Format
State - EPS Workfile
State - EPS Workfile
State - Hard copy
AIRS-AMS - Ad hoc retrievals
State - State format
Temporal
Resolution
Daily
Daily
Daily
Daily
Daily
Geoaraohic Coveraae
Entire State
Entire State
Entire State
Jacksonville, Miami/
Ft. Lauderdale, Tampa
Atlanta Urban Airshed
Adjustments to Data
None
None
None
Added Non-road emission estimates
from Int. Inventory to Jacksonville
(Duval County)
None
Illinois State - State format Daily
Indiana State - State format Daily
Kentucky State - State Format Daily
Louisiana State - State Format Daily
Maine State - EPS Workfile Daily
Maryland State - EPS Workfile Daily
Michigan State - State Format Daily
Missouri AIRS-AMS-Ad hoc retrievals Daily
New Hampshire State - EPS Workfile Daily
New Jersey State - EPS Workfile Daily
New York State - EPS Workfile Daily
North Carolina State - EPS Workfiles Annual
Ohio State - Hard copy Daily
Pennsylvania State - EPS Workfile Daily
Rhode Island State - EPS Workfile Daily
Tennessee State - State format Daily
Texas State - State Format Annual
Vermont State - EPS Workfile Daily
Virginia State - EPS Workfile Daily
West Virginia AIRS-AMS - Ad hoc retrievals Daily
Wisconsin State - State Format Daily
(47 Counties)
Entire State
Entire State
Kentucky Ozone Nonattainment
Areas
Baton Rouge Nonattainment
Area (20 Parishes)
Entire State
Entire State
49 Southern Michigan Counties
St. Louis area (25 counties)
Entire State
Entire State
Entire State
Entire State
Canton, Cleveland Columbus,
Dayton, Toledo, and Youngstown
Entire State
Entire State
42 Counties in Middle
Tennessee
Entire State
Entire State
Entire State
Charleston, Huntington/Ashland,
and Parkersburg (5 counties
total)
Entire State
None
Non-road emissions submitted were
county totals. Non-road emissions
distributed to specific SCCs based
on Int. Inventory
None
None
None
None
None
Only area source combustion data
was provided. All other area source
data came from Int. Inventory
None
None
None
Average Summer Day estimated
using default temporal factors.
Assigned SCCs and converted from
kgs to tons. NOX and CO from Int.
Inventory added to Canton, Dayton,
and Toledo counties.
Non-road emissions submitted were
county totals. Non-road emissions
distributed to specific SCCs based
on Int. Inventory
None
No non-road data submitted. Non-
road emissions added from Int.
Inventory
Average Summer Day estimated
using default temporal factors.
None
None
None
None
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-75
1985-1996 Methodology
Industrial
-------
Table 4.3-13. Ad Hoc Report
Criteria
Regn
DLL4
DLL4
DLL4
DLL4
DLL4
DLL4
DES4
DUE4
VI NV
GTO
CEVOC
CECO
CESO2
CE NO2
CE PM-10
CE PT
GEO
VIETY
VIE 90
Plant Output
VINV
SITE
CNTY
CYCD
7IPC
DNED
DNME
LAT1
_ON1
SIC1
OPST
SIRS
YEAR OF INVENTORY
STATE F I PS CODE
COUNTY FIPS CODE
CITY CODE
ZIP CODE
MEDS POINT ID
DLANT NAME
LATITUDE PLANT
_ONGITUDE PLANT
STANDARD INDUSTRIAL
CODE
OPERATING STATUS
STATE REGISTRATION
MUMBER
Point Output
STTE
CNTY
PNED
DNUM
CAPC
CAPU
DAT1
DAT2
DAT3
DAT4
MOHD
MODW
MOHY
STATE FIPS CODE
COUNTY FIPS CODE
NEDS POINT ID
DOINT NUMBER
DESIGN CAPACITY
DESIGN CAPACITY
UNITS
WINTER
THROUGHPUT
SPRING
THROUGHPUT
SUMMER
THROUGHPUT
-ALL THROUGHPUT
MUMBER HOURS/DAY
MUMBER DAYS/WEEK
MUMBER
HOURS/YEAR
Stack Output
STTE
CNTY
PNED
STNB
_AT2
_ON2
STHT
STDM
STET
STEV
STFR
DLHT
STATE FIPS CODE
COUNTY FIPS CODE
NEDS POINT ID
STACK NUMBER
_ATITUDE STACK
LONGITUDE STACK
STACK HEIGHT
STACK DIAMETER
STACK EXIT
TEMPERATURE
STACK EXIT VELOCITY
STACK FLOW RATE
DLUME HEIGHT
Segment Output
General
STTE
CNTY
DNED
STNB
DNUM
SEGN
SCC8
HEAT
ZPRT
SULF
^SHC
DODP
STATE FIPS CODE
COUNTY FIPS CODE
MEDS POINT ID
STACK NUMBER
DOINT NUMBER
SEGMENT NUMBER
sec
HEAT CONTENT
^NNUALFUEL
THROUGHPUT
SULFUR CONTENT
ASH CONTENT
DEAK OZONE
SEASON DAILY
DROCESS RATE
Segment Output
Pollutant
STTE
CNTY
DNED
STNB
DNUM
SEGN
SCC8
DLL4
D034
DU04
DES4
DUE4
CLEE
CLT1
CTL2
REP4
DME4
Emfa
STATE FIPS CODE
COUNTY FIPS CODE
MEDS POINT ID
STACK NUMBER
DOINT NUMBER
SEGMENT NUMBER
sec
DOLLUTANT CODE
OSD EMISSIONS
OSD EMISSION
UNITS
DEFAULT
ESTIMATED
EMISSIONS
DEFAULT
ESTIMATED
EMISSIONS UNITS
CONTROL
EFFICIENCY
DRIMARY CONTROL
DEVICE CODE
SECONDARY
CONTROL DEVICE
CODE
RULE
EFFECTIVENESS
VIETHODCODE
Emission factor
-------
Table 4.3-14. SEDS National Fuel Consumption, 1990-1996 (trillion Btu)
Fuel Tvoe End-User
Code
1990
1991
1992
1993
1994
1995
1996
Anthracite Coal
Commercial
Electric utility
Industrial
Residential
ACCCB
ACEUB
ACICB
ACRCB
12
17
10
19
11
16
8
17
11
17
7
17
11
16
11
16
11
15
10
16
11
15
10
16
11
15
10
16
Bituminous Coal
Distillate
Distillate
Commercial
Electric utility
Industrial
Residential
Fuel
Commercial
Industrial
Residential
Total
BCCCB
BCEUB
BCICB
BCRCB
DFCCB
DFICB
DFRCB
DFTCB
Fuel including Kerosene jet
Electric utility
DKEUB
80
16,071
2,744
43
487
1,181
837
6,422
fuel
86
15,
2,
1,
6,
72
997
592
39
482
139
832
210
80
75
16,175
2,505
40
464
1,144
865
6,351
67
72
16,825
2,489
40
464
1,100
913
6,466
77
70
16,995
2,434
40
450
1,090
887
6,417
64
17,
2,
1,
6,
69
,164
,379
39
435
,080
862
,368
58
68
17,333
2,333
39
422
1,071
836
6,319
54
Kerosene
Commercial
Industrial
Residential
Total
KSCCB
KSICB
KSRCB
KSTCB
12
12
64
88
12
11
72
96
11
10
65
86
14
13
76
103
13
10
67
89
12
9
59
76
11
9
51
65
Liquid Petroleum Gas
Commercial
Industrial
Residential
Total
LGCCB
LGICB
LGRCB
LGTCB
64
1,608
365
2,059
1,
2,
69
749
389
227
67
1,860
382
2,328
70
1,794
399
2,282
70
1,804
398
2,290
1,
2,
70
,813
397
,298
70
1,823
397
2,306
Natural Gas
Residual
Commercial
Electric utility
Industrial
Residential
Total
Fuel
Commercial
Electric utility
Industrial
Total
NGCCB
NGEUB
NGICB
NGRCB
NGTCB
RFCCB
RFEUB
RFICB
RFTCB
2,698
2,861
8,520
4,519
19,280
233
1,139
417
2,820
2,
2,
8,
4,
19,
1,
2,
808
854
637
685
605
213
076
336
657
2,884
2,829
8,996
4,821
20,139
191
854
391
2,518
2,996
2,744
9,387
5,097
20,868
175
939
452
2,479
3,035
2,720
9,635
5,132
21,164
170
823
459
2,346
3,
2,
9,
5,
21,
2,
,074
,698
,883
,166
,461
168
726
469
,213
3,114
2,675
10,131
5,201
21,757
167
650
481
2,080
Population
TPOPP
248,709
252,
131
255,025
257,785
259,693
261.
,602
263,510
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-77
1985-1996 Methodology
Industrial
-------
Table 4.3-15. BEA SA-5 National Earnings by Industry, 1990-1996 (million $)
Industry
LNUM
SIC
1990 1991 1992 1993 1994 1995 1996
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Farm
Farm
Farm
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Metal mining
Coal mining
Oil and gas extraction
Nonmetallic minerals, except fuels
Construction
Construction
Construction
Construction
Manufacturing
Durable goods
Lumber and wood products
Furniture and fixtures
Stone, clay, and glass products
Primary metal industries
Fabricated metal products
Machinery, except electrical
Electric and electronic equipment
Motor vehicles and equipment
Transportation equipment, excluding motor vehicles
Instruments and related products
Miscellaneous manufacturing industries
Nondurable goods
Food and kindred products
Tobacco manufactures
Textile mill products
Apparel and other textile products
Paper and allied products
Printing and publishing
Chemicals and allied products
Petroleum and coal products
Rubber and miscellaneous plastic products
020
030
040
041
045
046
047
050
060
070
071
072
081
082
090
100
110
120
121
122
123
200
210
220
230
240
300
310
320
330
400
410
413
417
420
423
426
429
432
435
438
441
444
450
453
456
459
462
465
468
471
474
477
999
999
999
999
999
999
999
999
999
999
999
999
1,2
1,2
1,2
7-9
7-9
7-9
7-9
7-9
7-9
7-9
10
11, 12
13
14
15-17
15-17
15-17
15-17
998
996
24
25
32
33
34
35
36
371
37
38
39
997
20
21
22
23
26
27
28
29
30
0
1
3,634
238
3,395
971
735
2,932
321
381
34
347
48
3,586
3,001
24
20
4
1
2
1
36
2
8
20
4
218
54
29
135
710
437
22
13
20
33
51
86
63
41
54
43
11
273
51
3
16
20
28
54
61
9
27
0
1
3,593
242
3,350
947
791
2,891
331
370
28
342
41
3,552
2,957
24
20
3
1
2
1
37
3
8
22
4
197
47
28
123
690
418
21
12
18
30
48
83
62
38
52
42
11
111
51
3
16
20
27
54
63
9
26
0
1
3,732
248
3,483
907
858
2,975
351
405
34
372
46
3,686
3,079
24
21
3
1
2
1
36
3
8
21
4
195
46
28
121
705
423
22
13
19
31
49
83
62
42
50
42
11
281
52
3
17
20
28
55
66
10
28
0
1
3,785
253
3,531
914
888
3,003
371
410
32
378
45
3,740
3,126
24
22
3
0
2
1
34
2
6
21
4
199
47
27
125
705
424
22
13
19
30
49
84
63
46
45
40
12
282
52
2
17
19
28
56
65
9
29
0
1
3,891
265
3,626
934
912
3,082
383
426
29
396
42
3,849
3,228
26
23
3
1
2
1
35
2
6
21
4
216
51
29
136
725
440
24
14
20
32
51
86
65
53
43
40
12
285
53
2
17
19
29
57
65
10
30
0
1
4,011
273
3,737
980
951
3,182
394
436
18
418
31
3,980
3,353
27
24
3
1
2
1
35
2
6
21
4
219
51
29
138
740
452
25
14
20
33
53
90
68
56
42
40
12
288
53
3
17
19
29
58
67
9
31
0
1
4,086
280
3,805
981
994
3,231
408
447
16
432
29
4,058
3,423
27
25
3
1
1
1
35
3
6
21
4
219
50
29
139
747
456
25
14
20
32
53
91
69
60
39
39
12
291
54
3
17
19
29
59
68
9
31
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-78
1985-1996 Methodology
Industrial
-------
Table 4.3-15 (continued)
Industry
LNUM
SIC
1990 1991 1992 1993 1994 1995 1996
Leather and leather products
Leather and leather products
Railroad transportation
Trucking and warehousing
Water transportation
Water transportation
Local and interurban passenger transit
Transportation by air
Pipelines, except natural gas
Transportation services
Communication
Electric, gas, and sanitary services
Wholesale trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Banking and credit agencies
Banking and credit agencies
Banking and credit agencies
Insurance
Insurance
Real estate
Holding companies and investment services
Services
Hotels and other lodging places
Personal services
Private households
Business and miscellaneous repair services
Auto repair, services, and garages
Auto repair, services, and garages
Amusement and recreation services
Amusement and recreation services
Health services
Legal services
Educational services
Social services and membership organizations
Social services and membership organizations
Social services and membership organizations
Social services and membership organizations
Miscellaneous professional services
Government and government enterprises
Federal, civilian
Federal, military
State and local
State and local
State and local
480
500
510
520
530
540
541
542
543
544
560
570
610
620
621
622
623
624
625
626
627
628
700
710
730
731
732
733
734
736
800
805
810
815
820
825
830
835
840
845
850
855
860
865
870
875
880
900
910
920
930
931
932
31
31
40
42
44
44
41
45
46
47
48
49
50,51
52-59
52-59
52-59
52-59
52-59
52-59
52-59
52-59
52-59
52-59
60,61
60,61
60,61
63,64
63,64
65,66
62,67
995
70
72
88
76
75
75
78,79
78,79
80
81
82
83,86
83,86
83,86
83,86
84, 87, 89
995
43,91,97
992
92-96
92-96
92-96
3
243
12
59
7
48
8
30
1
12
63
49
236
342
18
40
56
55
18
22
76
57
246
82
163
38
56
34
28
8
946
31
33
10
170
29
15
29
16
290
80
39
29
1
35
125
14
585
118
50
417
125
292
3
245
12
58
7
49
8
30
1
13
63
52
231
335
18
38
56
54
18
20
78
54
247
81
166
40
59
33
25
10
951
31
32
9
162
28
13
30
16
304
80
41
31
1
36
121
14
594
120
50
425
128
297
2
251
13
60
7
50
9
31
1
14
64
53
238
342
18
39
57
54
18
19
80
57
280
86
194
50
61
33
36
14
1,008
32
33
10
175
28
13
34
16
325
85
42
34
1
36
127
15
607
123
51
433
128
305
3
260
12
62
6
51
9
31
1
14
67
56
235
347
19
39
56
56
18
19
82
57
290
89
201
53
62
34
43
10
1,032
33
36
10
180
30
14
33
17
330
84
44
35
1
38
130
15
613
124
48
441
130
311
3
269
12
66
6
50
9
31
1
15
71
56
242
359
20
40
57
60
18
21
85
59
291
89
202
51
63
36
44
9
1,066
33
36
10
191
31
14
35
18
341
84
45
38
2
40
132
17
621
125
45
451
134
317
2
277
12
69
6
52
10
31
1
16
75
56
255
372
21
41
58
62
18
22
88
62
302
90
212
55
63
37
47
10
1,128
35
36
11
213
33
15
37
20
355
85
46
40
2
41
141
18
626
123
44
459
136
323
2
283
12
71
6
53
10
31
1
17
78
57
258
378
21
41
58
64
18
22
90
63
313
91
221
58
65
38
51
10
1,164
36
37
11
221
34
15
39
20
368
86
48
42
2
42
145
19
635
124
43
468
138
330
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-79
1985-1996 Methodology
Industrial
-------
Table 4.3-16. Area Source Listing by SCC and Growth Basis
sec
FILE
CODE'
SCC
FILE
CODE
SCC
FILE
CODE
SCC
FILE
CODE
SCC
FILE
CODE
2101002000
2101004001
2101004002
2101006001
2101006002
2102001000
2102002000
2102004000
2102005000
2102006000
2102006001
2102006002
2102007000
2102008000
2102010000
2102011000
2103001000
2103002000
2103004000
2103005000
2103006000
2103007000
2103008000
2103011000
2104001000
2104002000
2104004000
2104005000
2104006000
2104007000
2104008000
2104008001
2104008010
2104008030
2104008050
2104008051
2104011000
2110030000
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
SEDS
SEDS
SEDS
SEDS
NG
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
NG
ACEUB
DKEUB
DKEUB
NGEUB
NGEUB
ACICB
BCICB
DFICB
RFICB
NGICB
NGICB
NGICB
LGICB
400
LGICB
KSICB
ACCCB
BCCCB
DFCCB
RFCCB
NGCCB
LGCCB
400
KSCCB
ACRCB
BCRCB
DFRCB
NGRCB
LGRCB
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
KSRCB
2199005000
2199006000
2199007000
2199011000
2260000000
2260001000
2260001010
2260001020
2260001030
2260001050
2260001060
2260002000
2260002006
2260002009
2260002021
2260002033
2260003000
2260003010
2260003020
2260003030
2260003040
2260004000
2260004010
2260004015
2260004020
2260004025
2260004030
2260004035
2260004050
2260004075
2260005000
2260006000
2260006005
2260006010
2260006015
2260006020
2260007000
2260007005
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
RFTCB
NGTCB
LGTCB
KSTCB
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
300
300
300
300
300
400
400
400
400
400
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
81
400
400
400
400
400
100
100
2260008010
2265000000
2265001000
2265001010
2265001030
2265001040
2265001050
2265001060
2265002000
2265002003
2265002006
2265002009
2265002015
2265002021
2265002024
2265002027
2265002030
2265002033
2265002039
2265002042
2265002045
2265002054
2265002057
2265002060
2265002066
2265002072
2265002078
2265002081
2265003000
2265003010
2265003020
2265003030
2265003040
2265003050
2265004000
2265004010
2265004015
2265004025
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
SEDS
SEDS
542
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
400
400
400
400
400
400
TPOPP
TPOPP
TPOPP
TPOPP
2265004035
2265004040
2265004045
2265004050
2265004055
2265004060
2265004065
2265004070
2265004075
2265005000
2265005010
2265005015
2265005020
2265005030
2265005035
2265005040
2265005045
2265005050
2265005055
2265006000
2265006005
2265006010
2265006015
2265006025
2265006030
2265007000
2265007010
2265008000
2265008005
2265008010
2270000000
2270001000
2270001010
2270001050
2270001060
2270002000
2270002003
2270002009
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
81
81
81
81
81
81
81
81
81
81
400
400
400
400
400
400
100
100
542
542
542
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
300
300
300
2270002015
2270002018
2270002021
2270002027
2270002030
2270002033
2270002036
2270002039
2270002042
2270002045
2270002048
2270002051
2270002054
2270002057
2270002060
2270002063
2270002066
2270002069
2270002072
2270002075
2270002078
2270002081
2270003000
2270003010
2270003020
2270003030
2270003040
2270003050
2270004000
2270004010
2270004040
2270004055
2270004060
2270004065
2270004070
2270004075
2270005000
2270005015
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
300
400
400
400
400
400
400
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
81
81
-------
Table 4.3-16 (continued)
sec
FILE CODE'
SCC
FILE
CODE
SCC
FILE
CODE
SCC
FILE
CODE
SCC
FILE
CODE
2199004000
2270005025
2270005035
2270005045
2270005050
2270005055
2270006000
2270006005
2270006010
2270006015
2270006025
2270006030
2270007000
2270007015
2270007020
2270008000
2270008005
2270008010
2275000000
2275001000
2275020000
2275020021
2275050000
2275060000
2275070000
2275900000
2275900101
2275900102
2280000000
2280001000
2280002000
2280002010
2280002020
2280002040
2280003000
2280003010
2280003020
2280003030
2280004020
2282000000
2501050000
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
BEA
DFTCB
81
81
81
81
81
400
400
400
400
400
400
100
100
100
542
542
542
542
920
542
542
542
542
542
542
542
542
530
530
530
530
530
530
530
530
530
530
530
TPOPP
610
2260008000
2282005000
2282005010
2282005015
2282005025
2282010000
2282010005
2282010010
2282010015
2282010020
2282010025
2282020000
2282020005
2282020010
2282020020
2282020025
2283002000
2285000000
2285002000
2285002005
2285002010
2301000000
2301010000
2301020000
2301030000
2301040000
2302000000
2302002000
2302010000
2302050000
2302070000
2302070001
2302070005
2302070010
2303020000
2304000000
2304050000
2305000000
2305070000
2306000000
2501995000
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
542
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
920
510
510
510
510
471
471
471
471
471
453
453
453
453
453
453
453
453
423
423
423
240
240
474
230
2265004030
2306010000
2308000000
2309000000
2309100230
2310000000
2310010000
2310020000
2312000000
2325030000
2390004000
2390005000
2390006000
2390007000
2390010000
2399000000
2401000000
2401001000
2401002000
2401005000
2401008000
2401015000
2401020000
2401025000
2401030000
2401035000
2401040000
2401045000
2401045999
2401050000
2401055000
2401060000
2401065000
2401070000
2401075000
2401080000
2401085000
2401090000
2401100000
2401200000
2601020000
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
NG
BEA
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
TPOPP
474
477
426
426
230
230
230
429
210
400
400
400
400
400
400
TPOPP
TPOPP
825
TPOPP
413
417
417
465
477
426
426
426
426
429
432
432
435
438
438
438
444
400
400
570
2270002012
2401990000
2415000000
2415000385
2415000999
2415035000
2415045000
2415065000
2415100000
2415105000
2415110000
2415120000
2415125000
2415130000
2415135000
2415140000
2415145000
2415200000
2415230000
2415245000
2415260000
2415300000
2415305000
2415310000
2415315000
2415320000
2415325000
2415330000
2415335000
2415340000
2415345000
2415350000
2415355000
2415360000
2415365000
2420000000
2420000055
2420000370
2420000999
2420010000
2810015000
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
300
400
400
400
400
438
444
413
400
417
423
426
429
432
438
441
444
438
432
444
825
438
417
423
423
426
429
432
438
441
444
510
620
825
820
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
2270005020
2420010055
2420010370
2420010999
2420020000
2420020055
2425000000
2425000999
2425010000
2425030000
2425040000
2430000000
2440000000
2440000999
2440020000
2460000000
2460000385
2461000000
2461020000
2461021000
2461022000
2461023000
2461050000
2461160000
2461600000
2461800000
2461850000
2465000000
2465100000
2465200000
2465400000
2465600000
2465800000
2465900000
2500000000
2501000000
2501000030
2501000090
2501000150
2501010000
2495000000
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
NG
BEA
BEA
BEA
BEA
BEA
SEDS
81
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
820
820
820
820
820
477
444
444
444
TPOPP
TPOPP
300
300
300
300
300
300
300
300
300
300
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
230
230
230
230
230
TPOPP
-------
Table 4.3-16 (continued)
sec
FILE CODE'
SCC
FILE
CODE
SCC
FILE
CODE
SCC
FILE
CODE
SCC
FILE
CODE
2501050030
2501050060
2501050090
2501050120
2501050150
2501050180
2501060000
2501060050
2501060051
2501060052
2501060053
2501060100
2501060101
2501060102
2501060103
2501060200
2501060201
2501070000
2501070051
2501070052
2501070101
2501070103
2501070201
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
610
610
610
610
610
610
620
620
620
620
620
620
620
620
620
620
620
620
620
620
620
620
620
2501995030
2501995060
2501995090
2501995120
2501995150
2501995180
2505000000
2505000120
2505010120
2505020000
2505020030
2505020060
2505020090
2505020120
2505020150
2505020180
2505020900
2505030000
2505030120
2510000000
2510995000
2601000000
2601010000
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
230
230
230
230
230
230
474
474
474
474
474
474
474
474
474
474
474
474
474
471
471
570
570
2601030000
2610000000
2610010000
2610020000
2610030000
2620000000
2620030000
2630000000
2630010000
2630020000
2630030000
2640000000
2640000001
2640000004
2640010001
2640010004
2660000000
2801000005
2801500000
2810001000
2810003000
2810005000
2810010000
BEA
BEA
BEA
BEA
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
NG
SEDS
BEA
BEA
570
570
570
570
TPOPP
570
570
570
570
570
570
570
570
570
570
570
570
100
100
TPOPP
100
100
2810025000
2810030000
2810035000
2810050000
2810060000
2830000000
2830001000
2850000010
2102009000
2275085000
2280004000
2294000000
2296000000
2302080000
2307060000
2309100010
2310030000
2311000100
2325000000
2401010000
2415045999
2415060000
2461800999
SEDS
SEDS
SEDS
SEDS
SEDS
NG
NG
NG
BEA
BEA
BEA
NG
NG
BEA
BEA
BEA
BEA
NG
NG
BEA
BEA
BEA
SEDS
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
400
542
530
453
413
426
230
459
400
400
TPOPP
2505010000
2710020030
2730050000
2730100000
2801000003
2801520000
2801700001
2801700002
2801700003
2801700004
2801700005
2801700006
2801700007
2801700008
2801700009
2801700010
2805000000
2805001000
2805020000
2805025000
2805030000
2805040000
2805045001
BEA
BEA
NG
NG
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
474
81
81
81
81
81
81
81
81
81
81
81
81
81
81
81
81
81
81
81
81
NOTE(S): * BEA Code is equal to LNUM on previous table.
-------
Table 4.3-17. Emission Estimates Available from AIRS/FS by State, Year, and Pollutant
State
1990
C N S P T V
1991
C N S P T V
1992
C N S P T V
1993
C N S P T V
1994
C N S P T V
1995
C N S P T V
Alabama
Alaska
Arizona
California
Colorado
Connecticut
Hawaii
Illinois
Louisiana
Michigan
Minnesota
Montana
Nebraska
Nevada
New Hampshire
New Mexico
North Dakota
Oregon
Pennsylvania
South Carolina
South Dakota
Texas
Utah
Vermont
Virginia
Washington
Wisconsin
Wyoming
Notes:
C = CO N = NO2 S = SO2 P = PM-10 T = TSP V = VOC
Pennsylvania only includes Allegheny County (State 42, County 003); New Mexico only includes Albuquerque (State 35, County 001); Washington only includes Puget
Sound (State 53, County 033, 053, or 061); Nebraska includes all except Omaha City (State 31, County 055); the CO emissions in NET were maintained for South Dakota
(State 46).
-------
Table 4.3-18. NOX and VOC Major Stationary Source Definition
Ozone Nonattainment Status
Major Stationary Source (tons)
Marginal/Moderate
Serious
Severe
Extreme
Ozone Transport Region
100
50
25
10
50
Table 4.3-19. Summary of Revised NOX Control Efficiencies
Pod
ID
55
58
59
60
70
71
72
73
74
75
76
77
84
85
86
87
88
89
90
Pod Name
Industrial Process Heat
Commercial/Institutional - Coal
Commercial/Institutional - Oil
Commercial/Institutional - Gas
Industrial Oil Fired Turbines
Industrial Oil Fired Reciprocating Engines
Industrial Gas Fired Turbines
Industrial Gas Fired Reciprocating Engines
Utility Oil Fired Turbines
Utility Oil Fired Reciprocating Engines
Utility Gas Fired Turbines
Utility Gas Fired Reciprocating Engines
Industrial External Combustion - Coal
Industrial External Combustion - Oil - < 100 MMBtu/hr
Industrial External Combustion - Oil -Cogeneration
Industrial External Combustion - Oil -General
Industrial External Combustion - Gas - < 100 MMBtu/hr
Industrial External Combustion - Gas - Cogeneration
Industrial External Combustion - Gas - General
Estimated Efficiency
74
50
50 H
50
70
25
84 H
30
70
25
84 H
30
50
50
50 H
50
50
50
.50
Control
ULNB
LNB
LNB
LNB
Wl
IR
LNB
AF+IR
Wl
IR
LNB
AF + IR
LNB
LNB
LNB
LNB
LNB
LNB
LNB
Reference
ACT(EPA,1993d)
ACT(EPA,1993e)
ACT(EPA,1993e)
ACT(EPA,1993e)
ACT(EPA,1993f)
ACT(EPA,1993g)
ACT(EPA,1993f)
ACT(EPA,1993g)
ACT(EPA,1993f)
ACT(EPA,1993g)
ACT(EPA,1993f)
ACT(EPA,1993g)
ACT(EPA,1993e)
ACT(EPA,1993e)
ACT(EPA,1993e)
ACT(EPA,1993e)
ACT(EPA,1993e)
ACT(EPA,1993e)
ACT(EPA,1993e)
Controls: AF - Air/Fuel Adjustment ULNB -
IR - Ignition Time Retardation Wl
LNB - Low NOV Burner
Ultra-low NOX Burner
- Water Injection
-------
Table 4.3-20. Cotton Ginning Emission Factors
22
Control Type
Full controls (high-efficiency cyclone)
Conventional controls (screened drums or
cages)
Total PM
(Ib/bale)
2.4
3.1
PM-10
(Ib/bale)
0.82
1.2
PM-2.5
(Ib/bale)
0.024
0.031
Table 4.3-21. Estimated Percentage of Crop By Emission Control Method
(By State and U.S. Average)29
State
Alabama
Arizona
Arkansas
California
Florida
Georgia
Louisiana
Mississippi
Missouri
New Mexico
North Carolina
Oklahoma
South Carolina
Tennessee
Texas
Virginia
U.S. Average3
Percent Crop -
Full Controls
20
50
30
72
20
30
20
20
20
20
30
20
20
20
30
20
35
Percent Crop -
Conventional Controls
80
50
70
28
80
70
80
80
80
80
70
80
80
80
70
80
65
aAverage is based on the average crop (average total bales ginned per year) from 1991 to
1995 for these states.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-85
1985-1996 Methodology
Industrial
-------
Table 4.3-22. Cotton Ginnings: Running Bales Ginned By
County, District, State, and United States3
State/County/
District
UNITED STATES
Alabama
Colbert 1/
Lauderdale 1/
Lawrence
Limestone
Madison
District 1 0
Blount 1/
Cherokee 1/
District 20
Chilton 1/
Fayette 1/
Pickens 1/
Shelby 1/
Tallapoosa 1/
Tuscaloosa 1/
District 30 2/
Autauga 1/
Dallas 1/
El more
Greene 1/
Hale 1/
Lowndes 1/
Macon 1/
Marengo 1/
District 40
Running Bales
Ginned
17,498,800
72,000
72,000
35,200
59,300
25,750
144,250
4,538
4,538
4,538
4,538
4,538
4,538
4,538
4,538
4,079
4,079
6,100
4,079
4,079
4,079
4,079
4,079
34,650
State/County/
District
Alabama (Cont'd)
Baldwin 1/
Escambia 1/
Mobile 1/
Monroe 1/
District 50
Covington 1/
Crenshaw 1/
Geneva 1/
Henry 1/
Houston 1/
Russell 1/
District 60
AL Total
Arizona
Mohave 1/
District 20 2/
Maricopa
Final
District 50
La Paz 1/
Yuma
Running Bales
Ginned
30,575
30,575
30,575
30,575
122,300
25,608
25,608
25,608
25,608
25,608
25,608
153,650
491,150
354,050
266,900
620,950
74,100
aThe data in and format of this table were taken from the 03/25/96 Cotton Ginnings report.
1/ Withheld to avoid disclosing individual gins.
21 Withheld to avoid disclosing individual gins, but included in state total.
3/ Excludes some gins' data to avoid disclosing individual gins, but included in state total.
41 Withheld to avoid disclosing individual gins, but included in U.S. total.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-86
1985-1996 Methodology
Industrial
-------
Table 4.3-23. Point Source Controls by Pod and Measure
POD PODNAME
MEASNAME
SOURCE
PTFYCE
4 Fixed roof petroleum product tanks
5 Fixed roof gasoline tanks
6 EFR petroleum product tanks
7 EFR gasoline tanks
15 Ethylene oxide manufacture
16 Phenol manufacture
17 Terephthalic acid manufacture
18 Acrylonitrile manufacture
21 Cellulose acetate manufacture
23 Polypropylene manufacture
24 Polyethylene manufacture
25 Ethylene manufacture
26 Petroleum refinery wastewater treatment
27 Petroleum refinery vacuum distillation
28 Vegetable oil manufacture
29 Paint and varnish manufacture
32 Carbon black manufacture
42 Surface coating - thinning solvents
47 Ferrosilicon production
48 By-product coke manufacture - other
49 By-product coke manufacture - oven charging
50 Coke ovens - door and topside leaks
51 Coke oven by-product plants
53 Whiskey fermentation - aging
54 Charcoal manufacturing
56 SOCMI reactor
57 SOCMI distillation
61 Open top degreasing
62 In-line degreasing
63 Cold cleaning
65 Open top degreasing - halogenated
66 In-line degreasing - halogenated
68 SOCMI fugitives
CTG
CTG
CTG
CTG
SOCMI HON
SOCMI HON
Incineration (RACT)
SOCMI HON
Carbon adsorber (RACT)
Flare (RACT)
Flare (RACT)
Flare (RACT)
Benzene NESHAP/CTG
CTG
Stripper and equipment (RACT)
RACT
Flare (RACT)
RACT
RACT
NESHAP
NESHAP
NESHAP
NESHAP
Carbon adsorption (RACT)
Incineration (RACT)
New CTG
New CTG
MACT
MACT
MACT
MACT
MACT
HON - Equipment Leak and Detec
Fixed roof petroleum tanks 98
Fixed roof gasoline tanks 96
EFR petroleum tanks 90
EFR gasoline tanks 95
Ethylene oxide manufacture 79
Phenol manufacture 79
Terephthalic acid manufacture 98
Acrylonitrile manufacture 79
Cellulose acetate manufacture 54
Polypropylene manufacture 98
Polyethylene manufacture 98
Ethylene manufacture 98
Petroleum ref wastewater treatment 95
Petroleum ref vacuum distillation 100
Vegetable oil manufacture 42
Paint and varnish manufacture 70
Carbon black manufacture 90
Surface coating - thinning solvents 90
Ferrosilicon production 88
By-product coke manufacture - other 94
By-product coke mfg - oven charging 94
Coke ovens - door and topside leaks 94
Coke oven by-product plants 94
Whiskey fermentation - aging 85
Charcoal manufacturing 80
SOCMI reactor 98
SOCMI distillation 98
Open top degreasing 63
In-line degreasing 63
Cold cleaning 63
Open top degreasing - halogenated 63
In-line degreasing - halogenated 63
SOCMI fugitives 79
-------
Table 4.3-23 (continued)
POD PODNAME
MEASNAME
SOURCE
PTFYCE
69 SOCMI wastewater
71 SOCMI processes - pharmaceutical
73 SOCMI processes - gum and wood
74 SOCMI processes - cyclic crudes
75 SOCMI processes - industrial chemicals
77 SOCMI processes - crudes & agricultural
80 SOCMI fugitives - cyclic crudes
81 SOCMI fugitives - industrial organics
82 SOCMI - process vents
84 VOL storage
85 Misc organic solvent evaporation
86 Single chamber incinerators
91 Dry cleaning - perchloroethylene
93 Dry cleaning - other
95 Bakeries
96 Urea resins - general
97 Organic acids manufacture
98 Leather products
114 Petroleum refineries - Slowdown w/o control
199 Miscellaneous non-combustion
401 By-product coke mfg
402 By-product coke - flushing-liquor circulation tank
403 By-product coke - excess-ammonia liquor tank
404 By-product coke mfg - tar storage
405 By-product coke mfg - light oil sump
406 By-product coke mfg - light oil dec/cond vents
407 By-product coke mfg - tar bottom final cooler
408 By-product coke mfg - naphthalene processing
409 By-product coke mfg - equipment leaks
SOCMI HON
SOCMI HON/Pharmaceuticals
SOCMI reactor CTG
SOCMI HON
SOCMI HON
SOCMI reactor CTG
SOCMI HON
SOCMI HON
SOCMI HON
SOCMI HON
SOCMI HON
RACT
MACT
MACT
Incineration (RACT)
RACT
RACT
RACT
RACT/CTG
RACT
Benzene NESHAP
Benzene NESHAP
Benzene NESHAP
Benzene NESHAP
Benzene NESHAP
Benzene NESHAP
Benzene NESHAP
Benzene NESHAP
Benzene NESHAP
SOCMI wastewater 79
SOCMI processes - pharmaceutical 79
SOCMI processes - gum and wood 98
SOCMI processes - cyclic crudes 79
SOCMI processes - industrial chem 79
SOCMI processes - crudes & agricul 98
SOCMI fugitives - cyclic crudes 79
SOCMI fugitives - ind organics 79
SOCMI - process vents 79
VOL storage 79
Misc organic solvent evaporation 79
Single chamber incinerators 90
Dry cleaning - perchloroethylene 44
Dry cleaning - other 44
Bakeries 95
Urea resins - general 90
Organic acids manufacture 90
Leather products 90
Petoleum ref - blowdown 98
Miscellaneous non-combustion 90
By-product coke mfg 85
By-prod coke - flush-liq circ tank 95
By-prod coke - ex nh3 liquor tank 98
By-product coke mfg - tar storage 98
By-product coke - light oil sum 98
By-prod coke - oil dec/cond vents 98
By-prod coke - tar bottom cooler 81
By-prod coke - naphth processing 100
By-product coke - equipment leaks 83
NOTE: A pod is a group of SCCs with similar emissions and process characteristics for which common control measures (i.e., cost and emission reductions) can be applied.
-------
Table 4.3-24. Point Source SCC to Pod Match-up
sec
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
30100101
30100103
30100104
30100180
30100199
30100504
30100509
30100601
30100603
30100604
30100699
30101012
30101013
30101021
30101022
30101030
30101099
30101401
30101402
30101403
30101404
30101499
30101501
30101502
30101503
30101505
30101599
30101603
30101801
30101802
30101803
75
17
56
81
75
32
68
54
54
54
73
116
116
116
116
116
116
29
29
29
29
29
29
29
29
29
29
145
140
23
23
30101842
30101847
30101849
30101852
30101860
30101861
30101863
30101864
30101865
30101866
30101870
30101872
30101880
30101881
30101882
30101885
30101890
30101891
30101892
30101893
30101894
30101899
30101901
30101902
30101904
30101907
30102001
30102002
30102003
30102004
30102005
70
136
143
70
24
24
24
24
24
24
136
136
136
136
136
136
104
104
104
104
104
104
74
74
74
57
29
29
29
29
29
30102630
30102699
30103101
30103102
30103103
30103104
30103105
30103199
30103301
30103311
30103312
30103399
30103402
30103405
30103406
30103410
30103412
30103420
30103425
30103499
30104204
30106001
30106002
30106003
30106004
30106005
30106006
30106007
30106008
30106009
30106010
22
22
134
134
134
134
134
134
76
76
76
78
75
82
82
75
75
75
75
75
75
71
71
71
71
71
71
71
71
71
71
30112021
30112099
30112199
30112480
30112501
30112502
30112509
30112510
30112512
30112514
30112520
30112524
30112525
30112526
30112533
30112534
30112535
30112540
30112541
30112547
30112550
30112599
30112699
30112701
30112702
30112730
30112780
30113201
30113210
30113221
30113227
56
75
56
81
75
75
81
75
82
75
75
81
75
82
75
81
75
75
75
75
81
75
75
75
75
75
81
75
75
75
75
30116780
30116799
30116901
30116906
30116980
30117401
30117421
30117480
30117617
30117680
30118101
30118102
30118103
30118110
30118180
30119001
30119013
30119014
30119080
30119501
30119580
30119701
30119705
30119707
30119708
30119709
30119710
30119741
30119742
30119743
30119744
81
75
74
74
80
15
15
15
75
75
74
74
74
74
80
74
74
74
80
75
81
25
25
75
75
75
75
75
75
75
75
30125003
30125004
30125005
30125010
30125015
30125020
30125099
30125101
30125180
30125201
30125301
30125302
30125306
30125315
30125325
30125326
30125380
30125401
30125405
30125406
30125409
30125413
30125415
30125420
30125499
30125801
30125802
30125803
30125805
30125807
30125810
82
81
56
56
56
56
56
75
81
56
75
82
82
75
75
82
81
75
18
75
81
75
75
81
56
75
75
57
75
57
75
30181001
30182001
30182002
30182003
30182004
30182005
30182006
30182007
30182008
30182009
30182010
30182011
30183001
30184001
30188801
30188802
30188803
30188804
30188805
30190001
30190002
30190003
30190004
30201003
30201401
30201902
30201903
30201906
30201907
30201908
30201911
77
69
69
69
69
69
69
69
69
69
69
69
68
57
68
68
68
68
68
88
88
88
88
53
94
28
28
28
28
28
28
-------
Table 4.3-24 (continued)
sec
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
30101805
30101807
30101808
30101809
30101810
30101811
30101812
30101813
30101814
30101815
30101816
30101817
30101818
30101819
30101820
30101821
30101822
30101827
30101832
30101837
30101838
30101839
30101840
30300335
30300336
30300341
30300342
30300343
30300344
30300351
30300353
30300361
30300813
137
24
24
24
24
24
24
24
24
136
136
138
136
136
136
136
138
136
96
144
143
143
143
402
404
405
406
406
406
401
408
409
46
30102099
30102401
30102402
30102410
30102416
30102423
30102424
30102426
30102427
30102499
30102501
30102505
30102601
30102602
30102608
30102609
30102612
30102613
30102614
30102615
30102616
30102617
30102625
3060081 1
30600812
30600813
30600814
30600815
30600816
30600817
30600818
30600819
30600821
29
142
104
141
21
21
21
21
21
21
139
21
22
22
22
22
22
22
22
22
22
22
22
20
20
20
20
20
20
20
20
20
20
30106011
30106012
30106099
30109101
30109105
30109151
30109152
30109153
30109154
30109180
30109199
30110002
30110003
30110080
30110099
30112001
30112002
30112005
30112006
30112007
30112011
30112013
30112014
30700703
30700704
30700705
30700706
30700707
30700708
30700709
30700711
30700713
30700715
71
71
79
75
75
75
75
57
57
81
75
75
82
81
75
75
75
82
82
81
75
82
82
117
117
117
117
117
117
117
117
117
117
30113299
30113301
30113302
30113701
30113710
30113799
30114001
30114005
30115201
30115301
30115311
30115380
30115601
30115604
30115701
30115704
30115780
30115802
30115803
30115822
30116701
30116703
30116704
31000205
31000206
31000207
31000299
31000401
31000403
31000404
31000405
31088801
31088802
97
75
75
75
75
75
75
56
75
75
82
81
74
74
74
74
80
75
75
57
75
82
75
112
112
112
112
88
88
88
88
112
112
30119745
30119749
30119799
30120201
30120202
30120204
30120205
30120206
30120280
30120501
30120502
30120521
30120530
30120545
30120580
30120601
30120603
30120680
30121001
30121002
30121101
30125001
30125002
40100101
40100102
40100103
40100104
40100105
40100198
40100201
40100202
40100203
40100204
75
75
25
16
16
82
16
16
81
75
75
82
82
82
81
74
74
80
75
82
75
75
75
91
92
91
92
93
93
61
65
65
65
30125815
30125880
30125899
30130101
30130102
30130103
30130104
30130105
30130106
30130107
30130108
30130180
30130301
30130380
30130402
30130480
30130501
30130502
30130580
30180001
30180002
30180003
30180006
40188898
40199999
40200101
40200110
40200301
40200310
40200401
40200410
40200501
40200510
75
75
75
74
74
74
74
74
82
74
74
80
75
81
75
81
75
75
81
68
68
68
68
63
63
33
33
34
34
33
40
33
33
30201912
30201914
30201915
30201916
30201917
30201918
30201919
30201999
30203201
30203202
30203299
30300302
30300303
30300304
30300306
30300308
30300313
30300314
30300315
30300331
30300332
30300333
30300334
40201505
40201531
40201599
40201601
40201602
40201603
40201604
40201605
40201606
40201607
28
28
28
28
28
28
28
28
95
95
95
49
48
48
48
50
48
50
51
401
402
403
402
37
37
37
33
33
33
33
33
33
33
-------
Table 4.3-24 (continued)
sec
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
30300825
30390003
30390004
30490001
30490003
30490004
30490031
30490033
30490034
30600101
30600102
30600103
30600104
30600105
30600106
30600107
306001 1 1
30600201
30600202
30600204
30600301
30600401
30600402
30600503
30600504
30600505
30600506
30600508
30600514
30600516
30600517
30600519
30600520
46
88
88
88
88
88
88
88
88
88
88
88
88
88
88
88
88
109
109
109
109
113
114
26
26
26
26
26
26
26
26
26
26
30600903
30600904
30600905
30600999
30601001
30601101
30601201
30601401
30609902
30609903
30609904
30610001
30688801
30688802
30688803
30688804
30688805
30700101
30700102
30700103
30700104
30700105
30700106
30700107
30700108
30700109
30700110
30700199
30700203
30700214
30700215
30700221
30700222
110
110
110
110
110
110
110
110
110
110
110
110
20
20
20
20
20
60
60
60
60
60
60
60
60
60
60
60
60
60
60
60
60
30700798
30700799
30701199
30790001
30790002
30790003
30800101
30800102
30800103
30800104
30800105
30800106
30800107
30800108
30800109
30800120
30800121
30800122
30800123
30800197
30800198
30800199
30800501
30800699
30800701
30800702
30800703
30800704
30800705
30800720
30800721
30800722
30800723
117
117
36
88
88
88
30
30
30
30
30
31
30
30
30
30
30
30
31
30
30
30
30
123
123
123
123
123
123
123
123
123
123
31088803
31088804
31088805
32099997
32099998
32099999
39000201
39000203
39000289
39000299
39000402
39000403
39000489
39000499
39000501
39000502
39000503
39000589
39000598
39000599
39000602
39000603
39000605
39000689
39000699
39000701
39000702
39000789
39000797
39000799
39000801
39000889
39000899
112
112
112
98
98
98
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
87
40100205
40100206
40100207
40100221
40100222
40100223
40100224
40100225
40100235
40100236
40100251
40100252
40100253
40100254
40100255
40100256
40100257
40100258
40100259
40100275
40100295
40100296
40100297
40100298
40100299
40100301
40100302
40100303
40100304
40100305
40100306
40100307
40100308
65
61
65
62
66
66
66
66
62
62
61
65
65
65
65
61
65
61
61
61
62
62
61
62
61
63
63
63
63
63
61
63
63
40200601
40200610
40200701
40200706
40200707
40200710
40200801
40200802
40200803
40200810
40200898
40200998
40201001
40201002
40201003
40201004
40201101
40201103
40201105
40201112
40201113
40201114
40201115
40201116
40201199
40201201
40201210
40201301
40201303
40201304
40201305
40201399
40201401
33
33
36
36
36
36
35
35
35
35
35
33
88
88
88
88
41
41
41
41
41
41
41
41
41
41
41
36
36
36
36
36
37
40201608
40201609
40201619
40201620
40201621
40201622
40201623
40201625
40201626
40201627
40201628
40201629
40201631
40201632
40201699
40201702
40201703
40201704
40201705
40201721
40201722
40201723
40201724
40201725
40201726
40201727
40201728
40201731
40201732
40201734
40201735
40201799
40201801
33
33
33
33
33
33
33
33
33
33
33
33
33
33
33
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
37
-------
Table 4.3-24 (continued)
sec
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
30600602
30600603
30600701
30600702
30600801
30600802
30600803
30600804
30600805
30600806
30600807
40202031
40202033
40202099
40202101
40202103
40202104
40202105
40202106
40202107
40202108
40202109
40202131
40202132
40202133
40202199
40202201
40202202
40202203
40202205
40202299
40202301
40202302
27
27
111
111
20
20
20
20
20
20
20
37
37
37
40
40
40
40
40
40
40
40
40
40
40
40
38
38
38
38
38
132
132
30700223
30700234
30700299
30700301
30700303
30700401
30700402
30700501
30700597
30700599
30700701
40300106
40300107
40300108
40300109
403001 1 1
40300112
40300115
40300116
40300150
40300151
40300152
40300153
40300154
40300156
40300157
40300159
40300160
40300161
40300198
40300199
40300201
40300202
60
60
60
60
60
60
60
115
115
115
117
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
4
7
7
30800724
30800799
30800901
30901601
31000104
31000105
31000199
31000201
31000202
31000203
31000204
40301068
40301078
40301097
40301098
40301099
40301101
40301102
40301103
40301104
40301105
40301106
40301107
40301108
40301109
40301110
40301 1 1 1
40301112
40301113
40301114
40301115
40301116
40301117
123
123
123
108
112
112
112
112
112
112
112
4
4
4
4
4
7
7
7
7
7
7
7
7
6
6
6
6
6
6
6
6
6
39000989
39000999
39001089
39001099
39001299
39001389
39001399
39990001
39990002
39990003
39990004
40388802
40388803
40388804
40388805
40399999
40400101
40400102
40400103
40400104
40400105
40400106
40400107
40400108
40400109
40400110
404001 1 1
40400112
40400113
40400114
40400115
40400116
40400117
87
87
87
87
98
87
87
88
88
88
88
110
110
110
110
110
150
150
150
150
150
150
151
151
151
152
152
152
152
152
152
153
153
40100309
40100310
40100335
40100336
40100398
40100399
40100499
40100550
40188801
40188802
40188805
40400240
40400241
40400250
40400251
40400254
40400260
40400261
40400271
40400301
40400302
40400303
40400304
40400305
40400401
40400402
40400403
40400404
40400406
40400408
40400410
40400412
40400413
63
63
63
63
63
63
63
63
63
63
63
173
173
155
155
155
174
174
174
156
157
158
158
158
159
160
159
160
160
160
160
160
159
40201404
40201405
40201406
40201431
40201432
40201433
40201435
40201499
40201501
40201502
40201503
40500510
4050051 1
40500512
40500513
40500514
40500598
40500599
40500601
40500701
40500801
4050081 1
40500812
40588801
40588802
40588803
40588804
40588805
40600101
40600126
40600130
40600131
40600132
37
37
37
37
37
37
37
37
37
37
37
186
183
183
183
183
183
183
184
187
188
188
188
188
188
188
188
188
161
163
166
163
166
40201803
40201805
40201806
40201899
40201901
40201903
40201904
40201999
40202001
40202002
40202005
40600243
40600244
40600245
40600246
40600248
40600249
40600250
40600251
40600253
40600257
40600259
40600298
40600299
40600301
40600302
40600306
40600307
40600399
40700401
40700402
40700497
40700498
37
37
37
37
39
39
39
39
37
37
37
55
55
55
55
55
55
55
55
55
55
55
55
55
168
169
170
171
170
84
84
84
84
-------
Table 4.3-24 (continued)
sec
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
40202305
40202306
40202399
40202401
40202402
40202403
40202405
40202406
40202499
40202501
40202502
40202503
40202504
40202505
40202531
40202532
40202533
40202534
40202537
40202598
40202599
40202601
40202605
40202606
40202607
40202699
40290013
40300101
40300102
40300103
40300104
40300105
40703202
132
132
132
52
52
52
52
52
52
37
37
37
37
37
37
37
37
37
37
37
37
37
37
37
37
37
88
5
4
5
4
4
84
40300203
40300204
40300205
40300207
40300208
40300209
40300210
40300212
40300216
40300299
40300302
40301001
40301002
40301003
40301004
40301005
40301006
40301007
40301008
40301009
40301010
40301011
40301012
40301013
40301014
40301015
40301016
40301017
40301018
40301019
40301020
40301021
40704498
6
6
6
6
6
6
6
6
6
6
6
5
5
5
5
5
5
5
5
5
4
4
4
4
4
4
4
4
4
4
4
4
84
40301118
40301119
40301120
40301130
40301131
40301132
40301133
40301134
40301135
40301140
40301141
40301142
40301143
40301144
40301145
40301150
40301151
40301152
40301153
40301154
40301155
40301197
40301198
40301199
40301201
40301202
40301203
40301204
40301205
40301206
40301299
40388801
40707698
6
6
6
6
7
6
6
6
6
8
9
8
8
8
8
8
9
8
8
8
8
6
6
6
7
7
7
6
6
6
6
110
84
40400118
40400119
40400120
40400130
40400131
40400140
40400141
40400150
40400151
40400152
40400153
40400154
40400160
40400161
40400170
40400171
40400178
40400199
40400201
40400202
40400203
40400204
40400205
40400206
40400207
40400208
40400209
40400210
40400211
40400212
40400230
40400231
40787201
154
154
154
173
173
173
173
155
155
155
155
155
174
174
174
174
174
155
150
150
150
151
151
151
152
152
152
154
154
154
173
173
84
40400414
40400497
40400498
40500101
40500199
40500201
40500202
40500203
40500211
40500212
40500299
40500301
40500303
40500304
40500305
40500306
40500307
4050031 1
40500312
40500314
40500401
4050041 1
40500412
40500413
40500414
40500416
40500418
40500501
40500502
40500503
40500506
40500507
50200301
160
159
160
189
189
180
186
186
180
180
180
181
186
186
186
186
186
181
181
181
182
182
182
182
182
182
182
183
183
186
186
186
89
40600133
40600134
40600135
40600136
40600137
40600138
40600139
40600140
40600141
40600143
40600144
40600145
40600146
40600147
40600148
40600149
40600161
40600162
40600163
40600197
40600198
40600199
40600231
40600232
40600233
40600234
40600235
40600236
40600237
40600238
40600239
40600240
166
166
166
161
164
164
164
164
162
165
165
165
165
163
166
166
166
167
167
172
172
172
55
55
55
55
55
55
55
55
55
55
40700801
40700802
40700803
40700805
40700806
40700807
40700808
40700809
40700810
4070081 1
40700812
40700813
40700814
40700815
40700816
40700817
40700818
40700897
40700898
40701605
40701606
40701608
40701611
40701612
40701613
40701614
40701697
40701698
40702003
40702097
40702098
40703201
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
-------
Table 4.3-24 (continued)
sec
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
40703203
40703204
40703205
40703206
40703297
40703298
40703601
40703602
40703603
40703605
40703606
40703608
40703609
40703610
40703613
40703614
40703615
40703616
40703617
40703618
40703619
40703620
40703622
40703623
40703624
40703697
40703698
40704001
40704002
40704003
40704004
40704008
40704009
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
40704801
40704802
40704897
40704898
40705203
40705208
40705210
40705211
40705213
40705216
40705297
40705298
40705603
40705604
40705605
40705606
40705607
40705609
40705610
40705697
40705698
40706005
40706006
40706007
40706008
40706009
40706010
4070601 1
40706012
40706013
40706015
40706017
40706018
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
40708097
40708098
40708401
40708403
40708404
40708497
40708498
40715809
40717205
40717206
40717207
40717208
40717209
40717211
40717297
40717298
40717601
40717602
40717603
40717604
40717697
40717698
40718097
40720801
40720897
40720898
40722001
40722003
40722005
40722009
40722010
40722097
40722098
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
40787299
40799997
40799998
40899995
40899997
40899999
49000101
49000103
49000105
49000199
49000201
49000202
49000203
49000204
49000205
49000206
49000299
49000399
49000401
49000499
49000501
49000599
49090013
49090023
49099998
49099999
50100101
50100103
50100201
50100401
50100505
50100506
50100507
84
84
84
85
55
85
85
85
85
85
85
85
85
85
85
85
85
85
85
85
85
85
85
85
85
85
89
89
89
89
89
89
89
50200302
50200505
50200506
50200601
50200602
50290005
50290006
50290099
50300101
50300102
50300103
50300104
50300105
50300106
50300201
50300202
50300204
50300501
50300506
50300599
50300601
50300602
50300603
50300701
50300801
50300810
50300820
50300830
50300899
50390005
50390006
50390010
62540010
89
89
89
128
128
88
88
88
89
89
89
89
89
89
89
89
89
89
89
89
128
128
128
89
129
129
129
129
129
89
89
89
138
-------
Table 4.3-24 (continued)
sec
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
SCC
POD
40704097
40704098
40704401
40704402
40704403
40704404
40704405
40704406
40704407
40704408
4070441 1
40704412
40704414
40704416
40704418
40704419
40704420
40704421
40704422
40704497
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
40706019
40706020
40706021
40706022
40706023
40706024
40706097
40706098
40706401
40706402
40706403
40706497
40706801
40706802
40706814
40706897
40706898
40707601
40707602
40707697
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
40722801
40722802
40722803
40722804
40722805
40722806
40722897
40722898
40781602
40781605
40781699
40782001
40782003
40782006
40782009
40782099
40783203
40784899
40786004
40786099
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
84
50100510
50100515
50100516
50100601
50100603
50100701
50100702
50100703
50100704
50190005
50190006
50200101
50200103
50200104
50200105
50200106
50200116
50200117
50200201
50200202
89 62540020
89 62540022
89 64630016
88 64630040
89
127
127
127
127
87
87
89
89
89
89
89
89
89
89
89
138
138
138
138
NOTE: A pod is a group of SCCs with similar emissions and process characteristics for which common control measures (i.e., cost and emission reductions) can be applied.
-------
POD
Table 4.3-25. Area Source VOC Controls by SCC and Pod
SCO SOURCE MEASURE
PCTRD96
211 2420010055 Dry Cleaning - perchloroethylene
211 2420000055 Dry Cleaning - perchloroethylene
217 2501050120 Bulk Terminals
217 2501050000 Bulk Terminals
217 2501995000 Bulk Terminals
241 2415305000 Cold cleaning
241 2415310000 Cold cleaning
241 2415320000 Cold cleaning
241 2415325000 Cold cleaning
241 2415330000 Cold cleaning
241 2415335000 Cold cleaning
241 2415340000 Cold cleaning
241 2415345000 Cold cleaning
241 2415355000 Cold cleaning
241 2415360000 Cold cleaning
241 2415365000 Cold cleaning
250 2401075000 Aircraft surface coating
251 2401080000 marine surface coating
259 2301040001 SOCMI batch reactor processes
270 2640000000 TSDFs
270 2640000004 TSDFs
272 2461021000 Cutback Asphalt
272 2461020000 Cutback Asphalt
274 2301040000 SOCMI fugitives
276 2306000000 Petroleum refinery fugitives
277 2301030000 Pharmaceutical manufacture
278 2301020000 Synthetic fiber manufacture
279 2310000000 Oil & natural gas fields
279 2310010000 Oil & natural gas fields
279 2310020000 Oil & natural gas fields
279 2310030000 Oil & natural gas fields
280 2501060050 Service stations - stage I
281 2501060101 Service stations - stage II
281 2501060103 Service stations - stage II
283 2501060201 Service stations - underground tank
283 2501060201 Service stations - underground tank
284 2620000000 Municipal solid waste landfills
284 2620030000 Municipal solid waste landfills
MACT 44.0
MACT 44.0
RACT 51.0
RACT 51.0
RACT 51.0
MACT 35.0
MACT 35.0
MACT 35.0
MACT 35.0
MACT 35.0
MACT 35.0
MACT 35.0
MACT 35.0
MACT 35.0
MACT 35.0
MACT 35.0
MACT 0.0
MACT 0.0
New CTG 78.0
Phase I & II rules 94.0
Phase I & II rules 94.0
Switch to emulsified (CTG) 100.0
Switch to emulsified (CTG) 100.0
RACT 37.0
RACT 43.0
RACT 37.0
RACT (adsorber) 54.0
RACT (equipment/maintenance) 37.0
RACT (equipment/maintenance) 37.0
RACT (equipment/maintenance) 37.0
RACT (equipment/maintenance) 37.0
Vapor balance (CTG) 95.0
Vapor balance (stage II) 70.0
Vapor balance (stage II) 70.0
Vapor balance (stage II) 84.0
Vapor balance (stage II) 86.0
RCRA standards 82.0
RCRA standards 82.0
POD VOC PODNAME
APPLICABLE
211
217
241
250
251
259
270
272
274
276
277
278
279
280
284
Dry Cleaning - perchloroethylene
Bulk Terminals
Cold cleaning
Aircraft surface coating
marine surface coating
SOCMI batch reactor processes
Treatment, stroage and disposal facilities
Cutback Asphalt
SOCMI fugitives
Petroleum refinery fugitives
Pharmaceutical manufacture
Synthetic fiber manufacture
Oil and natural gas production fields
Service stations - stage l-truck unloading
Municipal solid waste landfills
National
National
National
National
National
Moderate*
National
Marginal*
National
National
National
National
Moderate*
National
National
NOTE: A pod is a group of SCCs with similar emissions and process characteristics for which common control measures (i.e., cost and
emission reductions) can be applied.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-96
1985-1996 Methodology
Industrial
-------
Table 4.3-26. Counties in the United States with Stage II Programs
that use Reformulated Gasoline
State
County
State
County
State
County
6
6
6
6
6
6
6
9
9
9
9
9
9
9
9
10
10
10
11
17
17
17
17
17
17
17
17
18
18
21
21
21
21
21
21
23
23
23
23
23
23
23
24
24
24
24
24
24
24
24
24
24
24
24
24
California
California
California
California
California
California
California
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Delaware
Delaware
Delaware
Dist. Columbia
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Indiana
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Maine
Maine
Maine
Maine
Maine
Maine
Maine
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
19
29
37
55
67
73
75
1
3
5
7
9
11
13
15
1
3
5
1
31
43
63
89
93
97
111
197
89
127
15
29
37
111
117
185
1
5
11
13
15
23
31
3
5
9
13
15
17
21
25
27
29
31
33
35
Fresno Co
Kern Co
Los Angeles Co
Napa Co
Sacramento Co
San Diego Co
San Francisco Co
Fairfield Co
Hartford Co
Litchfield Co
Middlesex Co
New Haven Co
New London Co
Tolland Co
Windham Co
Kent Co
New Castle Co
Sussex Co
Washington
Cook Co
Du Page Co
Grundy Co
Kane Co
Kendall Co
Lake Co
McHenry Co
Will Co
Lake Co
Porter Co
Boone Co
Bullitt Co
Campbell Co
Jefferson Co
Kenton Co
Oldham Co
Androscoggin Co
Cumberland Co
Kennebec Co
KNOX Co
Lincoln Co
Sagadahoc Co
York Co
Anne Arundel Co
Baltimore Co
Calvert Co
Carroll Co
Cecil Co
Charles Co
Frederick Co
Harford Co
Howard Co
Kent Co
Montgomery Co
Prince George's Co
Queen Annes Co
24
25
25
25
25
25
25
25
25
25
25
25
25
25
25
33
33
33
33
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
36
36
36
36
36
36
36
36
36
36
36
36
42
42
42
Maryland
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
New Hampshire
New Hampshire
New Hampshire
New Hampshire
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New York
New York
New York
New York
New York
New York
New York
New York
New York
New York
New York
New York
Pennsylvania
Pennsylvania
Pennsylvania
510
1
3
5
7
9
11
13
15
17
19
21
23
25
27
11
13
15
17
1
3
5
7
9
11
13
15
17
19
21
23
25
27
29
31
33
35
37
39
41
5
27
47
59
61
71
79
81
85
87
103
119
17
29
45
Baltimore
Barnstable Co
Berkshire Co
Bristol Co
Dukes Co
Essex Co
Franklin Co
Hampden Co
Hampshire Co
Middlesex Co
Nantucket Co
Norfolk Co
Plymouth Co
Suffolk Co
Worcester Co
Hillsborough Co
Merrimack Co
Rockingham Co
Strafford Co
Atlantic Co
Bergen Co
Burlington Co
Camden Co
Cape May Co
Cumberland Co
Essex Co
Gloucester Co
Hudson Co
Hunterdon Co
Mercer Co
Middlesex Co
Monmouth Co
Morris Co
Ocean Co
Passaic Co
Salem Co
Somerset Co
Sussex Co
Union Co
Warren Co
Bronx Co
Dutchess Co
Kings Co
Nassau Co
New York Co
Orange Co
Putnam Co
Queens Co
Richmond Co
Rockland Co
Suffolk Co
Westchester Co
Bucks Co
Chester Co
Delaware Co
42
42
44
44
44
44
44
48
48
48
48
48
48
48
48
48
48
48
48
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
55
55
55
55
55
55
Pennsylvania
Pennsylvania
Rhode Island
Rhode Island
Rhode Island
Rhode Island
Rhode Island
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Wisconsin
Wisconsin
Wisconsin
Wisconsin
Wisconsin
Wisconsin
91
101
1
3
5
7
9
39
71
85
113
121
157
167
201
291
339
439
473
13
36
41
85
87
95
107
153
159
179
199
510
550
570
600
610
650
670
683
685
700
710
735
740
760
800
810
830
59
79
89
101
131
133
Montgomery Co
Philadelphia Co
Bristol Co
Kent Co
Newport Co
Providence Co
Washington Co
Brazoria Co
Chambers Co
Collin Co
Dallas Co
Denton Co
Fort Bend Co
Galveston Co
Harris Co
Liberty Co
Montgomery Co
Tarrant Co
Waller Co
Arlington Co
Charles City Co
Chesterfield Co
Hanover Co
Henrico Co
James City Co
Loudoun Co
Prince William Co
Richmond Co
Stafford Co
York Co
Alexandria
Chesapeake
Colonial Heights
Fairfax
Falls Church
Hampton
Hopewell
Manassas
Manassas Park
Newport News
Norfolk
Poquoson
Portsmouth
Richmond
Suffolk
Virginia Beach
Williamsburg
Kenosha Co
Milwaukee Co
Ozaukee Co
Racine Co
Washington Co
Waukesha Co
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-97
1985-1996 Methodology
Industrial
-------
Table 4.3-27. VOC Area Source RACT
SCC
POD PODNAME
ATTAINMENT RULPEN96 CONEFF96
2102001000 22 Industrial Bituminous Coal Combustion Moderate
2102001000 22 Industrial Bituminous Coal Combustion Serious
2102001000 22 Industrial Bituminous Coal Combustion Severe
2102001000 22 Industrial Bituminous Coal Combustion Extreme
2102002000 22 Industrial Anthracite Coal Combustion Moderate
2102002000 22 Industrial Anthracite Coal Combustion Serious
2102002000 22 Industrial Anthracite Coal Combustion Severe
2102002000 22 Industrial Anthracite Coal Combustion Extreme
2102004000 23 Industrial Distillate Oil Combustion Moderate
2102004000 23 Industrial Distillate Oil Combustion Serious
2102004000 23 Industrial Distillate Oil Combustion Severe
2102004000 23 Industrial Distillate Oil Combustion Extreme
2102005000 23 Industrial Residual Oil Combustion Moderate
2102005000 23 Industrial Residual Oil Combustion Serious
2102005000 23 Industrial Residual Oil Combustion Severe
2102005000 23 Industrial Residual Oil Combustion Extreme
2102006000 24 Industrial Natural Gas Combustion Moderate
2102006000 24 Industrial Natural Gas Combustion Serious
2102006000 24 Industrial Natural Gas Combustion Severe
2102006000 24 Industrial Natural Gas Combustion Extreme
23
45
45
45
23
45
45
45
8
16
16
16
8
16
16
16
11
22
22
22
21
21
21
21
21
21
21
21
36
36
36
36
42
42
42
42
31
31
31
31
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-98
1985-1996 Methodology
Industrial
-------
Figure 4.3-1. OTAG Inventory Data Source - Area Sources.
D STATE SUBMITTED
INTERIM INVENTORY
-------
Figure 4.3-2. OTAG Inventory Data Source - Point Sources.
! ! STATE SUBMITTED - 1990
D STATE SUBMITTED - OTHER YEAR
D INTERIM INVENTORY
-------
4.4 OTHER COMBUSTION
The source categories falling under "Other Combustion" include the following Tier I and Tier II
categories:
Tier I Category Tier II Category
OTHER COMBUSTION All
MISCELLANEOUS Other Combustion
Since the publication of the last version of this report,1 Environmental Protection Agency (EPA) has
made major changes to the 1990 emissions. The revised emissions are referred to in this document as the
1990 National Emission Trends (NET) emissions and are for the most part based on State submitted data
and used as the base year inventory for the post-1990 emission inventory. Emission estimates for pre-
1990 are based mainly on the "old" 1990 emissions which are referred to in this document as the Interim
Inventory 1990 emissions. For most source categories, the methodology for the Interim Inventory 1990
emissions is the same as that previously published in the Procedures document.
The Tier I, Other Combustion emissions include residential and commercial/institutional burning of
all fuels except solid waste. The emissions for the miscellaneous, other combustion category include
agricultural burning, forest fires/wildfires, prescribed/slash and managed burning, and structural fires.
The emissions from agricultural burning, open burning, and structural fires were produced using the
methodology described in section 4.4.1. The methodologies used to estimate the emissions for forest
fires/wildfires, residential wood combustion, and prescribed/slash and managed burning are described in
section 4.4.7.
The 1990 Interim Inventory emissions for the majority of the source categories were generated from
both the point source and area source portions of the 1985 National Acid Precipitation Assessment
Program (NAPAP) inventory, except for emissions from wildfires, residential wood combustion, and
prescribed burning. The 1990 Interim Inventory emissions served as the base year from which the
emissions for the years 1985 through 1989 were estimated. The emissions for the years 1985 through
1989 were estimated using historical data compiled by the BEA2 or historic estimates of fuel consumption
based on the DOE's SEDS.3
The 1990 NET emissions were revised to incorporate as much state- supplied data as possible.
Sources of state data include the Ozone Transport Assessment Group (OTAG) emission inventory, the
Grand Canyon Visibility Transport Commission (GCVTC) emission inventory, and Aerometric
Information Retrieval System/Facility Subsystem (AIRS/FS). For most point sources, these emissions
were projected from the revised 1990 NET inventory to the years 1991 through 1996 using BEA and
SEDS data. States were surveyed to determine whether EPA should project their 1990 non-utility point
source emissions or extract them from AIRS/FS. For all states that selected AIRS/FS option, the
emissions in the NET inventory reflect their AIRS/FS data for the years 1991 through 1995. Additional
controls were added to the projected (or grown) emissions for the year 1996.
This section describes the methods used to estimate both base year 1990 emission inventories and
the emission estimates for the years 1985 through 1989 and 1991 through 1996. Point and area source
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-101 Other Combustion
-------
emissions for the years 1985-1996 were estimated for the pollutants VOC, CO, NOX, SO2, and PM-10.
Area source emissions were estimated for only 1985 through 1989 for VOC. Point source emission
estimates for PM-2.5 were only estimated for the years 1990 through 1996. PM-2.5 and NH3 were
estimated for the years 1990 through 1996.
4.4.1 1990 Interim Inventory
The 1985 NAPAP inventory estimates for the point sources have been projected to the year 1990
based on the growth in BEA historic earnings for the appropriate state and industry, as identified by the
two-digit SIC code. To remove the effects of inflation, the earnings data were converted to 1982
constant dollars using the implicit price deflator for personal consumption expenditures.4 State and SIC-
level growth factors were calculated as the ratio of the 1990 earnings data to the 1985 earnings data.
Additional information on point source growth indicators is presented in section 4.4.2.1.
For the 1990 Interim inventory, the emissions from agricultural burning, open burning, and structural
fires were based on the 1985 NAPAP inventory. The emissions estimation methodologies for these
categories are described individually below.
The agricultural burning category includes emissions from burning practices routinely used to
clear and/or prepare land for planting. Specific operations include grass stubble burning, burning of
agricultural crop residues, and burning of standing field corps as part of harvesting activities (e.g., sugar
cane). Emissions are estimated by multiplying the number of acres burned in each county by a fuel
loading factor and the an emission factor for each pollutant.
The original emissions estimation methodology for agricultural burning was developed by IIT
Research5 and estimated the 1974 activity level in terms of acres burned per state. It was assumed that
the total quantity of agricultural products burned in 1974 was the same quantity which was consumed by
fire each year. If no specific crop data were available, it was assumed that the number of acres burned
annually was divided equally between sugar cane and other field crops.6 Fuel loadings for grass burning
were 1 to 2 tons per acre; fuel loadings for sugar cane burning were 6 to 12 tons per acre.7 Emission
factors were taken from the 1985 Procedures Document6 and AP-42.8
NAPAP defined open burning as the uncombined burning of wastes such as leaves, landscape
refuse, and other rubbish. The activity factor for open burning was the quantity of solid waste burned,
which was computed for the year of interest by updating the previous year's waste generation for each
sector. The update factor was determined using engineering judgement. Estimates of the quantity of
solid waste burned in the most recent year were obtained from the National Emissions Data System
(NEDS) point source data.9 Generation factors were originally obtained from data in the 1968 Survey of
Solid Waste Practices, Interim Report^ and the Preliminary Data Analysis.,n Allocations were based on
county population and emission factors for open burning or refuse and organic materials were taken
directly from AP-42.8
Structural fires were included in NAPAP because these fires can be sources of high-level, short-
term emissions of air contaminants. The activity factor for this category was the total number of fires per
county, and was multiplied by a loading factor and emission factors to obtain emission estimates. For the
1985 NAPAP inventory, the total national number of building fires was obtained from the 1985 statistics
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from the National Fire Protection Association.12 Since there were no data available to allocate the
number of fires to the county level, an average of four fires per 1,000 population was assumed to occur
each year (based on nationwide figures given in Reference 12). The fuel loading factor was 6.8 tons per
fire6 and emission factors were taken from the OAQPS Technical Tables.6
The area source emissions from the 1985 NAPAP inventory have been projected to the year 1990
based on BEA historic earnings data, BEA historic population data, DOE SEDS data, or other growth
indicators. The specific growth indicator was assigned based on the source category. The BEA earnings
data were converted to 1982 dollars as described above. The 1990 SEDS data were extrapolated from
data for the years 1985 through 1989. All growth factors were calculated as the ratio of the 1990 data to
the 1985 data for the appropriate growth indicator. Additional information on area source growth
indicators is presented in section 4.4.2.2.
When creating the 1990 emission inventory, changes were made to emission factors, control
efficiencies, and emissions from the 1985 inventory for some sources. The PM-10 control efficiencies
were obtained from the PM-10 Calculator.,13 In addition, rule effectiveness, which was not applied in the
1985 NAPAP inventory, was applied to the 1990 emissions estimated for the point sources. The CO,
NOX, and VOC point source controls were assumed to be 80 percent effective; PM-10 and SO2 controls
were assumed to be 100 percent effective.
The 1990 emissions for CO, NOX, SO2, NH3, and VOC were calculated using the following steps:
(1) projected 1985 controlled emissions to 1990 using the appropriate growth factors, (2) calculated the
uncontrolled emissions using control efficiencies from the 1985 NAPAP Emission Inventory, and
(3) calculated the final 1990 controlled emissions using revised control efficiencies and the appropriate
rule effectiveness. The 1990 PM-10 and PM-2.5 emissions were calculated using the TSP emissions from
the 1985 NAPAP inventory. The 1990 uncontrolled TSP emissions were estimated in the same manner
as the other pollutants. The 1990 uncontrolled PM-10 estimates were calculated from these TSP
emissions by applying SCC-specific uncontrolled particle size distribution factors. The controlled PM-10
emissions were estimated in the same manner as the other pollutants. Because the majority of area source
emissions for all pollutants represented uncontrolled emissions, the second and third steps were not
required to estimate the 1990 area source emissions.
4.4.1.1 Control Efficiency Revisions
In the 1985 NAPAP point source estimates, control efficiencies for VOC, NOX, CO, and SO2
sources in Texas were judged to be too high for their process/control device combination. These high
control efficiencies occurred because Texas did not ask for control efficiency information, and simply
applied the maximum efficiency for the reported control device.14 High control efficiencies lead to high
future growth in modeling scenarios based on uncontrolled emissions (which are based on the control
efficiency and reported actual emissions). High control efficiencies also lead to extreme increases in
emissions when rule effectiveness is incorporated.
Revised VOC control efficiencies were developed for Texas for the ERCAM-VOC.15 For this
analysis, revised efficiencies were also developed by SCC and control device combination for NOX, SO2,
and CO using engineering judgement. These revised control efficiencies were applied to sources in
Texas. A large number of point sources outside of Texas had VOC and CO control efficiencies that were
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also judged to be too high. The VOC and CO control efficiencies used for Texas were also applied to
these sources.
4. 4. 1. 2 Rule Effectiveness Assumptions
Controlled emissions for each inventory year were recalculated, assuming that reported VOC, NOX
and CO controls were 80 percent effective. Sulfur dioxide and PM-10 controls were assumed to be
100 percent effective.
4.4.1.3 Emissions Calculations
A three-step process was used to calculate emissions incorporating rule effectiveness. First, base
year controlled emissions are projected to the inventory year using Equation 4.4-1.
CE. = CEM + (CEBY x EG} (Eq. 4.4-1)
where: CE; = controlled emissions for inventory year I
CEBY = controlled emissions for base year
EG; = earnings growth for inventory year I
Earnings growth is calculated using Equation 4.4-2:
DAT.
EGt= 1- — — i- (Eq. 4.4-2)
UA1BY
where: EG = earnings growth
DAT; = earnings data for inventory year I
DATBY = earnings data in the base year
Second, uncontrolled emissions in the inventory year are back-calculated from the controlled emissions
based on the control efficiency with Equation 4.4-3.
CE.
UE; =
1 _ CEFF\ (Eq. 4.4-3)
I 100 J
where: UE; = uncontrolled emissions for inventory year I
CE; = controlled emissions for inventory year I
CEFF = control efficiency (percent)
Third, controlled emissions are recalculated incorporating rule effectiveness using Equation 4.4-4:
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100
100
EFn
(Eq. 4.4-4)
where: CER; = controlled emissions incorporating rule effectiveness
UQ = uncontrolled emissions
REFF = rule effectiveness (percent)
CEFF = control efficiency (percent)
EF; = emission factor for inventory year I
EFBY = emission factor for base year
4.4.2 Emissions, 1985 to 1989
As explained in section 4.4.1, the 1990 controlled emissions were projected from the 1985 NAPAP
inventory using Equations 4.4-1 through 4.4-4. For all other years (1985 to 1989) the emissions were
projected from the 1990 emissions using Equations 4.4-1 and 4.4-2. Therefore, the 1985 emissions
estimated by this method do not match the 1985 NAPAP inventory due to the changes made in control
efficiencies and emission factors and the addition of rule effectiveness when creating the 1990 base year
inventory.
4.4.2.1 Point Source Growth
The changes in the point source emissions were equated with the changes in historic earnings by
state and industry. Emissions from each point source in the 1985 NAPAP inventory were projected to
the years 1985 through 1990 based on the growth in earnings by industry (two-digit SIC code).
Historical annual state and industry earnings data from BEA's Table SA-5 (Reference 2) were used to
represent growth in earnings from 1985 through 1990.
The 1985 through 1990 earnings data in Table SA-5 are expressed in nominal dollars. To estimate
growth, these values were converted to constant dollars to remove the effects of inflation. Earnings data
for each year were converted to 1982 constant dollars using the implicit price deflator for PCE. The PCE
deflators used to convert each year's earnings data to 1982 dollars are:
Year
1985
1987
1988
1989
1990
1982 PCE Deflator
111.6
114.3
124.2
129.6
136.4
Several BEA categories did not contain a complete time series of data for the years 1985 through
1990. Because the SA-5 data must contain 1985 earnings and earnings for each inventory year (1985
through 1990) to be useful for estimating growth, a log linear regression equation was used where
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possible to fill in missing data elements. This regression procedure was performed on all categories that
were missing at least one data point and which contained at least three data points in the time series.
Each record in the point source inventory was matched to the BEA earnings data based on the state
and the two-digit SIC. Table 4.4-1 shows the BEA earnings category used to project growth for each of
the two-digit SICs found in the 1985 NAPAP inventory. No growth in emissions was assumed for all
point sources for which the matching BEA earnings data were not complete. Table 4.4-1 also shows the
national average growth and earnings by industry from Table SA-5.
4.4.2.2 Area Source Growth
Emissions from the 1985 NAPAP inventory were grown to the Emission Trends years based on
historical BEA earnings data section 4.4.2.1, historical estimates of fuel consumption (SEDS), or other
category-specific growth indicators. Table 4.4-2 shows the growth indicators used for each area source
by NAPAP category.
The SEDS data were used as an indicator of emissions growth for the area source fuel combustion
categories shown in Table 4.4-3. (SEDS reports fuel consumption by sector and fuel type.) Since fuel
consumption was the activity level used to estimate emissions for these categories, fuel consumption was
a more accurate predictor of changes in emissions, compared to other surrogate indicators such as
earnings or population. SEDS fuel consumption data were available through 1989. The 1990 values
were extrapolated from the 1985 through 1989 data using a log linear regression technique. In addition
to projecting 1990 data for all fuel consumption categories, the regression procedure was used to fill in
missing data points for fuel consumption categories if at least three data points in the time series (1985 to
1989) were available.
Due to the year-to-year volatility in the SEDS fuel consumption data for the commercial residual oil
fuel use category, the regression technique used above did not yield realistic projections for 1990 for this
category. Therefore, a different procedure was used to project 1990 data for commercial residual oil fuel
use. State-level sales volumes of residual fuel to the commercial sector were obtained from Fuel Oil and
Kerosene Sales 199016 for 1989 and 1990. Each state's growth in sales of residual fuel to the commercial
sector from 1989 to 1990 was applied to that state's 1989 SEDS commercial residual fuel consumption
to yield a 1990 consumption estimate. A summary of SEDS national fuel consumption by fuel and sector
can be found in Table 4.4-3.
The last step in the creation of the area source inventory was matching the NAPAP categories to the
new AMS categories. This matching is provided in Table 4.4-4. Note that there is not always a one-to-
one correspondence between NAPAP and AMS categories.
4.4.3 1990 National Emission Trends
The 1990 National Emission Trends is based primarily on state data, with the 1990 Interim data
filling in the gaps. The data base houses U.S. annual and average summer day emission estimates for the
50 states and the District of Columbia. Seven pollutants (CO, NOX, VOC, SO2, PM-10, PM-2.5, and
NH3) were estimated in 1990. The state data were extracted from three sources, the OTAG inventory,
the GCVTC inventory, and AIRS/FS. Sections 4.4.3.1, 4.4.3.2, and 4.4.3.3 give brief descriptions of
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these efforts. Section 4.4.3.4 describes the efforts necessary to supplement the inventory gaps that are
either temporal, spacial, or pollutant.
Since EPA did not receive documentation on how these inventories were developed, this section
only describes the effort to collect the data and any modifications or additions made to the data.
4.4.3.1 OTAG
The OTAG inventory for 1990 was completed in December 1996. The data base houses emission
estimates for those states in the Super Regional Oxidant A (SUPROXA) domain. The estimates were
developed to represent average summer day emissions for the ozone pollutants (VOC, NOX, and CO).
This section gives a background of the OTAG emission inventory and the data collection process.
4.4.3.1.1 Inventory Components —
The OTAG inventory contains data for all states that are partially or fully in the SUPROXA
modeling domain. The SUPROXA domain was developed in the late 1980s as part of the EPA regional
oxidant modeling (ROM) applications. EPA had initially used three smaller regional domains (Northeast,
Midwest, and Southeast) for ozone modeling, but wanted to model the full effects of transport in the
eastern United States without having to deal with estimating boundary conditions along relatively high
emission areas. Therefore, these three domains were combined and expanded to form the Super Domain.
The western extent of the domain was designed to allow for coverage of the largest urban areas in the
eastern United States without extending too far west to encounter terrain difficulties associated with the
Rocky Mountains. The Northern boundary was designed to include the major urban areas of eastern
Canada. The southern boundary was designed to include as much of the United States as possible, but
was limited to latitude 26 °N, due to computational limitations of the photochemical models. (Emission
estimates for Canada were not extracted from OTAG for inclusion in the NET inventory.)
The current SUPROXA domain is defined by the following coordinates:
North: 47.00°N East: 67.00°W
South: 26.00°N West: 99.00°W
Its eastern boundary is the Atlantic Ocean and its western border runs from north to south through North
Dakota, South Dakota, Nebraska, Kansas, Oklahoma, and Texas. In total, the OTAG Inventory
completely covers 37 states and the District of Columbia.
The OTAG inventory is primarily an ozone precursor inventory. It includes emission estimates of
VOC, NOX, and CO for all applicable source categories throughout the domain. It also includes a small
amount of SO2 and PM-10 emission data that was sent by states along with their ozone precursor data.
No quality assurance (QA) was performed on the SO2 and PM-10 emission estimates for the OTAG
inventory effort.
Since the underlying purpose of the OTAG inventory is to support photochemical modeling for
ozone, it is primarily an average summer day inventory. Emission estimates that were submitted as
annual emission estimates were converted to average summer day estimates using operating schedule data
and default temporal profiles and vice versa.
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The OTAG inventory is made up of three major components: (1) the point source component,
which includes segment/pollutant level emission estimates and other relevant data (e.g., stack parameters,
geographic coordinates, and base year control information) for all stationary point sources in the domain;
(2) the area source component, which includes county level emission estimates for all stationary area
sources and non-road engines; and (3) the on-road vehicle component, which includes county/roadway
functional class/vehicle type estimates of VMT and MOBILESa input files for the entire domain. Of
these three components, the NET inventory extracted all but the utility emissions. (See section 4.2 for a
description of the utility NET emissions and section 4.6 for the on-road mobile NET emissions.)
4.4.3.1.2 Interim Emissions Inventory (OTAG Default) —
The primary data sources for the OTAG inventory were the individual states. Where states were
unable to provide data, the 1990 Interim Inventory 17> 18 was used for default inventory data. A more
detailed description of the 1990 Interim Inventory is presented in section 4.4.1.
4.4.3.1.3 State Data Collection Procedures —
Since the completion of the Interim Inventory in 1992, many states had completed 1990 inventories
for ozone nonattainment areas as required for preparing SIPs. In addition to these SIP inventories, many
states had developed more comprehensive 1990 emission estimates covering their entire state. Since
these state inventories were both more recent and more comprehensive than the 1990 Interim Inventory,
a new inventory was developed based on state inventory data (where available) in an effort to develop the
most accurate emission inventory to use in the OTAG modeling.
On May 5, 1995, a letter from John Seitz (Director of EPA's Office of Air Quality Planning and
Standards [OAQPS]) and Mary Gade (Vice President of ECOS) to State Air Directors, states were
requested to supply available emission inventory data for incorporation into the OTAG inventory.19
Specifically, states were requested to supply all available point and area source emissions data for VOC,
NOX, CO, SO2, and PM-10, with the primary focus on emissions of ozone precursors. Some emission
inventory data were received from 36 of the 38 states in the OTAG domain. To minimize the burden to
the states, there was no specified format for submitting State data. The majority of the state data was
submitted in one of three formats:
1) an Emissions Preprocessor System Version 2.0 (EPS2.0) Workfile
2) an ad hoc report from AIRS/FS
3) data files extracted from a state emission inventory data base
The origin of data submitted by each state is described in section 4.4.3.1.4.1 for point sources and
4.4.3.1.4.2 for area sources.
4.4.3.1.4. State Data Incorporation Procedures/Guidelines —
The general procedure for incorporating state data into the OTAG Inventory was to take the data
"as is" from the state submissions. There were two main exceptions to this policy. First, any inventory
data for years other than 1990 was backcast to 1990 using BEA Industrial Earnings data by state and
two-digit SIC code. This conversion was required for five states that submitted point source data for the
years 1992 through 1994. All other data submitted were for 1990.
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Second, any emission inventory data that included annual emission estimates but not average
summer day values were temporally allocated to produce average summer day values. This temporal
allocation was performed for point and area data supplied by several states. For point sources, the
operating schedule data, if supplied, were used to temporally allocate annual emissions to average
summer weekday using Equation 4.4-5
EMISSIONSASD = EMISSIONSANNUAL * SUMTHRU * I/(13 * DPW) (Eq. 4.4-5)
where:
EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
SUMTHRU = summer throughput percentage
DPW = days per week in operation
If operating schedule data were not supplied for the point source, annual emissions were temporally
allocated to an average summer weekday using EPA's default Temporal Allocation file. This computer
file contains default seasonal and daily temporal profiles by SCC. Equation 4.4-6 was used.
EMISSIONSASD = EMISSIONSANNUAL I (SUMFACSCC * WDFACSCC) (Eq. 4.4-6)
where:
EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
SUMFACSCC = default summer season temporal factor for SCC
WDFACSCC = default summer weekday temporal factor for SCC
There were a small number of SCCs that were not in the Temporal Allocation file. For these SCCs,
average summer weekday emissions were assumed to be the same as those for an average day during the
year and were calculated using Equation 4.4-7.
EMISSIONSASD = EMISSIONSANNUAL I 365 (Eq. 4.4-7)
where:
EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
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4.4.3.1.4.1 Point. For stationary point sources, 36 of the 38 states in the OTAG domain supplied
emission estimates covering the entire state. Data from the 1990 Interim Inventory were used for the two
states (Iowa and Mississippi) that did not supply data. Most states supplied 1990 point source data,
although some states supplied data for later years because the later year data reflected significant
improvements over their 1990 data. Inventory data for years other than 1990 were backcast to 1990
using BEA historical estimates of industrial earnings at the 2-digit SIC level. Table 4.4-5 provides a brief
description of the point source data supplied by each state.
4.4.3.1.4.2 Area. For area sources, 17 of the 38 states in the OTAG domain supplied 1990 emission
estimates covering the entire state, and an additional nine states supplied 1990 emission estimates
covering part of their state (partial coverage was mostly in ozone nonattainment areas). 1990 Interim
Inventory data were the sole data source for 12 states. Where the area source data supplied included
annual emission estimates, the default temporal factors were used to develop average summer daily
emission estimates. Table 4.4-6 provides a brief description of the area source data supplied by each
state.
4.4.3.1.4.4 Rule Effectiveness. For the OTAG inventory, states were asked to submit their best
estimate of 1990 emissions. There was no requirement that state-submitted point source data include rule
effectiveness for plants with controls in place in that year. States were instructed to use their judgment
about whether to include rule effectiveness in the emission estimates. As a result, some states submitted
estimates that were calculated using rule effectiveness, while other states submitted estimates that were
calculated without using rule effectiveness.
The use of rule effectiveness in estimating emissions can result in emission estimates that are much
higher than estimates for the same source calculated without using rule effectiveness, especially for
sources with high control efficiencies (95 percent or above). Because of this problem, there was concern
that the OTAG emission estimates for states that used rule effectiveness would be biased to larger
estimates relative to states that did not include rule effectiveness in their computations.
To test if this bias existed, county level maps of point source emissions were developed for the
OTAG domain. If this bias did exist, one would expect to see sharp differences at state borders between
states using rule effectiveness and states not using rule effectiveness. Sharp state boundaries were not
evident in any of the maps created. Based on this analysis, it was determined that impact of rule
effectiveness inconsistencies was not causing large biases in the inventory.
4.4.3.2 GCVTC Inventory
The GCVTC inventory includes detailed emissions data for eleven states: Arizona, California,
Colorado, Idaho, Montana, Nevada, New Mexico, Oregon, Utah, Washington, and Wyoming.20 This
inventory was developed by compiling and merging existing inventory data bases. The primary data
sources used were state inventories for California and Oregon, AIRS/FS for VOC, NOX, and SO2 point
source data for the other nine states, the 1990 Interim Inventory for area source data for the other nine
states, and the 1985 NAPAP inventory for NH3 and TSP data. In addition to these existing data, the
GCVTC inventory includes newly developed emission estimates for forest wildfires and prescribed
burning.
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After a detailed analysis of the GC VTC inventory, it was determined that the following portions of
the GCVTC inventory would be incorporated into the PM inventory:
• complete point and area source data for California
• complete point and area source data for Oregon
• forest wildfire data for the entire eleven state region
• prescribed burning data for the entire eleven state region
State data from California and Oregon were incorporated because they are complete inventories
developed by the states and are presumably based on more recent, detailed and accurate data than the
Interim Inventory (some of which is still based on the 1985 NAPAP inventory). The wildfire data in the
GCVTC inventory represent a detailed survey of forest fires in the study area and are clearly more
accurate than the wildfire data in the Interim Inventory. The prescribed burning data in the GCVTC
inventory are the same as the data in the Interim Inventory at the state level, but contain more detailed
county-level data.
Point source emission estimates in the GCVTC inventory from states other than California and
Oregon came from AIRS/FS. Corrections were made to this inventory to the VOC and PM emissions.
The organic emissions reported in GCVTC inventory for California are total organics (TOG). These
emissions were converted to VOC using the profiles from EPA's SPECIATE18 data base. Since the PM
emissions in the GCVTC were reported as both TSP and PM-2.5, EPA estimated PM-10 from the TSP in
a similar manner as described in section 4.4.1.
4.4.3.3 AIRS/FS
SO2 and PM-10 (or PM-10 estimated from TSP) sources of greater than 250 tons per year as
reported to AIRS/FS that were not included in either the OTAG or GCVTC inventories were appended
to the NET inventory. The data were extracted from AIRS/FS using the data criteria set listed in table
4.4-7. The data elements extracted are also listed in Table 4.4-7. The data were extracted in late
November 1996. It is important to note that default estimated emissions were extracted.
4.4.3.4 Data Gaps
As stated above, the starting point for the 1990 NET inventory is the OTAG, GCVTC, AIRS, and
1990 Interim inventories. Data added to these inventories include estimates of SO2, PM-10, PM-2.5, and
NH3, as well as annual or ozone season daily (depending on the inventory) emission estimates for all
pollutants. This section describes the steps taken to fill in the gaps from the other inventories.
4.4.3.4.1 SO2 and PM Emissions —
For SO2 and PM-10, state data from OTAG were used where possible. (The GCVTC inventory
contained SO2 and PM annual emissions.) In most cases, OTAG data for these pollutants were not
available. For point sources, data for plants over 250 tons per year for SO2 and PM-10 were added from
AIRS/FS. The AIRS/FS data were also matched to the OTAG plants and the emissions were attached to
existing plants from the OTAG data where a match was found. Where no match was found to the plants
in the OTAG data, new plants were added to the inventory. For OTAG plants where there were no
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matching data in AIRS/FS and for all area sources of SO2 and PM-10, emissions were calculated based
on the emission estimates for other pollutants.
The approach to developing SO2 and PM-10 emissions from unmatched point and area sources
involved using uncontrolled emission factor ratios to calculate uncontrolled emissions. This method used
SO2 or PM-10 ratios to NOX. NOX was the pollutant utilized to calculate the ratio because (1) the types
of sources likely to be important SO2 and PM-10 emitters are likely to be similar to important NOX
sources and (2) the generally high quality of the NOX emissions data. Ratios of SO2/NOX and PM-10/NOX
based on uncontrolled emission factors were developed. These ratios were multiplied by uncontrolled
NOX emissions to determine either uncontrolled SO2 or PM-10 emissions. Once the uncontrolled
emissions were calculated, information on VOC, NOX, and CO control devices was used to determine if
they also controlled SO2 and/or PM-10. If this review determined that the control devices listed did not
control SO2 and/or PM-10, plant matches between the OTAG and Interim Inventory were performed to
ascertain the SO2 and PM-10 controls applicable for those sources. The plant matching component of
this work involved only simple matching based on information related to the state and county FIPS code,
along with the plant and point IDs.
There were two exceptions to the procedures used to develop the SO2 and PM-10 point source
estimates. For South Carolina, PM-10 emission estimates came from the Interim Inventory. This was
because South Carolina had no PM data in AIRS/FS for 1990 and using the emission factor ratios
resulted in unrealistically high PM-10 emissions. The residential nonwood SO2 and PM emissions were
also deemed too high for all states based on the above calculation. The emission estimates reverted to an
earlier method as outlined in section 4.4.7.4.
There were no PM-2.5 data in either OTAG or AIRS/FS. Therefore, the point and area PM-2.5
emission estimates were developed based on the PM-10 estimates using source-specific uncontrolled
particle size distributions and particle size specific control efficiencies for sources with PM-10 controls.
To estimate PM-2.5, uncontrolled PM-10 was first estimated by removing the impact of any PM-10
controls on sources in the inventory. Next, the uncontrolled PM-2.5 was calculated by multiplying the
uncontrolled PM-10 emission estimates by the ratio of the PM-2.5 particle size multiplier to the PM-10
particle size multiplier. (These particle size multipliers represent the percentage to total particulates
below the specified size.) Finally, controls were reapplied to sources with PM-10 controls by multiplying
the uncontrolled PM-2.5 by source/control device particle size specific control efficiencies.
4.4.3.4.2 NH3 Emissions —
All NH3 emission estimates incorporated into the NET Inventory came directly from EPA's National
Particulate Inventory (NPI).18 This methodology is the same as that reported in section 4.4.1 for the
1990 Interim Inventory. The NPI contained the only NH3 emissions inventory available. (Any NH3
estimates included in the OTAG or AIRS/FS inventory were eliminated due to sparseness of data.) As
with SO2 and PM-10, plant matching was performed for point sources. Emissions were attached to
existing plants where there was a match. New plants were added for plants where there was no match.
4.4.3.4.4 Other Modifications —
Additional data were also used to fill data gaps for residential wood combustion and prescribed
burning. Although these categories were in the OTAG inventory, the data from OTAG were not usable
since the average summer day emissions were often very small or zero. Therefore, annual and average
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summer day emission estimates for these two sources were taken from the NET (detailed in sections
4.4.7.3 and 4.4.7.2).
Additional QA/quality control (QC) of the inventory resulted in the following changes:
• Emissions with SCCs of fewer than eight digits or starting with a digit greater than the number
"6" were deleted because they are invalid codes.
• Tier assignments were made for all SCCs.
• Checked and fixed sources with PM-2.5 emissions which were greater than their PM-10
emissions.
• Checked and fixed sources with PM-10 emissions greater than zero and PM-2.5 emissions
equal to zero.
4.4.4 Emissions, 1991 to 1994
The 1991 through 1994 area source emissions were grown in a similar manner as the 1985 through
1989 estimates, except for using a different base year inventory. The base year for the 1991 through
1994 emissions is the 1990 NET inventory. The point source inventory was also grown for those states
that did not want their AIRS/FS data used. (The list of states are detailed in the AIRS/FS subsection,
4.4.4.2.) For those states requesting that EPA extract their data from AIRS/FS, the years 1990 through
1995 were downloaded from the EPA IBM Mainframe. The 1996 emissions were not extracted since
states are not required to have the 1996 data uploaded into AIRS/FS until July 1997.
4.4.4.1 Grown Estimates
The 1991 through 1994 point and area source emissions were grown using the 1990 NET inventory
as the basis. The algorithm for determining the estimates is detailed in section 4.4.1.3. The 1990 through
1996 SEDS and BEA data are presented in Tables 4.4-8 and 4.4-9. The 1996 BEA and SEDS data were
determined based on linear interpretation of the 1988 through 1995 data. Point sources were projected
using the first two digits of the SIC code by state. Area source emissions were projected using either
BEA or SEDS. Table 4.4-10 lists the SCC and the source for growth.
The 1990 through 1996 earnings data in BEA Table SA-5 (or estimated from this table) are
expressed in nominal dollars. In order to be used to estimate growth, these values were converted to
constant dollars to remove the effects of inflation. Earnings data for each year were converted to 1992
constant dollars using the implicit price deflator for PCE. The PCE deflators used to convert each year's
earnings data to 1992 dollars are:
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-113 Other Combustion
-------
Year 1992 PCE Deflator
1990 93.6
1991 97.3
1992 100.0
1993 102.6
1994 104.9
1995 107.6
1996 109.7
4.4.4.2 AIRS/FS
Several states responded to EPA's survey and requested that their 1991 through 1995 estimates
reflect their emissions as reported in AIRS/FS. The list of these states, along with the years available in
AIRS/FS is given in Table 4.4-11. As described in section 4.4.3.3, default estimated annual and ozone
season daily emissions (where available) were extracted from AIRS/FS. Some changes were made to
these AIRS/FS files. For example, the default emissions for some states contain rule effectiveness and the
emissions were determined to be too high by EPA. The emissions without rule effectiveness were
extracted from AIRS/FS and replaced the previously high estimates. The changes made to select state
and/or plant AIRS/FS data are listed below.
• Louisiana All VOC source emissions were re-extracted to obtain
emissions without rule effectiveness for the year 1994.
• Colorado - Mastercraft The VOC emissions were reported as ton/year in the initial
download from AIRS. The units were changed to
pounds/year in AIRS.
• Wisconsin - Briggs and Stratton The VOC emissions for two SCCs were changed from with
rule effectiveness to without rule effectiveness for the years
1991, 1993, and 1994.
As noted in Table 4.4-11, several states did not report emissions for all pollutants for all years for
the 1990 to 1995 time period. To fill these data gaps, EPA applied linear interpolation or extrapolated
the closest two years worth of emissions at the plant level. If only one year of emissions data were
available, the emission estimates were held constant for all the years. The segment-SCC level emissions
were derived using the average split for all available years. The non-emission data gaps were filled by
using the most recent data available for the plant.
As described in section 4.4.3.4.1, many states do not provide PM-10 emissions to AIRS. These
states' TSP emissions were converted to PM-10 emissions using uncontrolled particle size distributions
and AP-42 derived control efficiencies. The PM-10 emissions are then converted to PM-2.5 in the same
manner as described in section 4.4.1.3. The State of South Carolina provided its own conversion factor
for estimating PM-10 from TSP.22
For all sources that did not report ozone season daily emissions, these emissions were estimated
using the algorithm described in section 4.4.3.1.4 and equations 4.4-5 through 4.4-7.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-114 Other Combustion
-------
4.4.5 1995 Emissions
The 1995 emission estimates were derived in a similar manner as the 1991 through 1994 emissions.
The estimates were either extracted from AIRS/FS for 1995, estimated using AIRS/FS data for the years
1990 through 1994, or projected using the 1990 NET inventory. The method used depended on states'
responses to a survey conducted by EPA early in 1997. A description of the AIRS/FS methodology is
described in section 4.4.4. The following three subsections describe the projected emissions.
4.4.5.1 Grown Estimate
The 1995 point and area source emissions were grown using the 1990 NET inventory as the
basis. The algorithm for determining the estimates is detailed in section 4.4.1.3 and equations 4.4-1
through 4.4-4. The 1990 through 1996 SEDS and BEA data are presented in Tables 4.4-8 and 4.4-9.
4.4.5.2 NOXRACT
Major stationary source NOX emitters in marginal and above nonattainment areas and in ozone
transport regions (OTRs) are required to install Reasonably Available Control Technology (RACT)-level
controls under the ozone nonattainment related provisions of Title I of the 1990 Clean Air Act
Amendments (CAAA). The definition of major stationary source for NOX differs by the severity of the
ozone problem as shown in Table 4.4-12.
NOX RACT controls for non-utility sources that were modeled for the 1995 NET emissions are
shown in Table 4.4-13. These RACT-level controls were applied to point source emitters with emissions
at or above the major source size definition for each area. The application of NOX RACT controls was
only applied to grown sources.
4.4.5.3 Rule Effectiveness
Rule effectiveness was revised in 1995 for all grown sources using the information in the 1990 data
base file. If the rule effectiveness value was between 0 and 100 percent in 1990 and the control efficiency
was greater than 0 percent, the uncontrolled emissions were calculated for 1990. The 1995 emissions
were calculated by multiplying the growth factor by the 1990 uncontrolled emissions and the control
efficiency and a rule effectiveness of 100 percent. The adjustment for rule effectiveness was only applied
to grown sources.
4.4.6 1996 Emissions
The 1996 emission estimates were derived in a similar manner as the 1995 emissions. For point
sources, the 1995 AIRS/FS emissions and 1995 emissions grown from 1990 emissions were merged. The
following describes the projected 1996 emissions. No controls were added to the 1996 emissions.
The 1996 point and area source emissions were grown using the 1995 NET inventory as the basis.
The algorithm for determining the estimates is described by Equation 4.4-8. The 1990 through 1996
SEDS and BEA data are presented in Tables 4.4-8 and 4.4-9. The 1996 BEA and SEDS data were
determined using linear interpretation of the 1988 through 1995 data. Rule effectiveness was updated to
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-115 Other Combustion
-------
100 percent as described in section 4.4.5.3 for the AIRS/FS sources that reported rule effectiveness of
less than 100 percent in 1995.
The following equation describes the calculation used to estimate the 1996 emissions:
1QQfi 1QQ,
1996 1995
where: CER1996 = controlled emissions incorporating rule effectiveness
UC1995 = uncontrolled emissions
GS = growth surrogate (either BEA or SEDS data)
REFF = rule effectiveness (percent)
CEFF = control efficiency (percent)
RP = rule penetration (percent)
The rule effectiveness for 1996 was always assumed to be 100 percent. The control efficiencies and rule
penetrations are 100 percent since no additional controls were applied.
4.4.7 Alternative Base Inventory Calculations
For three combustion sources, the 1985 NAPAP inventory was not used as the base year for some
or all other years. The 1985 to 1990 wildfire estimates were extracted from the GCVTC inventory.20
The wildfire emissions for 1985 through 1990 for non-GCVTC states or missing years are based on
AP-42 emission factors and fuel loading values. The activity data were derived from the U.S.
Department of Agriculture (USD A) Forest Service and the U.S. Department of Interior (DOI). The
prescribed burning estimates for the years 1985 to 1990 are the same and were obtained from the USDA.
Residential wood combustion estimates are also based on AP-42 emission factors and EPA-generated
activity.
4. 4. 7. 1 Forest Fires/Wildfires
Forest fire/wildfire emissions were generated for the years 1985 through 1995 using the data on
number of acres burned (obtained from the Department of the Interior [DOI]23' 24 and the USDA Forest
Service [USFS]25'26), AP-42 emission factors, and AP-42 fuel loading factors.27 Equation 4.4-9
summarizes the calculation.
= Activity x Fuel Loading x EF x UCF (Eq. 4.4-9)
where: Estate = annual state emissions (tons)
Activity = sum of DOI, USFS, and state and private land acres burned (acres)
Fuel Loading = average fuel loading for state (tons/acre)
EF = emission factor (Ibs/ton)
UCF = unit conversion factor (1 ton /2,000 Ibs)
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-116 Other Combustion
-------
Table 4.4-14 shows the emission factors and fuel loading for wildfires developed from AP-42. PM-
2.5 emissions for 1990 through 1995 were calculated by multiplying the PM-10 emissions by 0.23.18
Since complete data for 1996 were not available, 1996 emissions were assumed to be the same as 1995
emissions.
4.4.7.1.1 Grand Canyon States —
4.4.7.1.1.1 Grand Canyon States f 1986-1993). For the years 1986 through 1993, for the states of
Arizona, California, Colorado, Idaho, Montana, Nevada, New Mexico, Oregon, Utah, Washington, and
Wyoming, the CO, NOX, VOC, and PM-10 emissions calculated using the methodology described above
were replaced by those included in the GCVTC inventory.20 The GCVTC inventory provided county
level emissions for forest fires in this source category. PM-2.5 emissions for 1990 were also replaced by
those in the GCVTC inventory. PM-2.5 emissions for 1991 through 1995 were calculated by multiplying
the PM-10 emissions by 0.23.18 The SO2 emissions for these states were calculated using the AP-42
emission factor ratio equation shown below. The emission factors are shown in Table 4.4-10.
SO2 EF
Emissions = x NO Emissions (En 44-10)
NO EF { 4' ;
where: SO2 Emissions = annual county SO2 emissions (tons)
SO2 EF = AP-42 emission factor for SOX (Ibs/ton)
NOX EF = AP-42 emission factor for NOX (Ibs/ton)
NOX Emissions = annual NOX emissions (tons)
4.4.7.1.1.2 Grand Canyon States (1985.1994.1995). For the years 1985, 1994, and 1995, for the
states of Arizona, California, Colorado, Idaho, Montana, Nevada, New Mexico, Oregon, Utah,
Washington, and Wyoming, CO, NOX, VOC, PM-10 and PM-2.5 emissions were calculated using
Equation 4.4-11.
State Activity
County Emissions ear = — x County Emissions 1990 (Eq. 4.4-11)
ACtlVlt ,
where: County Emissionsyear = annual county emissions (tons)
State Activity = DOI, state and private, and National Forest Lands burned (acres)
County Emissions1990 = annual county emissions provided by the GCVTC (tons)
4.4.7.1.2 Activity —
The activity factor for wildfires is land acres burned. There are three sources of data for this activity:
National Forest Service lands burned, state and private acres burned,25'26 and U.S. DOI acres burned.23'24
Data from these three sources were summed to get the total acres burned for each state.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-117 Other Combustion
-------
4.4. 7.1.3 Fuel Loading and Emission Factors —
AP-42 fuel loading and emission factors are shown in Table 4.4- 14.27 An average fuel loading was
determined for five regions in the United States. Emission factors for SO2, NOX, VOC, CO, and PM-10
were used. PM-2.5 emissions were calculated by multiplying the PM-10 emissions by 0.23. 18
4.4.7.1.4 County Distribution —
All non-GCVTC states were distributed to the county-level using the same county-level distribution
as was used in the 1985 NAPAP Inventory. GCVTC provided county-level emissions for 1986 through
1993. GCVTC emissions were calculated for 1985, 1994, and 1995 using the 1990 GCVTC emissions,
as described above.
4. 4. 7. 2 Prescribed/Slash and Managed Burning
The prescribed burning emissions were based on a 1989 USDA Forest Service inventory of
particulate matter and air toxics from prescribed burning.28 The Forest Service inventory contained state-
level totals for total particulate matter, PM-10, PM-2.5, CO, carbon dioxide, methane, non-methane, and
several air toxics.
The emissions for all pollutants were based on the 1989 Forest Service inventory of particulate
matter from prescribed burning. This inventory contains county-level emissions for PM-10, and VOC.
The NOX, CO, and SO2 emissions were calculated by assuming the ratio between the VOC emissions to
either the NOX, CO or SO2 emissions in the Forest Service inventory was equal to the corresponding ratio
using the 1985 NAPAP inventory. Equation 4.4-12 was used.
( NAPAP pn, \
FSPOL = FSVOC x POL (Eq. 4.4-12)
where: FSPOL = prescribed burning (NOX, CO, or SO2) emissions from Forest Service
FSVOC = prescribed burning VOC emissions from Forest Service
NAPAPPOL = prescribed burning (NOX, CO, or SO2) emissions from 1985 NAPAP
NAPAPVOC = prescribed burning VOC emissions from 1985 NAPAP
The resulting 1989 emissions for CO, NOX, PM-10, SO2, and VOC have been used for all years between
1985 and 1990.
4.4.7.3 Residential Wood
Emissions from residential wood combustion were estimated for 1985 through 1996 using annual
wood consumption and an emission factor. The following general equation (Equation 4.4-13) was used
to calculate emissions:
( CE\
Eyear = A^ity * EF * \1 - — (Eq. 4.4-13)
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-118 Other Combustion
-------
where: E
year
Activity
EF
CE
county emissions (tons)
wood consumption (cords)
emission factor (tons/cord)
control efficiency (percent)
Activity was based on EPA's County Wood Consumption Estimation Model.29 This model was adjusted
with heating degree day information,30 and normalized with annual wood consumption estimates.31
AP-42 emission factors for CO, NOX, PM-10, PM-2.5, SO2 and VOC were used. A control efficiency was
applied nationally to PM-10 and PM-2.5 emissions for the years 1991 through 1996.32
4.4.7.3.1 Activity - County Model —
EPA's County Wood Consumption Estimation Model is based on 1990 data and provides county
level estimates of wood consumption, in cords. Model F of the overall Model was used to estimate the
amount of residential wood consumed per county, using a sample set of 91 counties in the northeast and
northwestern United States. Model F calculates estimates of cords of wood consumed per household as
a function of the number of homes heating primarily with wood with a forced intercept of zero. Using
the Model F results, the percentage of the population heating with wood, the number of households in a
county, land area per county, and heating degree days, county-level wood consumption for 1990 was
estimated.
The counties listed below show no residential wood consumption activity. The emissions for these
18 counties for the years 1985 through 1996 are zero.
State
Alaska
Hawaii
Kansas
Montana
Texas
County
Aleutians East Borough
Kalawao
Kearny
Stanton
Yellowstone National Park
Cochran
Crockett
Crosby
Garza
Hartley
Jim Hogg
Loving
Moore
Reagan
Sterling
Swisher
Terrell
Yoakum
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-119
1985-1996 Methodology
Other Combustion
-------
4.4.7.3.2 Heating Degree Days —
A heating degree day is the number of degrees per day the daily average temperature is below
65 degrees Fahrenheit. These data were collected for one site in all states (except Texas and California
where data were collected for two sites) for each month and summed for the year. An average of the two
sites was used for Texas and California. This information is used to adjust the model, which is partially
based on 1990 heating degree days, to the appropriate year's heating degree data. Equation 4.4-14 was
used.
State Md Total
Adjusted Model = ——-—f— x County Modell990 (Eq. 4.4-14)
y State hdd Total1990 v H '
where: Adjusted Model = county wood consumption (cords)
State hdd Total = total heating degree days (degrees Fahrenheit)
County Model = EPA model consumption (cords)
4.4.7.3.3 National Wood Consumption —
The Adjusted Model wood consumption estimate was normalized on a national level using the U.S.
Department of Energy (DOE) estimate of residential U.S. wood consumption. This value is reported in
trillion British thermal units (Btu) and is converted to cords by multiplying by 500,000. Consumption for
the years 1985, 1986, and 1988 were unavailable from the DOE. Known year's consumption and heating
degree days were used to estimate these years. The 1985 DOE estimate was calculated using the ratio of
1985 total heating degree days to 1984 total heating degree days multiplied by the 1984 DOE wood
consumption estimate. The 1986 DOE estimate was calculated using the ratio of 1986 total heating
degree days to 1985 total heating degree days multiplied by the "calculated" 1985 DOE wood
consumption estimate. The 1988 DOE estimate was calculated using the ratio of 1988 total heating
degree days to 1987 total heating degree days multiplied by the 1987 DOE wood consumption estimate.
Equation 4.4-15 shows the normalization of the Adjusted Model.
DOE
Activity = Adjusted Model x ___ year — (Eq. 4.4-15)
Adjusted Model
where: Activity = normalized county consumption (cords)
Adjusted Model = county wood consumption (cords)
DOE = DOE national estimate of residential wood consumption (cords)
4.4.7.3.4 Emission Factors —
Emission factors were obtained from Table 1.10-1 of AP-42, Emission Factors for Residential
Wood Combustion, for conventional wood stoves,27 and are shown here in Table 4.4-15. Table 4.4-15
also shows the emission factors expressed in tons per cord consumed.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-120 Other Combustion
-------
4.4.7.3.5 Control Efficiency —
A control efficiency was applied nationally to PM-10 and PM-2.5 residential wood combustion for
the years 1991 through 1996.32 The control efficiency for all pollutants for the years 1985 through 1990,
and for VOC, NOX, CO, and SO2 for 1991 through 1996 is zero. Table 4.4-16 shows the control
efficiencies for PM-10 and PM-2.5 for 1991 through 1996.
4.4.7.4 SO 2 and PM Residential Nonwood Combustion
The 1990 SO2 and PM NET emissions are the same as the 1990 Interim Inventory emissions. The
1991 through 1994 emissions were estimated by applying growth factors to the 1990 Interim Inventory
emissions. The growth factors were obtained from the prereleased E-GAS, version 2.O.33 The E-GAS
generates growth factors at the SCC-level for counties representative of all counties within each ozone
nonattainment area classified as serious and above and for counties representative of all counties within
both the attainment portions and the marginal and moderate nonattainment areas within each state. The
appropriate growth factors were applied by county and SCC to the 1990 emissions as shown by Equation
4.5-16.
Emissions (county^SCCyear} = Growth (comtyfCCyear) x Emissions(county^scc^} (Eq. 4.5-16)
There are approximately 150 representative counties in E-GAS and 2000 SCCs present in the base
year inventory. This yields a matrix of 300,000 growth factors generated to determine a single year's
inventory. To list all combinations would be inappropriate.
4.4.8 References
1. National Air Pollutant Emission Trends, Procedures Document 1900-1993, EPA-454/R-95-002,
Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research
Triangle Park, NC. December 1994
2. Table SA-5 — Total Personal Income by Major Sources 1969-1990. Data files. Bureau of
Economic Analysis, U.S. Department of Commerce, Washington. DC. 1991.
3. State Energy Data Report — Consumption Estimates 1960-1989, DOE/EIA-0214(89), U.S.
Department of Energy, Energy Information Administration, Washington, DC. May 1991.
4. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC. 1986, 1987, 1988, 1989, 1990, 1991.
5. Area Source Documentation for the 1985 National Acid Precipitation Assessment Program
Inventory, EPA-600/8-88-106, U.S. Environmental Protection Agency, Air and Energy Engineering
Research Laboratory, Research Triangle Park, NC. December 1988.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-121 Other Combustion
-------
6. Procedures Document for Development of National Air Pollutant Emissions Trends Report, U.S.
Environmental Protection Agency, Office of Air Quality Planning and Standards, Research Triangle
Park, NC, December 1985.
7. AEROSManual Series Volume II: AEROS User's Manual, U.S. Environmental Protection Agency,
Office of Air Quality Planning and Standards, Research Triangle Park, NC, July 1984.
8. Compilation of Air Pollutant Emission Factors - Volume I: Stationary Point and Area Sources,
AP-42 (GPO 055-000-00251-7), Fourth Edition, U.S. Environmental Protection Agency, Research
Triangle Park, NC. 1985.
9. 1985 National Emissions Data System Point Source Data, U.S. Environmental Protection Agency,
Office of Air Quality Planning and Standards, Research Triangle Park, NC, 1987.
10. 1968 National Survey or Community Solid Waste Practices, Interim Report, U.S. Department of
Health, Education and Welfare, Public Health Services, Cincinnati, OH, 1968.
11. 1968 National Survey of Community Solid Waste Practices, Preliminary Data Analysis, U.S.
Department of Health, Education and Welfare, Public Health Services, Cincinnati, OH, 1968.
12. Structural Fires Statistics 1985, National Fire Protection Association, Boston, MA, 1986.
13. Dean, T. A. and P. Carlson, PM-10 Controlled Emissions Calculator. E.H. Pechan & Associates,
Inc. Contract No. 68-DO-0120 Work Assignment No. 11-81. Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. April 27, 1993.
(TTN CHIEF BBS)
14. Barnard, W.R., and P. Carlson, PM-10 Emission Calculation, Tables 1 and 4, E.H. Pechan &
Associates, Inc. Contract No. 68-DO-1020, U.S. Environmental Protection Agency, Emission
Factor and Methodologies Section. June 1992.
15. Gill, W., Texas Air Control Board personal communication with D. Solomon. April 23, 1992.
16. "Fuel Oil and Kerosene Sales 1990," U.S. Department of Energy, Energy Information
Administration, Washington, DC, October 1991.
17. Regional Interim Emission Inventories (1987-1991), Volume I: Development Methodologies, EPA-
454/R-23-021a, U.S. Environmental Protection Agency, Office of Air Quality Planning and
Standards, Research Triangle Park, NC. May 1993.
18. E.H. Pechan & Associates, Inc., National Particulates Inventory: Phase IIEmission Estimates,
Draft Report. June 1995.
19. Seitz, John, U.S. Environmental Protection Agency, Research Triangle Park, NC, Memorandum to
State Air Directors. May 5, 1995.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-122 Other Combustion
-------
20. An Emission Inventory for Assessing Regional Haze on the Colorado Plateau, Grand Canyon
Visibility Transport Commission, Denver, CO. January 1995.
21. Volatile Organic Compound (VOC)/Particulate Matter (PM) Speciation Data System (SPECIATE)
User's Manual, Version 1.5, Final Report, Radian Corporation, EPA Contract No. 68-DO-0125,
Work Assignment No. 60, Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. February 1993.
22. Internet E-mail from J. Nuovo to J. Better of the Department of Health and Environmental Control
(DHEC), Columbia, South Carolina, entitled Total Suspended Paniculate (TSP)/PM-10 Ratio.
Copy to P. Carlson, E.H. Pechan & Associates, Inc., Durham, NC. April 10, 1997.
23. Annual Wildland Fire Report. U.S. Department of the Interior. Internal Publication. 1994.
24. Wildfires by State. U.S. Department of the Interior. 1995.
25. Report to the U.S. Forest Service, Fiscal Year 1992. ISBN 0-16-041707-4. Forest Service, U.S.
Department of Agriculture. 1993.
26. National Forest Fire Report. Annual. Forest Service, U.S. Department of Agriculture. 1993-1995.
27. Compilation of Air Pollutant Emission Factors, AP-42, U.S. Environmental Protection Agency, 4th
Edition. July 1993.
28. An Inventory of Paniculate Matter and Air Toxic Emissions from Prescribed Fires in the United
States for 1989. Forest Service, U.S. Department of Agriculture, Seattle, WA. 1989.
29. Phillips, Breda M. County Wood Consumption Estimation Model, U.S. Environmental Protection
Agency, Research Triangle Park, NC, March 1995.
30. Local Climatology Data, National Climatological Center, U.S. Environmental Protection Agency,
Research Triangle Park, NC, Monthly, 1985-1996.
31. Estimates of U.S. Biofuels Consumption. DOE/EIA-0548. Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
32 .H. Pechan & Associates, Inc. 2010 Clean Air Act Baseline Emission Projections for the
Integrated Ozone, Paniculate Matter, and Regional Haze Cost Analysis. Prepared for U.S.
Environmental Protection Agency, Research Triangle Park, NC. May 1997.
33. Economic Growth Analysis System: User's Guide, Version 2.0. EPA-600/R-94-139b. Joint
Emissions Inventory Oversight Group, U.S. Environmental Protection Agency, Research Triangle
Park,NC. August 1994.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-123 Other Combustion
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Table 4.4-1. Bureau of Economic Analysis's SA-5 National Changes in
Earnings by Industry
Percent Growth from:
Industry
Wholesale trade
Retail trade
Banking and credit agencies
Insurance
Real estate
Holding companies and
investment services
Hotels and other lodging places
Personal services
Private households
Business and miscellaneous
repair services
Auto repair, services, and garages
Amusement and recreation
services and motion pictures
Health services
Legal services
Educational services
Social services and membership
organizations
Miscellaneous professional
services
Federal, civilian
Federal, military
State and local government
SIC
50,51
52 to 59
60,61
63,64
65,66
67
70
72
88
76
75
78,79
80
81
82
83
84
91
97
92 to 96
1985 to 1987
5.01
5.19
12.44
14.09
92.14
39.05
12.65
7.17
-5.68
17.05
6.65
17.93
15.15
20.14
9.35
17.39
11.28
-0.54
1.96
7.88
1987 to 1988
5.87
4.39
2.45
4.20
-6.98
-34.86
5.59
2.35
2.41
-17.34
2.46
16.43
7.08
9.92
7.17
8.45
5.04
3.79
-1.07
3.63
1988 to 1989
2.44
0.65
-0.33
1.52
-7.87
-12.18
1.71
7.44
0.83
5.79
3.00
4.06
5.11
4.09
3.88
7.95
7.08
1.21
-1.58
3.19
1989 to 1990
-1.02
-0.94
-0.49
2.71
-0.48
16.91
2.29
5.41
-3.69
4.34
3.93
7.59
6.28
4.80
2.60
7.37
4.12
1.96
-3.19
3.04
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-124
1985-1996 Methodology
Other Combustion
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Table 4.4-2. Area Source Growth Indicators
NAPAP
sec
1
2
3
4
5
6
7
8
9
10
11
12
60
61
62
64
99
Category Description
Residential Fuel - Anthracite Coal
Residential Fuel - Bituminous Coal
Residential Fuel - Distillate Oil
Residential Fuel - Residual Oil
Residential Fuel - Natural Gas
Residential Fuel - Wood
Commercial/Institutional Fuel - Anthracite
Coal
Commercial/Institutional Fuel - Bituminous
Coal
Commercial/Institutional - Distillate Oil
Commercial/Institutional - Residual Oil
Commercial/Institutional - Natural Gas
Commercial/Institutional - Wood
Forest Wild Fires
Managed Burning - Prescribed
Agricultural Field Burning
Structural Fires
Minor Point Sources
Data
Source
SEDS
SEDS
SEDS
SEDS
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
Growth Indicator
Res - Anthracite
Res - Bituminous
Res - Distillate oil
Zero growth
Res - Natural gas
Population
Comm - Anthracite
Comm - Bituminous
Comm - Distillate oil
Comm - Residual oil
Comm - Natural gas
Services
Zero growth
Zero growth
Farm
Zero growth
Population
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-125
1985-1996 Methodology
Other Combustion
-------
Table 4.4-3. SEDS National Fuel Consumption
Category 1985 1986 1987 1988 1989 1990
Anthracite Coal (thousand short tons)
Commercial 524 494
Residential 786 740
Bituminous Coal
Commercial
Residential
478
717
430
646
422
633
410
615
(thousand short tons)
4,205
2,264
4,182
2,252
3,717
2,002
3,935
2,119
3,323
1,789
3,470
1,869
Distillate Fuel (thousand barrels)
Commercial 107,233 102,246 101,891 98,479 91,891 95,385
Residential 171,339 173,736 176,822 182,475 178,629 184,501
Motor Gasoline (thousand barrels)
All Sectors 2,493,361 2,567,436 2,630,089 2,685,145 2,674,669 2,760,414
Natural Gas (million cubic feet)
Commercial 2,432 2,318 2,430 2,670 2,719 2,810
Residential 4,433 4,314 4,315 4,630 4,777 4,805
Residual Fuel (thousand barrels)
Commercial 30,956 39,480 41,667 42,256 35,406 27,776
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-126 Other Combustion
-------
Table 4.4-4. AMS to NAPAP Source Category Correspondence
AMS
NAPAP
SCC
Category
SCC Category
Stationary Source Fuel Combustion
2103001000 Commercial/Institutional - Anthracite Coal
(Total: All Boiler Types)
2103002000 Commercial/Institutional -
Bituminous/Subbituminous Coal (Total: All
Boiler Types)
2103004000 Commercial/Institutional - Distillate Oil
(Total: Boilers & I.C. Engines)
2103005000 Commercial/Institutional - Residual Oil
(Total: All Boiler Types)
2103006000 Commercial/Institutional - Natural Gas
(Total: Boilers & I.C. Engines)
2103008000 Commercial/Institutional - Wood (Total: All
Boiler Types)
2104001000 Residential - Anthracite Coal (Total: All
Combustor Types)
2104002000 Residential - Bituminous/Subbituminous
Coal (Total: All Combustor Types)
2104004000 Residential - Distillate Oil (Total: All
Combustor Types)
2104005000 Residential - Residual Oil (Total: All
Combustor Types)
2104006000 Residential - Natural Gas (Total: All
Combustor Types)
2104008000 Residential - Wood (Total: Woodstoves
and Fireplaces)
7 Commercial/Institutional Fuel -
Anthracite Coal
8 Commercial/Institutional Fuel -
Bituminous Coal
9 Commercial/Institutional - Distillate
Oil
10 Commercial/Institutional - Residual
Oil
11 Commercial/Institutional - Natural
Gas
12 Commercial/Institutional - Wood
1 Residential Fuel - Anthracite Coal
2 Residential Fuel - Bituminous Coal
3 Residential Fuel - Distillate Oil
4 Residential Fuel - Residual Oil
5 Residential Fuel - Natural Gas
6 Residential Fuel - Wood
Miscellaneous Area Sources
2801500000 Agriculture Production - Crops -
Agricultural Field Burning (Total)
2801520000 Agriculture Production - Crops - Orchard
Heaters (Total)
2810001000 Other Combustion - Forest Wildfires
(Total)
2810015000 Other Combustion - Managed
(Slash/Prescribed) Burning (Total)
2810030000 Other Combustion - Structure Fires
62 Agricultural Field Burning
63 Frost Control - Orchard Heaters
60 Forest Wild Fires
61 Managed Burning - Prescribed
64 Structural Fires
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-127
1985-1996 Methodology
Other Combustion
-------
Table 4.4-5. Point Source Data Submitted
State
Alabama
Arkansas
Connecticut
Delaware
District of Columbia
Florida
Georgia - Atlanta
Urban Airshed (47
counties) domain
Georgia - Rest of
State
Illinois
Indiana
Kansas
Kentucky - Jefferson
County
Kentucky - Rest of
State
Louisiana
Maine
Maryland
Massachusetts
Michigan
Minnesota
Missouri
Nebraska
New Hampshire
New Jersey
New York
North Carolina
North Dakota
Ohio
Oklahoma
Pennsylvania -
Allegheny County
Pennsylvania -
Philadelphia County
Pennsylvania - Rest
of State
Rhode Island
South Carolina
Data Source/Format
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - EPS Workfile
State - EPS Workfile
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State format
AIRS-AFS - Ad hoc retrievals
State - EPS Workfiles
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
Jefferson County - EPS Workfile
State - EPS Workfile
State - State Format
State - EPS Workfile
State - EPS Workfile
State - EPS Workfile
State - State Format
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - EPS Workfile
State - EPS Workfile
State - EPS Workfile
State - EPS Workfiles
AIRS-AFS - Ad hoc retrievals
State - State Format
State - State Format
Allegheny County - County Format
Philadelphia County - County Format
State - EPS Workfile
State - EPS Workfile
AIRS-AFS - Ad hoc retrievals
Temporal
Resolution
Annual
Annual
Daily
Daily
Annual
Annual
Daily
Annual
Daily
Annual
Annual
Daily
Daily
Annual
Daily
Daily
Daily
Annual
Annual
Annual
Annual
Daily
Daily
Daily
Daily
Annual
Annual
Annual
Daily
Daily
Daily
Daily
Annual
Year of Data
1994
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1993
1990
1990
1990
1990
1990
1990
1990
1994
1990
1990
1990
1990
1991
Adjustments to Data
Backcast to 1990 using BEA. Average Summer
Day estimated using methodology described above.
Average Summer Day estimated using default
temporal factors.
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
None
Average Summer Day estimated using default
temporal factors.
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
None
None
Average Summer Day estimated using methodology
described above.
None
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
Backcast to 1990 using BEA. Average Summer
Day estimated using methodology described above.
Average Summer Day estimated using methodology
described above.
None
None
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
Backcast to 1990 using BEA. Average Summer
Day estimated using methodology described above.
None
None
None
None
Average Summer Day estimated using default
temporal factors.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-128
1985-1996 Methodology
Other Combustion
-------
Table 4.4-5 (continued)
State
Data Source/Format
Temporal
Resolution Year of Data Adjustments to Data
South Dakota AIRS-AFS - Ad hoc retrievals
Tennessee AIRS-AFS - Ad hoc retrievals
Texas State - State Format
Vermont State - EPS Workfile
Virginia AIRS-AFS - Ad hoc retrievals
West Virginia AIRS-AFS - Ad hoc retrievals
Wisconsin State - State Format
Annual 1990 Average Summer Day estimated using methodology
described above.
Annual 1990 Average Summer Day estimated using default
temporal factors.
Daily 1992 Backcast to 1990 using BEA.
Daily 1990 None
Annual 1990 Average Summer Day estimated using methodology
described above.
Annual 1990 Average Summer Day estimated using methodology
described above.
Daily 1990 None
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-129
1985-1996 Methodology
Other Combustion
-------
Table 4.4-6. Area Source Data Submitted
State
Data Source/Format
Temporal
Resolution Geographic Coverage
Adjustments to Data
Connecticut
Delaware
District of Columbia
Florida
Georgia
Illinois
Indiana
Kentucky
Louisiana
Maine
Maryland
Michigan
Missouri
New Hampshire
New Jersey
New York
North Carolina
Ohio
Pennsylvania
Rhode Island
Tennessee
Texas
Vermont
Virginia
West Virginia
Wisconsin
State - EPS Workfile Daily
State - EPS Workfile Daily
State - Hard copy Daily
AIRS-AMS-Ad hoc retrievals Daily
State - State format Daily
State - State format Daily
State - State format Daily
State - State Format Daily
State - State Format Daily
State - EPS Workfile Daily
State - EPS Workfile Daily
State - State Format Daily
AIRS-AMS- Ad hoc retrievals Daily
State - EPS Workfile Daily
State - EPS Workfile Daily
State - EPS Workfile Daily
State - EPS Workfiles Annual
State - Hard copy Daily
State - EPS Workfile Daily
State - EPS Workfile Daily
State - State format Daily
State - State Format Annual
State - EPS Workfile Daily
State - EPS Workfile Daily
AIRS-AMS - Ad hoc retrievals Daily
State - State Format Daily
Entire State
Entire State
Entire State
Jacksonville, Miami/
Ft. Lauderdale, Tampa
Atlanta Urban Airshed
(47 Counties)
Entire State
Entire State
Kentucky Ozone Nonattainment
Areas
Baton Rouge Nonattainment
Area (20 Parishes)
Entire State
Entire State
49 Southern Michigan Counties
St. Louis area (25 counties)
Entire State
Entire State
Entire State
Entire State
None
None
None
Added Non-road emission estimates
from Int. Inventory to Jacksonville
(Duval County)
None
None
Non-road emissions submitted were
county totals. Non-road emissions
distributed to specific SCCs based
on Int. Inventory
None
None
None
None
None
Only area source combustion data
was provided. All other area source
data came from Int. Inventory
None
None
None
Average Summer Day estimated
using default temporal factors.
Canton, Cleveland Columbus, Assigned SCCs and converted from
Dayton, Toledo, and Youngstown kgs to tons. NOX and CO from Int.
Inventory added to Canton, Dayton,
and Toledo counties.
Entire State Non-road emissions submitted were
county totals. Non-road emissions
distributed to specific SCCs based
on Int. Inventory
Entire State None
42 Counties in Middle
Tennessee
Entire State
Entire State
Entire State
Charleston, Huntington/Ashland,
and Parkersburg (5 counties
total)
Entire State
No non-road data submitted. Non-
road emissions added from Int.
Inventory
Average Summer Day estimated
using default temporal factors.
None
None
None
None
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-130
1985-1996 Methodology
Other Combustion
-------
Table 4.4-7. Ad Hoc Report
Criteria
Regn
DLL4
DLL4
DLL4
DLL4
DLL4
DLL4
DES4
DUE4
VI NV
GTO
CEVOC
CECO
CESO2
CE NO2
CE PM-10
CE PT
GEO
VIETY
VIE 90
Plant Output
VINV
SITE
CNTY
CYCD
7IPC
DNED
DNME
LAT1
_ON1
SIC1
OPST
SIRS
YEAR OF INVENTORY
STATE F I PS CODE
COUNTY FIPS CODE
CITY CODE
ZIP CODE
MEDS POINT ID
DLANT NAME
LATITUDE PLANT
_ONGITUDE PLANT
STANDARD INDUSTRIAL
CODE
OPERATING STATUS
STATE REGISTRATION
MUMBER
Point Output
STTE
CNTY
PNED
DNUM
CAPC
CAPU
DAT1
DAT2
DAT3
DAT4
MOHD
MODW
MOHY
STATE FIPS CODE
COUNTY FIPS CODE
NEDS POINT ID
DOINT NUMBER
DESIGN CAPACITY
DESIGN CAPACITY
UNITS
WINTER
THROUGHPUT
SPRING
THROUGHPUT
SUMMER
THROUGHPUT
-ALL THROUGHPUT
MUMBER HOURS/DAY
MUMBER DAYS/WEEK
MUMBER
HOURS/YEAR
Stack Output
STTE
CNTY
PNED
STNB
_AT2
_ON2
STHT
STDM
STET
STEV
STFR
DLHT
STATE FIPS CODE
COUNTY FIPS CODE
NEDS POINT ID
STACK NUMBER
_ATITUDE STACK
LONGITUDE STACK
STACK HEIGHT
STACK DIAMETER
STACK EXIT
TEMPERATURE
STACK EXIT VELOCITY
STACK FLOW RATE
DLUME HEIGHT
Segment Output
General
STTE
CNTY
DNED
STNB
DNUM
SEGN
SCC8
HEAT
ZPRT
SULF
^SHC
DODP
STATE FIPS CODE
COUNTY FIPS CODE
MEDS POINT ID
STACK NUMBER
DOINT NUMBER
SEGMENT NUMBER
sec
HEAT CONTENT
^NNUALFUEL
THROUGHPUT
SULFUR CONTENT
ASH CONTENT
DEAK OZONE SEASON
DAILY PROCESS RATE
Segment Output
Pollutant
STTE
CNTY
DNED
STNB
DNUM
SEGN
SCC8
DLL4
D034
DU04
DES4
DUE4
CLEE
CLT1
CTL2
REP4
DME4
Emfa
STATE FIPS CODE
COUNTY FIPS CODE
MEDS POINT ID
STACK NUMBER
DOINT NUMBER
SEGMENT NUMBER
sec
DOLLUTANTCODE
OSD EMISSIONS
OSD EMISSION UNITS
DEFAULT ESTIMATED
EMISSIONS
DEFAULT ESTIMATED
EMISSIONS UNITS
CONTROL
EFFICIENCY
DRIMARY CONTROL
DEVICE CODE
SECONDARY
CONTROL DEVICE
CODE
RULE
EFFECTIVENESS
VIETHODCODE
Emission factor
-------
Table 4.4-8. SEDS National Fuel Consumption, 1990-1996 (trillion Btu)
Fuel Type End-User
Code
1990
1991
1992
1993
1994
1995
1996
Anthracite Coal
Commercial
Residential
Bituminous Coal
Commercial
Residential
Distillate Fuel
Commercial
Residential
Kerosene
Commercial
Residential
Liquid Petroleum Gas
Commercial
Residential
Natural Gas
Commercial
Residential
Residual Fuel
Commercial
Population
ACCCB
ACRCB
BCCCB
BCRCB
DFCCB
DFRCB
KSCCB
KSRCB
LGCCB
LGRCB
NGCCB
NGRCB
RFCCB
TPOPP
12
19
80
43
487
837
12
64
64
365
2,698
4,519
233
248,709
11
17
72
39
482
832
12
72
69
389
2,808
4,685
213
252,131
11
17
75
40
464
865
11
65
67
382
2,884
4,821
191
255,025
11
16
72
40
464
913
14
76
70
399
2,996
5,097
175
257,785
11
16
70
40
450
887
13
67
70
398
3,035
5,132
170
259,693
11
16
69
39
435
862
12
59
70
397
3,074
5,166
168
261,602
11
16
68
39
422
836
11
51
70
397
3,114
5,201
167
263,510
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-132
1985-1996 Methodology
Other Combustion
-------
Table 4.4-9. BEA SA-5 National Earnings by Industry, 1990-1996 (million $)
Industry
LNUM
SIC
1990 1991 1992 1993 1994 1995 1996
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Farm
Farm
Farm
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Metal mining
Coal mining
Oil and gas extraction
Nonmetallic minerals, except fuels
Construction
Construction
Construction
Construction
Manufacturing
Durable goods
Lumber and wood products
Furniture and fixtures
Stone, clay, and glass products
Primary metal industries
Fabricated metal products
Machinery, except electrical
Electric and electronic equipment
Motor vehicles and equipment
Transportation equipment, excluding motor vehicles
Instruments and related products
Miscellaneous manufacturing industries
Nondurable goods
Food and kindred products
Tobacco manufactures
Textile mill products
Apparel and other textile products
Paper and allied products
Printing and publishing
Chemicals and allied products
Petroleum and coal products
Rubber and miscellaneous plastic products
020
030
040
041
045
046
047
050
060
070
071
072
081
082
090
100
110
120
121
122
123
200
210
220
230
240
300
310
320
330
400
410
413
417
420
423
426
429
432
435
438
441
444
450
453
456
459
462
465
468
471
474
477
999
999
999
999
999
999
999
999
999
999
999
999
1,2
1,2
1,2
7-9
7-9
7-9
7-9
7-9
7-9
7-9
10
11, 12
13
14
15-17
15-17
15-17
15-17
998
996
24
25
32
33
34
35
36
371
37
38
39
997
20
21
22
23
26
27
28
29
30
0
1
3,634
238
3,395
971
735
2,932
321
381
34
347
48
3,586
3,001
24
20
4
1
2
1
36
2
8
20
4
218
54
29
135
710
437
22
13
20
33
51
86
63
41
54
43
11
273
51
3
16
20
28
54
61
9
27
0
1
3,593
242
3,350
947
791
2,891
331
370
28
342
41
3,552
2,957
24
20
3
1
2
1
37
3
8
22
4
197
47
28
123
690
418
21
12
18
30
48
83
62
38
52
42
11
111
51
3
16
20
27
54
63
9
26
0
1
3,732
248
3,483
907
858
2,975
351
405
34
372
46
3,686
3,079
24
21
3
1
2
1
36
3
8
21
4
195
46
28
121
705
423
22
13
19
31
49
83
62
42
50
42
11
281
52
3
17
20
28
55
66
10
28
0
1
3,785
253
3,531
914
888
3,003
371
410
32
378
45
3,740
3,126
24
22
3
0
2
1
34
2
6
21
4
199
47
27
125
705
424
22
13
19
30
49
84
63
46
45
40
12
282
52
2
17
19
28
56
65
9
29
0
1
3,891
265
3,626
934
912
3,082
383
426
29
396
42
3,849
3,228
26
23
3
1
2
1
35
2
6
21
4
216
51
29
136
725
440
24
14
20
32
51
86
65
53
43
40
12
285
53
2
17
19
29
57
65
10
30
0
1
4,011
273
3,737
980
951
3,182
394
436
18
418
31
3,980
3,353
27
24
3
1
2
1
35
2
6
21
4
219
51
29
138
740
452
25
14
20
33
53
90
68
56
42
40
12
288
53
3
17
19
29
58
67
9
31
0
1
4,086
280
3,805
981
994
3,231
408
447
16
432
29
4,058
3,423
27
25
3
1
1
1
35
3
6
21
4
219
50
29
139
747
456
25
14
20
32
53
91
69
60
39
39
12
291
54
3
17
19
29
59
68
9
31
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-133
1985-1996 Methodology
Other Combustion
-------
Table 4.4-9 (continued)
Industry
LNUM
SIC
1990 1991 1992 1993 1994 1995 1996
Leather and leather products
Leather and leather products
Railroad transportation
Trucking and warehousing
Water transportation
Water transportation
Local and interurban passenger transit
Transportation by air
Pipelines, except natural gas
Transportation services
Communication
Electric, gas, and sanitary services
Wholesale trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Banking and credit agencies
Banking and credit agencies
Banking and credit agencies
Insurance
Insurance
Real estate
Holding companies and investment services
Services
Hotels and other lodging places
Personal services
Private households
Business and miscellaneous repair services
Auto repair, services, and garages
Auto repair, services, and garages
Amusement and recreation services
Amusement and recreation services
Health services
Legal services
Educational services
Social services and membership organizations
Social services and membership organizations
Social services and membership organizations
Social services and membership organizations
Miscellaneous professional services
Government and government enterprises
Federal, civilian
Federal, military
State and local
State and local
State and local
480
500
510
520
530
540
541
542
543
544
560
570
610
620
621
622
623
624
625
626
627
628
700
710
730
731
732
733
734
736
800
805
810
815
820
825
830
835
840
845
850
855
860
865
870
875
880
900
910
920
930
931
932
31
31
40
42
44
44
41
45
46
47
48
49
50,51
52-59
52-59
52-59
52-59
52-59
52-59
52-59
52-59
52-59
52-59
60,61
60,61
60,61
63,64
63,64
65,66
62,67
995
70
72
88
76
75
75
78,79
78,79
80
81
82
83,86
83,86
83,86
83,86
84, 87, 89
995
43,91,97
992
92-96
92-96
92-96
3
243
12
59
7
48
8
30
1
12
63
49
236
342
18
40
56
55
18
22
76
57
246
82
163
38
56
34
28
8
946
31
33
10
170
29
15
29
16
290
80
39
29
1
35
125
14
585
118
50
417
125
292
3
245
12
58
7
49
8
30
1
13
63
52
231
335
18
38
56
54
18
20
78
54
247
81
166
40
59
33
25
10
951
31
32
9
162
28
13
30
16
304
80
41
31
1
36
121
14
594
120
50
425
128
297
2
251
13
60
7
50
9
31
1
14
64
53
238
342
18
39
57
54
18
19
80
57
280
86
194
50
61
33
36
14
1,008
32
33
10
175
28
13
34
16
325
85
42
34
1
36
127
15
607
123
51
433
128
305
3
260
12
62
6
51
9
31
1
14
67
56
235
347
19
39
56
56
18
19
82
57
290
89
201
53
62
34
43
10
1,032
33
36
10
180
30
14
33
17
330
84
44
35
1
38
130
15
613
124
48
441
130
311
3
269
12
66
6
50
9
31
1
15
71
56
242
359
20
40
57
60
18
21
85
59
291
89
202
51
63
36
44
9
1,066
33
36
10
191
31
14
35
18
341
84
45
38
2
40
132
17
621
125
45
451
134
317
2
277
12
69
6
52
10
31
1
16
75
56
255
372
21
41
58
62
18
22
88
62
302
90
212
55
63
37
47
10
1,128
35
36
11
213
33
15
37
20
355
85
46
40
2
41
141
18
626
123
44
459
136
323
2
283
12
71
6
53
10
31
1
17
78
57
258
378
21
41
58
64
18
22
90
63
313
91
221
58
65
38
51
10
1,164
36
37
11
221
34
15
39
20
368
86
48
42
2
42
145
19
635
124
43
468
138
330
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Table 4.4-10. Area Source Listing by SCC and Growth Basis
NOTE(S):
SCC
2103001000
2103002000
2103004000
2103005000
2103006000
2103007000
2103008000
2103011000
2199004000
2199005000
2199006000
2199007000
2199011000
2810001000
2810003000
2810005000
2810010000
2810015000
2810025000
2810030000
2810035000
2810050000
2810060000
FILE
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
NG
SEDS
BEA
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
CODE
ACCCB
BCCCB
DFCCB
RFCCB
NGCCB
LGCCB
400
KSCCB
DFTCB
RFTCB
NGTCB
LGTCB
KSTCB
TPOPP
100
100
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
BEA Code is equal to LNUM on previous table.
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Table 4.4-11. Emission Estimates Available from AIRS/FS by State, Year, and Pollutant
State
1990
C N S P T V
1991
C N S P T V
1992
C N S P T V
1993
C N S P T V
1994
C N S P T V
1995
C N S P T V
Alabama
Alaska
Arizona
California
Colorado
Connecticut
Hawaii
Illinois
Louisiana
Michigan
Minnesota
Montana
Nebraska
Nevada
New Hampshire
New Mexico
North Dakota
Oregon
Pennsylvania
South Carolina
South Dakota
Texas
Utah
Vermont
Virginia
Washington
Wisconsin
Wyoming
Notes:
C = CO
N = NO2
S = SO,
P = PM-10 T = TSP
V = VOC
Pennsylvania only includes Allegheny County (State 42, County 003); New Mexico only includes Albuquerque (State 35, County 001); Washington only includes Puget Sound
(State 53, County 033, 053, or 061); Nebraska includes all except Omaha City (State 31, County 055); the CO emissions in NET were maintained for South Dakota (State 46).
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Table 4.4-12. NOX and VOC Major Stationary Source Definition
Marginal/Moderate 100
Serious 50
Severe 25
Extreme 1 0
Ozone Transport Region _ 50
Table 4.4-13. Summary of Revised NOX Control Efficiencies
Pod Estimated
ID Pod Name Efficiency Control
58 Commercial/Institutional - Coal 50 LNB
59 Commercial/Institutional - Oil 50 LNB
60 Commercial/Institutional - Gas 50 LNB
Controls: LNB - Low NOV Burner
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Table 4.4-14. Wildfires
Region
Fuel loading
Tons/Acre
Burned
Pollutant
Rocky Mountain
Pacific
North Central
South
East
37
19
11
9
11
Emission Factor
Ibs/ton
TSP
SO2
NOX
VOC
CO
PM-10
17
0.15
4
19.2
140
13
States Comprising Regions
South
Alabama
Arkansas
Florida
Georgia
Kentucky
Louisiana
Mississippi
North Carolina
Oklahoma
South Carolina
Tennessee
Texas
Virginia
East
Connecticut
Delaware
Maine
Maryland
Massachusetts
New Hampshire
New Jersey
New York
Pennsylvania
Rhode Island
Vermont
West Virginia
Rocky Mountain
Arizona
Colorado
Idaho
Kansas
Montana
Nebraska
Nevada
New Mexico
North Dakota
South Dakota
Utah
Wyoming
North Central
Illinois
Indiana
Iowa
Michigan
Minnesota
Missouri
Ohio
Wisconsin
Pacific
Alaska
California
Guam
Hawaii
Oregon
Washington
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Table 4.4-15. Emission Factors for Residential Wood Combustion by Pollutant
Pollutant
CO
NOX
voc
S02
PM-103
PM-2.53
Emission Factor
(Ibs/ton)
230.80
2.80
43.80
0.40
30.60
30.60
Emission Factor
(tons/cord)
1.342E-1
1.628E-3
2.547 E-2
2.326 E-4
1.779 E-2
1.779 E-2
aAII PM is considered to be less than 2.5 microns.
Table 4.4-16. PM Control Efficiencies for 1991 through 1996
Year
1991
1992
1993
1994
1995
1996
Control Efficiency
(%)
1.4
2.8
4.8
6.8
8.8
10.8
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4.5 SOLVENT UTILIZATION
The point and area source categories under the "Solvent Utilization" heading include the following
Tier I and Tier II categories:
Tier I Category Tier II Category
(08) SOLVENT UTILIZATION All subcategories
Since the publication of the last version of this report,1 EPA has made major changes to the 1990
emissions. The revised emissions are referred to in this document as the 1990 National Emission Trends
(NET) emissions and are for the most part based on State submitted data and used as the base year
inventory for the post-1990 emission inventory. Emission estimates for pre-1990 are based mainly on the
"old" 1990 emissions which are referred to in this document as the Interim Inventory 1990 emissions.
For most source categories, the methodology for the Interim Inventory 1990 emissions is the same as that
previously published in the Procedures document.
The 1990 Interim Inventory emissions for these source categories were generated from the point
source source portions of the 1985 National Acid Precipitation Assessment Program (NAPAP) Emissions
Inventory. The VOC area source emissions were based on a national mass balance as described in section
4.5.1.1. These 1990 emissions served as the base year from which the emissions for the years 1985
through 1989 were estimated. The emissions for the years 1985 through 1989 were estimated using
historical data compiled by the Bureau of Economic Analysis (BEA).2
The 1990 NET emissions were revised to incorporate as much state- supplied data as possible.
Sources of state data include the OTAG emission inventory (EPA used the 1990 Interim Inventory data
inplace of state submitted VOC area source emissions), the GCVTC emission inventory, and AIRS/FS.
For most point sources, these emissions were projected from the revised 1990 NET inventory to the
years 1991 through 1996 using BEA and SEDS data. States were surveyed to determine whether EPA
should project their 1990 non-utility point source emissions or extract them from AIRS/FS. For all states
that selected AIRS/FS option, the emissions in the NET inventory reflect their AIRS/FS data for the
years 1991 through 1995. Additional controls were added to the projected (or grown) emissions for the
year 1996.
This section describes the methods used to estimate both base year 1990 emission inventories and
the emission estimates for the years 1985 through 1989 and 1991 through 1996. Point Source emissions
for the years 1985-1996 were estimated for the pollutants VOC, CO, NOX, SO2, and PM-10. Area
source emissions were estimated for only 1985 through 1989 for VOC. Area source emissions for the
years 1990 through 1996 were estimated for VOC, NOX, and CO. Point source emission estimates for
PM-2.5 were only estimated for the years 1990 through 1996.
4.5.1 1990 Interim Inventory
Solvent utilization emissions are included as both point and area sources in the Emission Trends
inventory. Point source emissions were based on the 1985 NAPAP inventory (see section 4.5.1.2). The
basis for the VOC area source component is a material balance on total nationwide solvent consumption.
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(There are no area source CO, NOX, SO2, and PM emissions in the NET inventory for the years 1985
through 1989. The 1990 through 1996 area source CO and NOX emissions estimates were not estimated
with this methodology.) Total nationwide solvent emissions by end-use category are estimated from
national consumption figures with some adjustments to account for air pollution controls and waste
management practices. The nationwide emissions are then apportioned to states and counties using
census data and information on state and local regulations pertaining to solvent emissions. County- and
category-level point source emissions are then subtracted from the emission totals, and the remaining
emissions are included in the area source solvent inventory. Section 4.5.1.1 describes the development of
national solvent emissions and apportionment to states and counties.
4.5.1.1 Area Source Emissions, VOC Only
Volatile organic compound emissions are estimated for area sources by first estimating national total
emissions that are distributed to county and end user, described in this section, and then subtracting the
point source emissions, described in section 4.5.1.2.
4.5.1.1.1 Overall National Emissions Estimates —
The overall national solvents material balance can be summarized as follows:
National solvent ., . , , „ , , ,, Solvents conveyed to
,, , National solvent Solvents destroyed by /T- /i c 1 \
emissions (by end-use = . -.„.,- waste management (Eq.4.5-1)
, consumption air pollution controls . \ i ;
category) operations
Note that this overall national material balance yields total solvent emissions, including both point and
area sources.
National solvent usage estimates by end-use category were obtained from three main sources. For
paints and coatings, the main source was the U.S. Paint Industry Data Base, prepared by SRI
International for the National Paint and Coatings Association.3 Solvent usage estimates for other
categories were obtained from industrial solvent marketing reports.4'5 The base year for this activity data
and for the total solvent emissions is 1989.
The solvent emission methodology is designed to incorporate pollution control and waste
management information at the source category level. However, the timeframe for the NET inventory
effort was too tight to permit development of category-specific information. The mass balance term for
waste management was based on the EPA's data base6 for TSDFs, which also forms the basis for the
TSDF portion of the NET inventory. (See section 4.3.1.5 for details on TSDF emissions.) In essence,
the portion of the TSDF inventory that is attributable to solvents is deducted from the current solvents
inventory in order to avoid double-counting. The TSDF deduction was apportioned evenly to all
industrial categories, and amounts to about 21 percent of total solvent usage in these categories.
Solvent destruction adjustments in the nationwide material balance were based on the same
assumptions used for the 1985 National Emissions Data System (NEDS) and the 1985 NAPAP
inventory. According to the data in NEDS and 1985 NAPAP inventory, approximately 16 percent of
industrial surface coating emissions are assumed to be destroyed in air pollution controls.
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Table 4.5-1 lists the elements in the national solvent material balance by emission source category.
As discussed above, these elements are: national solvent consumption, solvent destroyed in air pollution
controls, solvent sent to waste management operations, and net solvent emissions. Table 4.5-1 also
summarizes the major sources of these data.
4.5.1.1.2 Distribution of Solvent Emissions to States and Counties —
The primary tools used to distribute national solvent emissions to states and counties are 1988
census data bases.7'8'9 For each of the source categories listed in Table 4.5-1, state- and county-level
solvent usage is assumed to be proportional to a particular census measure. For consumer end-use
categories, solvent usage was distributed based on population. County-level employment data were used
for commercial and industrial end-use categories. Census data on the number of farm acres treated with
chemical sprays were used to distribute pesticide solvent usage. Table 4.5-2 lists the specific census data
used for each emission category.
State and local regulations covering solvent emissions were also incorporated in the spatial
distribution step for the solvent inventories. For an industrial or commercial end-use category, the overall
spatial distribution calculation can be summarized as follows:
,, . . „ , Estimated control efficiency for
County emissions ,, . , County employment '
,,J , National county ,_ . c ~,
(by end-use = . . x — ; x -—. •* ; (Eq. 4.5-2)
- emissions National Nationwide average control
category) ff • f t
employment efficiency far category
Quantitative information on state- and county-level control efficiency, rule effectiveness, and rule
penetration was obtained primarily from surveys carried out under EPA's ROM modeling effort.10 For
states outside the ROM domain, these parameters were estimated using Bureau of National Affairs
regulation summaries.
4.5.1.1.3 Deduction of Point Source Emissions —
The area source inventory is produced by deducting point source emissions from the county-level
category emission totals produced in Equation 4.5-3. The calculation is performed as follows:
County-level area source _ , , , „ 77-
,, , Total county-level County-level point source /T-, A c -,\
emissions (by end-use = . . ,.-,,- . (Eq. 4.5-3)
, emissions (equation 2) emissions ^ n '
category)
The AIRS/AMS solvent categories were first matched to the corresponding point source SCCs.
Using the 1990 Interim Inventory, point source totals by county for each corresponding AMS SCC were
calculated. These emissions were then subtracted from the total solvent emissions (the 1989 total solvent
emissions were projected to 1990 as described below) to yield the area source emissions. In the cases of
negative emissions (higher point source emissions than total estimated solvent emissions), the 1985
NAPAP methodology11 was followed — area source emissions were set to zero.
Then the non-zero county values were readjusted so that the sum of all county area source emissions
equal the difference between the total national emissions and the national point source emissions;
otherwise, area source emissions are underestimated.
'National Air Pollutant Emission Trends 1985-1996 Methodology
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All County National National
Area Source = Total - Point Source (Eq. 4.5-4)
Emissions Emissions Emissions
4.5.1.2 Point Sources, All Pollutants
The 1985 NAPAP inventory estimates for the point sources have been projected to the year 1990
based on the growth in BEA historic earnings for the appropriate state and industry,2 as identified by the
two-digit SIC code. To remove the effects of inflation, the earnings data were converted to 1982
constant dollars using the implicit price deflator for PCE.12 State and SIC-level growth factors were
calculated as the ratio of the 1990 earnings data to the 1985 earnings data. Additional information on
point source growth indicators is presented in section 4.5.1.2.2.
When creating the 1990 emission inventory, changes were made to emission factors, control
efficiencies, and emissions from the 1985 inventory for all sources. The PM-10 control efficiencies were
obtained from the PM-10 Calculator.13 In addition, rule effectiveness which was not applied in the 1985
NAPAP inventory, was applied to the 1990 emissions estimated for the point sources. The CO, NOX, and
VOC point source controls were assumed to be 80 percent effective; PM-10 and SO2 controls were
assumed to be 100 percent effective.
The 1990 emissions for CO, NOX, SO2, and VOC were calculated using the following steps:
(1) projected 1985 controlled emissions to 1990 using the appropriate growth factors, (2) calculated the
uncontrolled emissions using control efficiencies from the 1985 NAPAP inventory, and (3) calculated the
final 1990 controlled emissions using revised control efficiencies and the appropriate rule effectiveness.
The 1990 PM-10 emissions were calculated using the TSP emissions from the 1985 NAPAP inventory.
The 1990 uncontrolled TSP emissions were estimated in the same manner as the other pollutants. The
1990 uncontrolled PM-10 estimates were calculated from these TSP emissions by applying SCC-specific
uncontrolled particle size distribution factors.14 The controlled PM-10 emissions were estimated in the
same manner as the other pollutants.
4.5.1.2.1 Control Efficiency Revisions —
In the 1985 NAPAP point source estimates, control efficiencies for VOC, NOX, CO, and SO2
sources in Texas were judged to be too high for their process/control device combination. These high
control efficiencies occurred because Texas did not ask for control efficiency information, and simply
applied the maximum efficiency for the reported control device. High control efficiencies lead to high
future growth in modeling scenarios based on uncontrolled emissions (which are based on the control
efficiency and reported actual emissions). High control efficiencies also lead to extreme increases in
emissions when rule effectiveness is incorporated.
Revised VOC control efficiencies were developed for Texas for the ERCAM-VOC.15 For this
analysis, revised efficiencies were also developed by SCC and control device combination for NOX, SO2,
and CO using engineering judgement. These revised control efficiencies were applied to sources in
Texas. A large number of point sources outside of Texas had VOC and CO control efficiencies that were
also judged to be too high. The VOC and CO control efficiencies used for Texas were also applied to
these sources.
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4.5.1.2.2 Rule Effectiveness Assumptions —
Controlled emissions for each inventory year were recalculated, assuming that reported VOC, NOX,
and CO controls were 80 percent effective. Sulfur dioxide and PM-10 controls were assumed to be 100
percent effective.
4.5.1.2.3 Emissions Calculations —
A three-step process was used to calculate emissions incorporating rule effectiveness. First, base
year controlled emissions are projected to the inventory year using the following equation (Equation
4.5-5):
CE. = CEM + (CEBY x EG} (Eq. 4.5-5)
where: CE; = controlled emissions for inventory year i
CEBY = controlled emissions for base year
EG; = earnings growth for inventory year i
Earnings growth is calculated using Equation 4.5-6.
DAT
EGi = ! - J^T (Eq- 4.5-6)
L)A1BY
where: EG; = earnings growth for year i
DAT; = earnings data for inventory year i
DATBY = earnings data in the base year
Second, uncontrolled emissions in the inventory year are back-calculated from the controlled emissions
based on the control efficiency using Equation 4.5-7:
CE.
UE. =
1 _ CEFF\ (Eq. 4.5-7)
I 100 J
where: UE; = uncontrolled emissions for inventory year i
CE; = controlled emissions for inventory year i
CEFF = control efficiency (percent)
Third, controlled emissions are recalculated incorporating rule effectiveness using the following equation
(Equation 4.5-8):
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CER. = UC.
1 -
REFF]
100 j
CEFF\
100 I
(Eq. 4.5-8)
where: CER; = controlled emissions incorporating rule effectiveness
UQ = uncontrolled emissions
REFF = rule effectiveness (percent)
CEFF = control efficiency (percent)
4.5.2 Emissions, 1985 to 1989
As explained in section 4.5.1.2.3, the 1990 controlled point source emissions were projected from
the 1985 NAPAP inventory using Equations 4.5-4 through 4.5-7. For all other years (1985 to 1989), the
emissions were projected from the 1990 emissions using Equations 4.5-4 and 4.5-7. Therefore, the 1985
emissions estimated by this method do not match the 1985 NAPAP inventory due to the changes made in
control efficiencies and emission factors and the addition of rule effectiveness when creating the 1990
base year inventory. Area source emissions are detailed in section 4.5.2.1.
4.5.2.1 Area Sources
The total solvent inventory was based on 1989 activity- level data. (Spatial allocations for the
solvent area source inventory were based on the 1988 census, which provides the most recent data
available at the county level.) Projections to other years (1985 to 1990) are based on state-level earnings
data for major industrial categories, which generally correspond to two-digit SICs. The following
algorithm is used for the emission projection:
Projection year emissions (by county
and end-use category)
Base year emissions
Projection year
earnings (by state
and 2-digit SIC)
Base year earnings
(Eq. 4.5-9)
In this equation, the projection year represents the appropriate calendar year for the Emission Trends
inventory (ranging from 1985 to 1990). The total solvent inventory was first projected to 1990 to
complete the point source deduction described above. After deducting the point source solvents, this
1990 area source solvent data base was then scaled-back/projected to the other inventory years.
The county/source category emissions predicted using changes in BEA earnings data were then
scaled according to expected changes in national solvent emissions. Annual changes in national solvent
usage (by end-use category) were taken from the solvent marketing reports.4'5 All county-level emissions
within an end-use category were scaled by a factor so that total national emissions would be equivalent to
the national solvent emissions reported in the literature.
4.5.2.2 Point Sources
The changes in the point source emissions were equated with the changes in historic earnings by
state and industry. Emissions from each point source in the 1985 NAPAP inventory were projected to
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the years 1985 through 1990 based on the growth in earnings by industry (two-digit SIC code).
Historical annual state and industrial earnings data from BEA's Table SA-5 (Reference 2) were used to
represent growth in earnings from 1985 through 1990.
The 1985 through 1990 earnings data in Table SA-5 are expressed in nominal dollars. To estimate
growth, these values were converted to constant dollars to remove the effects of inflation. Earnings data
for each year were converted to 1982 constant dollars using the implicit price deflator for PCE.12 The
PCE deflators used to convert each year's earnings data to 1982 dollars are:
Year 1982 PCE Deflator
1985 111.6
1987 114.3
1988 124.2
1989 129.6
1990 136.4
Several BEA categories did not contain a complete time series of data for the years 1985 through
1990. Because the SA-5 data must contain 1985 earnings and earnings for each inventory year (1985
through 1990) to be useful for estimating growth, a log linear regression equation was used where
possible to fill in missing data elements. This regression procedure was performed on all categories that
were missing at least one data point and which contained at least three data points in the time series.
Each record in the point source inventory was matched to the BEA earnings data based on the state
and the two-digit SIC. Table 4.5-3 shows the BEA earnings category used to project growth for each of
the two-digit SICs found in the 1985 NAPAP inventory. No growth in emissions was assumed for all
point sources for which the matching BEA earnings data were not complete. Table 4.5-3 also shows the
national average growth and earnings by industry from Table SA-5.
4.5.3 1990 National Emission Trends
The 1990 National Emission Trends is based primarily on state data, with the 1990 interim data
filling in the gaps. The data base houses U.S. annual and average summer day emission estimates for the
50 states and the District of Columbia. Seven pollutants (CO, NOX, VOC, SO2, PM-10, PM-2.5, and
NH3) were estimated in 1990. The state data were extracted from three sources, the OTAG inventory,
the GCVTC inventory, and AIRS/FS. Sections 4.5.3.1, 4.5.3.2, and 4.5.3.3 give brief descriptions of
these efforts. Section 4.5.3.4 describes the efforts necessary to supplement the inventory gaps that are
either temporal, spacial, or pollutant. 1990 area source VOC emissions are detailed in section 4.5.1.
Since EPA did not receive documentation on how these inventories were developed, this section
only describes the effort to collect the data and any modifications or additions made to the data.
4.5.3.1 OTAG
The OTAG inventory for 1990 was completed in December 1996. The data base houses emission
estimates for those states in the Super Regional Oxidant A (SUPROXA) domain. The estimates were
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developed to represent average summer day emissions for the ozone pollutants (VOC, NOX, and CO).
This section gives a background of the OTAG emission inventory and the data collection process.
4.5.3.1.1 Inventory Components —
The OTAG inventory contains data for all states that are partially or fully in the SUPROXA
modeling domain. The SUPROXA domain was developed in the late 1980s as part of the EPA regional
oxidant modeling (ROM) applications. EPA had initially used three smaller regional domains (Northeast,
Midwest, and Southeast) for ozone modeling, but wanted to model the full effects of transport in the
eastern United States without having to deal with estimating boundary conditions along relatively high
emission areas. Therefore, these three domains were combined and expanded to form the Super Domain.
The western extent of the domain was designed to allow for coverage of the largest urban areas in the
eastern United States without extending too far west to encounter terrain difficulties associated with the
Rocky Mountains. The Northern boundary was designed to include the major urban areas of eastern
Canada. The southern boundary was designed to include as much of the United States as possible, but
was limited to latitude 26 °N, due to computational limitations of the photochemical models. (Emission
estimates for Canada were not extracted from OTAG for inclusion in the NET inventory.)
The current SUPROXA domain is defined by the following coordinates:
North: 47.00°N East: 67.00°W
South: 26.00°N West: 99.00°W
Its eastern boundary is the Atlantic Ocean and its western border runs from north to south through North
Dakota, South Dakota, Nebraska, Kansas, Oklahoma, and Texas. In total, the OTAG Inventory
completely covers 37 states and the District of Columbia.
The OTAG inventory is primarily an ozone precursor inventory. It includes emission estimates of
VOC, NOX, and CO for all applicable source categories throughout the domain. It also includes a small
amount of SO2 and PM-10 emission data that was sent by states along with their ozone precursor data.
No quality assurance (QA) was performed on the SO2 and PM-10 emission estimates for the OTAG
inventory effort.
Since the underlying purpose of the OTAG inventory is to support photochemical modeling for
ozone, it is primarily an average summer day inventory. Emission estimates that were submitted as
annual emission estimates were converted to average summer day estimates using operating schedule data
and default temporal profiles and vice versa.
The OTAG inventory is made up of two major components: (1) the point source component, which
includes segment/pollutant level emission estimates and other relevant data (e.g., stack parameters,
geographic coordinates, and base year control information) for all stationary point sources in the domain;
(2) the area source component, which includes county level emission estimates for all stationary area
sources. The NET inventory extracted all point sources except utility emissions.
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4.5.3.1.2 Interim Emissions Inventory (OTA G Default) —
The primary data sources for the OTAG inventory were the individual states. Where states were
unable to provide data, the 1990 Interim Inventory 16 was used for default inventory data. A more
detailed description of the 1990 Interim Inventory is presented in section 4.5.1.
4.5.3.1.3 State Data Collection Prodedures —
Since the completion of the Interim Inventory in 1992, many states had completed 1990 inventories
for ozone nonattainment areas as required for preparing SIPs. In addition to these SIP inventories, many
states had developed more comprehensive 1990 emission estimates covering their entire state. Since
these state inventories were both more recent and more comprehensive than the Interim Inventory, a new
inventory was developed based on state inventory data (where available) in an effort to develop the most
accurate emission inventory to use in the OTAG modeling.
On May 5, 1995, a letter from John Seitz (Director of EPA's Office of Air Quality Planning and
Standards [OAQPS]) and Mary Gade (Vice President of ECOS) to State Air Directors, states were
requested to supply available emission inventory data for incorporation into the OTAG inventory.17
Specifically, states were requested to supply all available point and area source emissions data for VOC,
NOX, CO, SO2, and PM-10, with the primary focus on emissions of ozone precursors. Some emission
inventory data were received from 36 of the 38 states in the OTAG domain. To minimize the burden to
the states, there was no specified format for submitting State data. The majority of the state data was
submitted in one of three formats:
1) an Emissions Preprocessor System Version 2.0 (EPS2.0) Workfile
2) an ad hoc report from AIRS/FS
3) data files extracted from a state emission inventory data base
The origin of data submitted by each state is described in section 4.5.3.1.4.1 for point sources and
4.5.3.1.4.2 for area sources.
4.5.3.1.4. State Data Incorporation Procedures/Guidelines —
The general procedure for incorporating state data into the OTAG Inventory was to take the data
"as is" from the state submissions. There were two main exceptions to this policy. First, any inventory
data for years other than 1990 was backcast to 1990 using BEA Industrial Earnings data by state and
two-digit SIC code.2 This conversion was required for five states that submitted point source data for the
years 1992 through 1994. All other data submitted were for 1990.
Second, any emission inventory data that included annual emission estimates but not average
summer day values were temporally allocated to produce average summer day values. This temporal
allocation was performed for point and area data supplied by several states. For point sources, the
operating schedule data, if supplied, were used to temporally allocate annual emissions to average
summer weekday using Equation 4.5-10.
EMISSIONSASD = EMISSIONSANNUAL * SUMTHRU * 1/(13 * DPW) (Eq. 4.5-10)
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where: EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
SUMTHRU = summer throughput percentage
DPW = days per week in operation
If operating schedule data were not supplied for the point source, annual emissions were temporally
allocated to an average summer weekday using EPA's default Temporal Allocation file. This computer
file contains default seasonal and daily temporal profiles by SCC. Equation 4.5-11 was used.
EMISSIONSASD = EMISSIONSANNUAL I (SUMFACSCC * WDFACSCC) (Eq. 4.5-11)
where: EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
SUMFACSCC = default summer season temporal factor for SCC
WDFACSCC = default summer weekday temporal factor for SCC
There were a small number of SCCs that were not in the Temporal Allocation file. For these SCCs,
average summer weekday emissions were assumed to be the same as those for an average day during the
year and were calculated using Equation 4.5-12.
EMISSIONSASD = EMISSIONSANNUAL I 365 (eq. 4.5-12)
where: EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
4.5.3.1.4.1 Point. For stationary point sources, 36 of the 38 states in the OTAG domain supplied
emission estimates covering the entire state. Data from the Interim Inventory were used for the two
states (Iowa and Mississippi) that did not supply data. Most states supplied 1990 point source data,
although some states supplied data for later years because the later year data reflected significant
improvements over their 1990 data. Inventory data for years other than 1990 were backcast to 1990
using BEA historical estimates of industrial earnings at the 2-digit SIC level. Table 4.5-4 provides a brief
description of the point source data supplied by each state.
4.5.3.1.4.2 Area. For area sources, 17 of the 38 states in the OTAG domain supplied 1990 emission
estimates covering the entire state, and an additional nine states supplied 1990 emission estimates
covering part of their state (partial coverage was mostly in ozone nonattainment areas). Interim
Inventory data were the sole data source for 12 states. Where the area source data supplied included
annual emission estimates, the default temporal factors were used to develop average summer daily
emission estimates. Table 4.5-5 provides a brief description of the area source data supplied by each
state.
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4.5.3.1.4.5 Rule Effectiveness. For the OTAG inventory, states were asked to submit their best
estimate of 1990 emissions. There was no requirement that state-submitted point source data include rule
effectiveness for plants with controls in place in that year. States were instructed to use their judgment
about whether to include rule effectiveness in the emission estimates. As a result, some states submitted
estimates that were calculated using rule effectiveness, while other states submitted estimates that were
calculated without using rule effectiveness.
The use of rule effectiveness in estimating emissions can result in emission estimates that are much
higher than estimates for the same source calculated without using rule effectiveness, especially for
sources with high control efficiencies (95 percent or above). Because of this problem, there was concern
that the OTAG emission estimates for states that used rule effectiveness would be biased to larger
estimates relative to states that did not include rule effectiveness in their computations.
To test if this bias existed, county-level maps of point source emissions were developed for the
OTAG domain. If this bias did exist, one would expect to see sharp differences at state borders between
states using rule effectiveness and states not using rule effectiveness. Sharp state boundaries were not
evident in any of the maps created. Based on this analysis, it was determined that impact of rule
effectiveness inconsistencies was not causing large biases in the inventory.
4.5.3.2 Grand Canyon Visibility Transport Commission Inventory
The 1990 GCVTC inventory includes detailed emissions data for 11 states: Arizona, California,
Colorado, Idaho, Montana, Nevada, New Mexico, Oregon, Utah, Washington, and Wyoming.18 This
inventory was developed by compiling and merging existing inventory data bases. The primary data
sources used were state inventories for California and Oregon, AIRS/FS for VOC, NOX, and SO2 point
source data for the other nine states, the 1990 Interim Inventory for area source data for the other nine
states, and the 1985 NAPAP inventory for NH3 and TSP data. In addition to these existing data, the
GCVTC inventory includes newly developed emission estimates for forest wildfires and prescribed
burning.
After a detailed analysis of the GCVTC inventory, it was determined that the following portions of
the GCVTC inventory would be incorporated into the 1990 NET inventory:
• complete point and area source data for California
• complete point and area source data for Oregon
• forest wildfire data for the entire 11-state region
• prescribed burning data for the entire 11-state region
State data from California and Oregon were incorporated because they are complete inventories
developed by the states and are presumably based on more recent, detailed and accurate data than the
Interim Inventory (some of which is still based on the 1985 NAPAP inventory). The wildfire data in the
GCVTC inventory represent a detailed survey of forest fires in the study area and are clearly more
accurate than the wildfire data in the Interim Inventory. The prescribed burning data in the GCVTC
inventory are the same as the data in the Interim Inventory.
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Non-utility point source emission estimates in the GCVTC inventory from states other than
California and Oregon came from AIRS/FS. Corrections were made to this inventory to the VOC and
PM emissions. The organic emissions reported in GCVTC inventory for California are total organics
(TOG). These emissions were converted to VOC using the profiles from EPA's SPECIATE19 data base.
Since the PM emissions in the GCVTC were reported as both TSP and PM-2.5, EPA estimated PM-10
from the TSP in a similar manner as described in section 4.5.1.2.
4.5.3.3 AIRS/FS
SO2 and PM-10 (or PM-10 estimated from TSP) sources of greater than 250 tons per year as
reported to AIRS/FS that were not included in either the OTAG or GCVTC inventories were appended
to the NET inventory. The data were extracted from AIRS/FS using the data criteria set listed in table
4.5-6. The data elements extracted are also listed in Table 4.5-6. The data were extracted in late
November 1996. It is important to note that estimated emissions were extracted.
4.5.3.4 Data Gaps
As stated above, the starting point for the 1990 NET inventory is the OTAG, GCVTC, AIRS, and
1990 Interim inventories. Data added to these inventories include estimates of SO2, PM-10, PM-2.5, and
NH3, as well as annual or ozone season daily (depending on the inventory) emission estimates for all
pollutants. This section describes the steps taken to fill in the gaps from the other inventories.
4.5.3.4.1 SO2 and PM Emissions —
For SO2 and PM-10, state data from OTAG were used where possible. (The GCVTC inventory
contained SO2 and PM annual emissions.) In most cases, OTAG data for these pollutants were not
available. For point sources, data for plants over 250 tons per year for SO2 and PM-10 were added from
AIRS/FS. The AIRS/FS data were also matched to the OTAG plants and the emissions were attached to
existing plants from the OTAG data where a match was found. Where no match was found to the plants
in the OTAG data, new plants were added to the inventory. For OTAG plants where there were no
matching data in AIRS/FS and for all area sources of SO2 and PM-10, emissions were calculated based
on the emission estimates for other pollutants.
The approach to developing SO2 and PM-10 emissions from unmatched point and area sources
involved using uncontrolled emission factor ratios to calculate uncontrolled emissions. This method used
SO2 or PM-10 ratios to NOX. NOX was the pollutant utilized to calculate the ratio because (1) the types
of sources likely to be important SO2 and PM-10 emitters are likely to be similar to important NOX
sources and (2) the generally high quality of the NOX emissions data. Ratios of SO2/NOX and PM-10/NOX
based on uncontrolled emission factors were developed. These ratios were multiplied by uncontrolled
NOX emissions to determine either uncontrolled SO2 or PM-10 emissions. Once the uncontrolled
emissions were calculated, information on VOC, NOX, and CO control devices was used to determine if
they also controlled SO2 and/or PM-10. If this review determined that the control devices listed did not
control SO2 and/or PM-10, plant matches between the OTAG and Interim Inventory were performed to
ascertain the SO2 and PM-10 controls applicable for those sources. The plant matching component of
this work involved only simple matching based on information related to the state and county FIPS code,
along with the plant and point IDs.
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There was one exception to the procedures used to develop the PM-10 point source estimates. For
South Carolina, PM-10 emission estimates came from the Interim Inventory. This was because South
Carolina had no PM data in AIRS/FS for 1990 and using the emission factor ratios resulted in
unrealistically high PM-10 emissions.
There were no PM-2.5 data in either OTAG or AIRS/FS. Therefore, the point and area PM-2.5
emission estimates were developed based on the PM-10 estimates using source-specific uncontrolled
particle size distributions and particle size specific control efficiencies for sources with PM-10 controls.
To estimate PM-2.5, uncontrolled PM-10 was first estimated by removing the impact of any PM-10
controls on sources in the inventory. Next, the uncontrolled PM-2.5 was calculated by multiplying the
uncontrolled PM-10 emission estimates by the ratio of the PM-2.5 particle size multiplier to the PM-10
particle size multiplier. (These particle size multipliers represent the percentage to total particulates
below the specified size.) Finally, controls were reapplied to sources with PM-10 controls by multiplying
the uncontrolled PM-2.5 by source/control device particle size specific control efficiencies.
4.5.3.4.5 Other Modifications —
Additional QA/quality control (QC) of the inventory resulted in the following changes:
• Emissions with SCCs of fewer than eight digits or starting with a digit greater than the number
"6" were deleted because they are invalid codes.
• Checked and fixed sources with PM-2.5 emissions which were greater than their PM-10
emissions.
• Checked and fixed sources with PM-10 emissions greater than zero and PM-2.5 emissions
equal to zero.
4.5.4 Emissions, 1991 to 1994
The 1991 through 1994 area VOC source emissions were grown using the Economic Growth
Analysis System (E-GAS). The point source and NOX and CO area source inventory was also grown for
those states that did not want their AIRS/FS data used. (The list of states are detailed in the AIRS/FS
subsection, 4.5.4.2.) For those states requesting that EPA extract their data from AIRS/FS, the years
1990 through 1995 were downloaded from the EPA IBM Mainframe. The 1996 emissions were not
extracted since states are not required to have the 1996 data uploaded into AIRS/FS until July 1997.
4.5.4.1 Grown Estimates
The 1991 through 1994 point and area source emissions were grown using the 1990 NET inventory
as the basis. The algorithm for determining the estimates is detailed in section 4.5.1.2.3. The 1990
through 1996 SEDS20 and BEA data are presented in Tables 4.5-7 and 4.5-8. The 1996 BEA and SEDS
data were determined based on linear interpretation of the 1988 through 1995 data. Point sources were
projected using the first two digits of the SIC code by state. Area source emissions were projected using
either BEA or SEDS. Table 4.5-9 lists the SCC and the source for growth.
The 1990 through 1996 earnings data in BEA Table SA-5 (or estimated from this table) are
expressed in nominal dollars. In order to be used to estimate growth, these values were converted to
constant dollars to remove the effects of inflation. Earnings data for each year were converted to 1992
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constant dollars using the implicit price deflator for PCE. The PCE deflators used to convert each year's
earnings data to 1992 dollars are:
Year 1992 PCE Deflator
1990 93.6
1991 97.3
1992 100.0
1993 102.6
1994 104.9
1995 107.6
1996 109.7
The 1991through 1994 emissions for VOC area source emissions were estimated by applying growth
factors to the 1990 emissions using a modified version of Equation 4.5-13. The growth factors were
obtained from the prereleased E-GAS, version 2.O.21 The E-GAS generates growth factors at the SCC-
level for counties representative of all counties within each ozone nonattainment area classified as serious
and above and for counties representative of all counties within both the attainment portions and the
marginal and moderate nonattainment areas within each state. The appropriate growth factors were
applied by county and SCC to the 1990 emissions as shown by Equation 4.5-13.
Emissions (countyfCCtyear} = Growth(county>scc>year} * Emissions (countyfCCtl990} (Eq. 4.5-13)
There are approximately 150 representative counties in E-GAS and 2000 SCCs present in the base
year inventory. This yields a matrix of 300,000 growth factors generated to determine a single year's
inventory. To list all combinations would be inappropriate.
4.5.4.2 AIRS/FS
Several states responded to EPA's survey and requested that their 1991 through 1995 estimates
reflect their emissions as reported in AIRS/FS. The list of these states, along with the years available in
AIRS/FS is given in Table 4.5-10. As described in section 4.5.3.3, default estimated annual and ozone
season daily emissions (where available) were extracted from AIRS/FS. Some changes were made to
these AIRS/FS files. For example, the default emissions for some states contain rule effectiveness and the
emissions were determined to be too high by EPA. The emissions without rule effectiveness were
extracted from AIRS/FS and replaced the previously high estimates. The changes made to select state
and/or plant AIRS/FS data are listed below.
• Louisiana All VOC source emissions were re-extracted to obtain
emissions without rule effectiveness for the year 1994.
• Colorado - Mastercraft The VOC emissions were reported as ton/year in the initial
download from AIRS. The units were changed to
pounds/year in AIRS.
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• Wisconsin - Briggs and Stratton The VOC emissions for two SCCs were changed from with
rule effectiveness to without rule effectiveness for the years
1991, 1993, and 1994.
As noted in Table 4.5-10, several states did not report emissions for all pollutants for all years for
the 1990 to 1995 time period. To fill these data gaps, EPA applied linear interpolation or extrapolated
the closest two years worth of emissions at the plant level. If only one year of emissions data were
available, the emission estimates were held constant for all the years. The segment-SCC level emissions
were derived using the average split for all available years. The non-emission data gaps were filled by
using the most recent data available for the plant.
As described in section 4.5.3.4.1, many states do not provide PM-10 emissions to AIRS. These
states' TSP emissions were converted to PM-10 emissions using uncontrolled particle size distributions
and AP-42 derived control efficiencies. The PM-10 emissions are then converted to PM-2.5 in the same
manner as described in section 4.5.1.4. The State of South Carolina provided its own conversion factor
for estimating PM-10 from TSP.22
For all sources that did not report ozone season daily emissions, these emissions were estimated
using the algorithm described in section 4.5.3.1.4 and equations 4.5-10 through 4.5-12.
4.5.5 1995 Emissions
The 1995 emission estimates were derived in a similar manner as the 1991 through 1994 emissions.
The estimates were either extracted from AIRS/FS for 1995, estimated using AIRS/FS data for the years
1990 through 1994, projected using the 1990 NET inventory or for VOC area sources projected using
E-GAS factors and the 1990 Interim Inventory. The method used depended on states' responses to a
survey conducted by EPA early in 1997. A description of the AIRS/FS methodology is described in
section 4.5.4. The following two subsections describe the projected emissions.
4.5.5.1 Grown Estimate
The 1995 point and CO and NOX area source emissions were grown using the 1990 NET inventory
as the basis. The algorithm for determining the estimates is detailed in section 4.5.1.2.3 and equations
4.5-5 through 4.5-8. The 1990 through 1996 SEDS and BEA data are presented in Tables 4.5-7 and
4.5-8.
4.5.5.2 Rule Effectiveness
Rule effectiveness was revised in 1995 for all grown sources using the information in the 1990 data
base file. If the rule effectiveness value was between 0 and 100 percent in 1990 and the control efficiency
was greater than 0 percent, the uncontrolled emissions were calculated for 1990. The 1995 emissions
were calculated by multiplying the growth factor by the 1990 uncontrolled emissions and the control
efficiency and a rule effectiveness of 100 percent. The adjustment for rule effectiveness was only applied
to grown sources.
National Air Pollutant Emission Trends 1985-1996 Methodology
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4.5.6 1996 Emissions
The 1996 emission estimates were derived in a similar manner as the 1995 emissions. For the point
sources, the 1995 AIRS/FS emissions and 1995 emissions grown from 1990 emissions were merged.
(This section also applies to the VOC area source emissions.) The following three subsections describes
the projected 1996 emissions.
4.5.6.1 Grown Estimates
The 1996 point and area source emissions were grown using the 1995 NET inventory as the basis.
The algorithm for determining the estimates is detailed in section 4.5.1.4 and is described by the equation
below. The 1990 through 1996 SEDS and BEA data are presented in Tables 4.5-7 and 4.5-8. The 1996
BEA and SEDS data were determined using linear interpretation of the 1988 through 1995 data. Rule
effectiveness was updated to 100 percent as described in section 4.5.5.3 for the AIRS/FS sources that
reported rule effectiveness of less than 100 percent in 1995.
Equation 4.5-14 describes the calculation used to estimate the 1996 emissions.
CEFF\ ( RP\\
— *— (Eq. 4.5-14)
where: CER1996 = controlled emissions incorporating rule effectiveness
UC1995 = uncontrolled emissions
GS = growth surrogate (either BEA or SEDS data)
REFF = rule effectiveness (percent)
CEFF = control efficiency (percent)
RP = rule penetration (percent)
The rule effectiveness for 1996 was always assumed to be 100 percent. The control efficiencies and rule
penetrations are detailed in the following subsections.
4.5.6.2 1996 VOC Controls
This section discusses VOC stationary source controls (except those for electric utilities). These
controls were developed to represent the measures mandated by the CAAA and in place in 1996. Title I
(specifically the ozone nonattainment provisions) affects VOC stationary sources. Title III hazardous air
pollutant regulations will also affect VOC source categories. The discussion for each source category-
specific control measure includes the regulatory authority, CAAA provisions relating to the control
measure, and relevant EPA guidance.
Table 4.5-1 1 list the point source controls by pod. (A pod is a group of SCCs with similar emissions
and process characteristics for which common control measures, i.e., cost and emission reductions, can
be applied. It is used for control measure application/costing purposes.) Table 4.5-12 lists the POD to
SCC match. Table 4.5-13 lists the area source control efficiencies, and rule effectiveness and rule
penetration if not 100 percent. A description of the controls is detailed below.
National Air Pollutant Emission Trends 1985-1996 Methodology
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EPA has issued three groups of CTG documents to be implemented in ozone nonattainment areas.
These controls should already be included in areas designated as nonattainment prior to 1990. These
controls, however, must also be implemented in newly designated nonattainment areas and over the entire
OTR. Not all CTGs are included in Table 4.5-13 because of the difficulty, in some cases, of matching the
document to the appropriate sources within the inventory. It is assumed that all existing CTGs are
implemented by 1996.
The source categories affected by Title III maximum achievable control technology (MACT)
standards were identified by using EPA's timetable for regulation development under Title III.23
Applicability of the anticipated regulations in various projection years was also derived from this draft
timetable.
Control technology efficiencies were estimated for the expected MACT standards based on available
information. The information used depended on the status of specific standards in their development
timetable. For standards that have already been proposed or promulgated, efficiencies were estimated
using information presented in preambles to the appropriate regulations.
Rule effectiveness was estimated at 100 percent for all Title III standards, in accordance with current
EPA guidelines for rule effectiveness. Rule penetration is not applicable for any of the MACT categories,
since it is included in the average "control technology efficiency" parameter.
4.5.7 References
1. National Air Pollutant Emission Trends, Procedures Document 1900-1993, EPA-454/R-95-002,
Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research
Triangle park, NC. December 1994.
2. Table SA-5 — Total Personal Income by Major Sources 1969-1990. Data files. U.S. Department
of Commerce, Bureau of the Census, Washington, DC. 1991.
3. Connolly et al., U.S. Paint Industry Data Base, prepared by SRI International for the National Paint
and Coatings Association, Inc., Washington, DC, 1990.
4. The Freedonia Group, Solvents, Industry Study #264, Cleveland, Ohio, 1989.
5. Frost & Sullivan, Inc., Industrial Solvents (Report A2180), New York, New York, 1989.
6. TSDF Inventory File, computer file transferred to E.H. Pechan & Associates, Inc., from U.S.
Environmental Protection Agency, Emission Standards Division, via Alliance Technologies, April
1989.
7. 1987 Census of Agriculture, Volume 1: Geographic Area Series, county data file, U.S. Bureau of
the Census, Department of Commerce, Washington, DC, 1987.
8. County Business Patterns, Bureau of the Census, U.S. Department of Commerce, Washington, DC,
1988.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-156 Solvent Utilization
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9. City/County Data Base, data files, Bureau of the Census, U.S. Department of Commerce,
Washington, DC, 1988.
10. Regional Ozone Modeling for Northeast Transport (ROMNET), EPA- 450/4-9 l-002a, U.S.
Environmental Protection Agency, Office of Air Quality Planning and Standards,Research Triangle
Park,NC, 1991.
11. Area Source Documentation for the 1985 National Acid Precipitation Assessment Program
Inventory, EPA-600/8-88-106, U.S. Environmental Protection Agency, Air and Energy Engineering
Research Laboratory, Research Triangle Park, NC, December 1988.
12. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC. 1988, 1987, 1988, 1989, 1990, 1991.
13. Dean, T. A. and P. Carlson, PM-10 Controlled Emissions Calculator. E.H. Pechan & Associates,
Inc. Contract No. 68-DO-0120 Work Assignment No. 11-81. Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. April 27, 1993.
(TTN CHIEF BBS)
14. Barnard, W.R., and P. Carlson, PM-10 Emission Calculation, Tables 1 and 4, E.H. Pechan &
Associates, Inc. Contract No. 68-DO-1020, U.S. Environmental Protection Agency, Emission
Factor and Methodologies Section. June 1992.
15. E.H. Pechan & Associates, Inc., National Assessment ofVOC, CO, andNOx Controls, Emissions,
and Costs, prepared for U.S. Environmental Protection Agency, Office of Policy Planning and
Evaluation, Washington, DC, September 1988.
16. Regional Interim Emission Inventories (1987-1991), Volume I: Development Methodologies, EPA-
454/R-23-021a, U.S. Environmental Protection Agency, Office of Air Quality Planning and
Standards, Research Triangle Park, NC. May 1993.
17. Seitz, John, U.S. Environmental Protection Agency, Research Triangle Park, NC, Memorandum to
State Air Directors. May 5, 1995.
18. An Emission Inventory for Assessing Regional Haze on the Colorado Plateau, Grand Canyon
Visibility Transport Commission, Denver, CO. January 1995.
19. Volatile Organic Compound (VOQ/P articulate Matter (PM) Speciation Data System (SPECIATE)
User's Manual, Version 1.5, Final Report, Radian Corporation, EPA Contract No. 68-DO-0125,
Work Assignment No. 60, Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. February 1993.
20. State Energy Data Report — Consumption Estimates 1960-1989, DOE/EIA-0214(89), U.S.
Department of Energy, Energy Information Administration, Washington, DC, May 1991.
National Air Pollutant Emission Trends 1985-1996 Methodology
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21. Economic Growth Analysis System: User's Guide, Version 2.0. EPA-600/R-94-139b. Joint
Emissions Inventory Oversight Group, U.S. Environmental Protection Agency, Research Triangle
Park, NC. August 1994.
22. Internet E-mail from J. Nuovo to J. Better of the Department of Health and Environmental Control
(DHEC), Columbia, South Carolina, entitled Total Suspended Paniculate (TSP)/PM-10 Ratio.
Copy to P. Carlson, E.H. Pechan & Associates, Inc., Durham, NC. April 10, 1997.
23. 58 FR 63941, 1993 Federal Register, Vol. 58, p. 63941, December 3, 1993.
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Table 4.5-1. National Material Balance for Solvent Emissions
Category
Solvent Usage
Description (1,000tpy)
Percent
Destroyed by
Air Pollution
Controls1
Percent Sent
to TSDFs2
Estimated
Emissions
(1,000tpy) Source
Surface Coating
2401001
2401005
2401008
2401015
2401020
2401025
2401030
2401040
2401045
2401055
2401060
2401065
2401070
2401075
2401080
2401085
2401090
2401100
2401200
Architectural
Auto refinishing
Traffic markings
Flat wood coating
Wood furniture
Metal furniture
Paper coating
Can coating
Coil coating
Electrical insulation
Appliances
Machinery
Motor vehicles (new)
Aircraft coating
Marine paints
Rail equip, coating
Misc. manufacturing
Industrial maintenance
Aerosols, spec, purpose
503
133
106
5
221
70
33
156
58
48
34
130
134
11
29
6
210
99
173
0
0
0
16
16
16
16
16
16
16
16
16
16
16
16
16
16
0
0
0
0
0
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
503
133
106
3
139
44
21
99
37
30
21
82
85
7
18
4
132
78
137
SRI International/
National Paint and
Coatings Institute
Vapor Degreasing (Conveyorized and Open-Top)
2415105
2415110
2415120
2415125
2415130
2415135
2415140
2415145
Furniture
Metallurgical proc.
Fabricated metals
Industrial machinery
Electrical equipment
Transportation equip.
Instrument mfg.
Misc. manufacturing
9
29
97
100
98
36
48
17
0
0
0
0
0
0
0
0
21
21
21
21
21
21
21
21
7
23
76
79
77
28
38
13
Total category
number from Frost
& Sullivan. Industry
breakdowns from
EPA BOAT Report
for spent solvents.
Cold Cleaner Degreasing
2415305
2415310
2415320
2415325
2415330
2415335
2415340
2415345
2415355
2415360
2415365
Furniture
Metallurgical proc.
Fabricated metals
Industrial machinery
Electrical equipment
Transportation equip.
Instruments
Misc. manufacturing
Automobile dealers
Automobile repair
Other
12
8
38
52
16
12
8
19
191
70
5
0
0
0
0
0
0
0
0
0
0
0
21
21
21
21
21
21
21
21
21
21
21
9
7
30
41
12
9
6
15
151
55
4
Total category
number from Frost
& Sullivan. Industry
breakdowns from
EPA BOAT Report
for spent solvents.
Other Categories
2420010
2420010
2420020
2425000
2430000
2440020
2461021
2461800
2465100
2465200
2465400
2465600
Drycleaning (perc.)
Drycleaning (petroleum)
Coin-op drycleaning
Graphic arts
Rubber/plastics
Adhesives - industrial
Cutback asphalt
Pesticides - farm
Personal products
Household products
Automotive products
Adhesives - Comml.
135
134
2
276
48
460
200
260
228
186
650
350
0
0
0
16
16
0
0
0
0
0
0
0
21
21
21
21
21
21
0
0
0
0
0
0
107
105
1
174
30
363
200
260
228
186
650
350
Frost & Sullivan
Frost & Sullivan
Frost & Sullivan
Frost & Sullivan
Frost & Sullivan
Freedonia Group
Asphalt Institute
Freedonia Group
Frost & Sullivan
Frost & Sullivan
Freedonia Group
Frost & Sullivan
1 Based on the 1985 NEDS methodology. Does not include solvents that are captured and recycled.
Calculated based on the TSDF sector of the 1985 NAPAP Inventory.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-159
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-2. Data Bases Used for County Allocation
AMS
Category
Surface Coating
2401001
2401005
2401008
2401015
2401020
2401025
2401030
2401040
2401045
2401055
2401060
2401065
2401070
2401075
2401080
2401085
2401090
2401100
2401200
Description
Architectural
Auto refinishing
Traffic markings
Flat wood coating
Wood furniture
Metal furniture
Paper coating
Can coating
Coil coating
Electrical insulation
Appliances
Machinery
Motor vehicles (new)
Aircraft coating
Marine paints
Rail equip, coating
Misc. manufacturing
Industrial maintenance
Aerosols, spec, purpose
Allocation Data
(from the Census)
Population
Employment in SIC 7532
Population
Employment in SIC 2430
Employment in SIC 25
Employment in SIC 25
Employment in SIC 26
Employment in SIC 341
Employment in SIC 344
Employment in SIC 36
Employment in SIC 363
Employment in SIC 35
Employment in SIC 371
Employment in SIC 372
Employment in SIC 373
Employment in SIC 374
Employment in SIC 20-39
Employment in SIC 20-39
Population
Vapor Degreasing (Conveyorized and Open-Top)
2415105
2415110
2415120
2415125
2415130
2415135
2415140
2415145
Cold Cleaner Degreasing
2415305
2415310
2415320
2415325
2415330
2415335
2415340
2415345
2415355
2415360
2415365
Other Categories
2420010
2420010
2420020
2425000
2430000
2440020
2461021
2461800
2465100
2465200
2465400
2465600
Furniture
Metallurgical proc.
Fabricated metals
Industrial machinery
Electrical equipment
Transportation equip.
Instrument mfg.
Misc. manufacturing
Furniture
Metallurgical proc.
Fabricated metals
Industrial machinery
Electrical equipment
Transportation equip.
Instruments
Misc. manufacturing
Automobile dealers
Automobile repair
Other
Drycleaning (perc.)
Drycleaning (petroleum)
Coin-op drycleaning
Graphic arts
Rubber/plastics
Adhesives - industrial
Cutback asphalt
Pesticides - farm
Personal products
Household products
Automotive products
Adhesives - Comml.
Employment in SIC 25
Employment in SIC 33
Employment in SIC 34
Employment in SIC 35
Employment in SIC 36
Employment in SIC 37
Employment in SIC 38
Employment in SIC 39
Employment in SIC 25
Employment in SIC 33
Employment in SIC 34
Employment in SIC 35
Employment in SIC 36
Employment in SIC 37
Employment in SIC 38
Employment in SIC 39
Employment in SIC 55
Employment in SIC 75
Employment in SIC 22
Employment in SIC 721 6
Employment in SIC 721 6
Employment in SIC 721 5
Employment in SIC 27
Employment in SIC 30
Employment in SIC 20-39
Population
Farm acres treated with sprays
Population
Population
Population
Population
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-160
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-3. Bureau of Economic Analysis's SA-5 National Changes in
Earnings by Industry
Percent Growth from:
Industry
Farm
Agricultural services, forestry,
fisheries, and other
Coal mining
Metal mining
Nonmetallic minerals, except fuels
Construction
Food and kindred products
Textile mill products
Apparel and other textile products
Paper and allied products
Printing and publishing
Chemicals and allied products
Petroleum and coal products
Tobacco manufactures
Rubber and miscellaneous plastic
products
Leather and leather products
Lumber and wood products
Furniture and fixtures
Primary metal industries
Fabricated metal products
Machinery, except electrical
Electric and electronic equipment
Transportation equipment,
excluding motor vehicles
Motor vehicles and equipment
Stone, clay, and glass products
Instruments and related products
Miscellaneous manufacturing
industries
Railroad transportation
Trucking and warehousing
Water transportation
Local and interurban passenger
transit
Transportation by air
Pipelines, except natural gas
Transportation services
Communication
Electric, gas, and sanitary services
SIC
01,02
07, 08, 09
11
10
14
15
20
22
23
26
27
28
29
21
30
31
24
25
33
34
35
36
37
371
32
38
39
40
42
44
41
45
46
47
48
49
1985 to 1987
14.67
23.58
-17.46
-3.03
2.33
7.27
1.67
8.50
-1.72
2.62
7.44
1.75
-10.82
-1.97
5.27
-9.39
10.03
6.82
-9.09
-4.52
-5.72
-3.17
8.44
-6.45
-0.23
-0.04
1.84
-14.13
5.63
-8.92
13.45
12.01
-5.21
15.92
1.94
0.07
1987 to 1988
-2.73
5.43
-6.37
18.01
3.74
4.81
1.34
-0.64
1.25
0.94
5.67
6.94
-3.22
2.43
5.51
-1.64
5.15
2.35
5.32
2.55
6.02
-18.01
-1.57
2.20
-1.61
60.65
6.92
-2.53
3.26
0.07
0.51
4.63
3.67
8.52
0.68
3.05
1988 to 1989
14.58
1.01
-4.16
8.94
-2.79
-1.36
-1.20
-1.39
-1.62
-0.14
-0.81
0.32
-3.02
-2.43
0.68
-3.58
-3.54
-1.46
-0.34
-0.86
-0.32
-1.91
0.55
-2.96
-1.96
-0.82
-2.21
-3.83
-0.20
-1.02
2.14
4.94
-4.93
4.60
-2.81
0.63
1989 to 1990
-3.11
2.48
4.53
4.56
-0.45
-3.80
-0.24
-4.97
-4.22
-0.39
0.43
1.61
1.06
-5.01
-0.14
-2.55
-3.71
-2.98
-3.03
-1.91
-1.92
-3.22
-1.07
-5.43
-3.19
-2.91
-2.54
-6.03
0.99
2.83
1.44
4.36
3.53
4.97
2.07
0.39
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-161
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-4. Point Source Data Submitted
State
Alabama
Arkansas
Connecticut
Delaware
District of Columbia
Florida
Georgia - Atlanta
Urban Airshed (47
counties) domain
Georgia - Rest of
State
Illinois
Indiana
Kansas
Kentucky - Jefferson
County
Kentucky - Rest of
State
Louisiana
Maine
Maryland
Massachusetts
Michigan
Minnesota
Missouri
Nebraska
New Hampshire
New Jersey
New York
North Carolina
North Dakota
Ohio
Oklahoma
Pennsylvania -
Allegheny County
Pennsylvania -
Philadelphia County
Pennsylvania - Rest
of State
Rhode Island
South Carolina
Data Source/Format
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - EPS Workfile
State - EPS Workfile
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State format
AIRS-AFS - Ad hoc retrievals
State - EPS Workfiles
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
Jefferson County - EPS Workfile
State - EPS Workfile
State - State Format
State - EPS Workfile
State - EPS Workfile
State - EPS Workfile
State - State Format
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - EPS Workfile
State - EPS Workfile
State - EPS Workfile
State - EPS Workfiles
AIRS-AFS - Ad hoc retrievals
State - State Format
State - State Format
Allegheny County - County Format
Philadelphia County - County Format
State - EPS Workfile
State - EPS Workfile
AIRS-AFS - Ad hoc retrievals
Temporal
Resolution
Annual
Annual
Daily
Daily
Annual
Annual
Daily
Annual
Daily
Annual
Annual
Daily
Daily
Annual
Daily
Daily
Daily
Annual
Annual
Annual
Annual
Daily
Daily
Daily
Daily
Annual
Annual
Annual
Daily
Daily
Daily
Daily
Annual
Year of Data
1994
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1993
1990
1990
1990
1990
1990
1990
1990
1994
1990
1990
1990
1990
1991
Adjustments to Data
Backcast to 1990 using BEA. Average Summer
Day estimated using methodology described above.
Average Summer Day estimated using default
temporal factors.
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
None
Average Summer Day estimated using default
temporal factors.
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
None
None
Average Summer Day estimated using methodology
described above.
None
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
Backcast to 1990 using BEA. Average Summer
Day estimated using methodology described above.
Average Summer Day estimated using methodology
described above.
None
None
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
Backcast to 1990 using BEA. Average Summer
Day estimated using methodology described above.
None
None
None
None
Average Summer Day estimated using default
temporal factors.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-162
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-4 (continued)
Temporal
South Dakota AIRS-AFS -Ad hoc retrievals
Tennessee AIRS-AFS - Ad hoc retrievals
Texas State - State Format
Vermont State - EPS Workfile
Virginia AIRS-AFS -Ad hoc retrievals
West Virginia AIRS-AFS -Ad hoc retrievals
Wisconsin State - State Format
Annual 1990 Average Summer Day estimated using methodology
described above.
Annual 1990 Average Summer Day estimated using default
temporal factors.
Daily 1992 Backcast to 1990 using BEA.
Daily 1990 None
Annual 1990 Average Summer Day estimated using methodology
described above.
Annual 1990 Average Summer Day estimated using methodology
described above.
Daily _ 1990 None _
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-163
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-5. Area Source Data Submitted
State
Connecticut
Delaware
District of Columbia
Florida
Georgia
Data Source/Format
State - EPS Workfile
State - EPS Workfile
State - Hard copy
AIRS-AMS - Ad hoc retrievals
State - State format
Temporal
Resolution
Daily
Daily
Daily
Daily
Daily
Geoaraohic Coveraae
Entire State
Entire State
Entire State
Jacksonville, Miami/
Ft. Lauderdale, Tampa
Atlanta Urban Airshed
Adjustments to Data
None
None
None
Added Nonroad emission estimates
from Int. Inventory to Jacksonville
(Duval County)
None
Illinois State - State format Daily
Indiana State - State format Daily
Kentucky State - State Format Daily
Louisiana State - State Format Daily
Maine State - EPS Workfile Daily
Maryland State - EPS Workfile Daily
Michigan State - State Format Daily
Missouri AIRS-AMS-Ad hoc retrievals Daily
New Hampshire State - EPS Workfile Daily
New Jersey State - EPS Workfile Daily
New York State - EPS Workfile Daily
North Carolina State - EPS Workfiles Annual
Ohio State - Hard copy Daily
Pennsylvania State - EPS Workfile Daily
Rhode Island State - EPS Workfile Daily
Tennessee State - State format Daily
Texas State - State Format Annual
Vermont State - EPS Workfile Daily
Virginia State - EPS Workfile Daily
West Virginia AIRS-AMS - Ad hoc retrievals Daily
Wisconsin State - State Format Daily
(47 Counties)
Entire State
Entire State
Kentucky Ozone Nonattainment
Areas
Baton Rouge Nonattainment
Area (20 Parishes)
Entire State
Entire State
49 Southern Michigan Counties
St. Louis area (25 counties)
Entire State
Entire State
Entire State
Entire State
Canton, Cleveland Columbus,
Dayton, Toledo, and Youngstown
Entire State
Entire State
42 Counties in Middle
Tennessee
Entire State
Entire State
Entire State
Charleston, Huntington/Ashland,
and Parkersburg (5 counties
total)
Entire State
None
Nonroad emissions submitted were
county totals. Nonroad emissions
distributed to specific SCCs based
on Int. Inventory
None
None
None
None
None
Only area source combustion data
was provided. All other area source
data came from Int. Inventory
None
None
None
Average Summer Day estimated
using default temporal factors.
Assigned SCCs and converted from
kgs to tons. NOX and CO from Int.
Inventory added to Canton, Dayton,
and Toledo counties.
Nonroad emissions submitted were
county totals. Nonroad emissions
distributed to specific SCCs based
on Int. Inventory
None
No nonroad data submitted.
Nonroad emissions added from Int.
Inventory
Average Summer Day estimated
using default temporal factors.
None
None
None
None
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-164
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-6. Ad Hoc Report
Critera
Regn
DLL4
DLL4
DLL4
DLL4
DLL4
DLL4
DES4
DUE4
VI NV
GTO
CEVOC
CECO
CESO2
CE NO2
CE PM-10
CE PT
GEO
VIETY
VIE 90
Plant Output
VINV
SITE
CNTY
CYCD
7IPC
DNED
DNME
LAT1
_ON1
SIC1
OPST
SIRS
YEAR OF INVENTORY
STATE F I PS CODE
COUNTY FIPS CODE
CITY CODE
ZIP CODE
MEDS POINT ID
DLANT NAME
LATITUDE PLANT
_ONGITUDE PLANT
STANDARD INDUSTRIAL
CODE
OPERATING STATUS
STATE REGISTRATION
MUMBER
Point Output
STTE
CNTY
PNED
DNUM
CAPC
CAPU
DAT1
DAT2
DAT3
DAT4
MOHD
MODW
MOHY
STATE FIPS CODE
COUNTY FIPS CODE
NEDS POINT ID
POINT NUMBER
DESIGN CAPACITY
DESIGN CAPACITY
UNITS
WINTER
THROUGHPUT
SPRING
THROUGHPUT
SUMMER
THROUGHPUT
-ALL THROUGHPUT
MUMBER HOURS/DAY
MUMBER DAYS/WEEK
MUMBER
HOURS/YEAR
Stack Output
STTE
CNTY
PNED
STNB
LAT2
_ON2
STHT
STDM
STET
STEV
STFR
DLHT
STATE FIPS CODE
COUNTY FIPS CODE
NEDS POINT ID
STACK NUMBER
LATITUDE STACK
LONGITUDE STACK
STACK HEIGHT
STACK DIAMETER
STACK EXIT
TEMPERATURE
STACK EXIT VELOCITY
STACK FLOW RATE
DLUME HEIGHT
Segment Output
General
STTE
CNTY
DNED
STNB
DNUM
SEGN
SCC8
HEAT
ZPRT
SULF
^SHC
DODP
STATE FIPS CODE
COUNTY FIPS CODE
MEDS POINT ID
STACK NUMBER
DOINT NUMBER
SEGMENT NUMBER
sec
HEAT CONTENT
^NNUALFUEL
THROUGHPUT
SULFUR CONTENT
ASH CONTENT
DEAK OZONE
SEASON DAILY
DROCESS RATE
Segment Output
Pollutant
STTE
CNTY
DNED
STNB
DNUM
SEGN
SCC8
DLL4
D034
DU04
DES4
DUE4
CLEE
CLT1
CTL2
REP4
DME4
Emfa
STATE FIPS CODE
COUNTY FIPS CODE
MEDS POINT ID
STACK NUMBER
DOINT NUMBER
SEGMENT NUMBER
sec
DOLLUTANT CODE
OSD EMISSIONS
OSD EMISSION
UNITS
DEFAULT
ESTIMATED
EMISSIONS
DEFAULT
ESTIMATED
EMISSIONS UNITS
CONTROL
EFFICIENCY
DRIMARY CONTROL
DEVICE CODE
SECONDARY
CONTROL DEVICE
CODE
RULE
EFFECTIVENESS
VIETHODCODE
Emission factor
-------
Table 4.5-7. SEDS National Fuel Consumption, 1990-1996 (trillion Btu)
Fuel Type End-User Code 1990 1991 1992 1993 1994 1995 1996
Population
TPOPP 248,709 252,131 255,025 257,785 259,693 261,602 263,510
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-166 Solvent Utilization
-------
Table 4.5-8. BEA SA-5 National Earnings by Industry, 1990-1996 (million $)
Industry
LNUM
SIC
1990 1991 1992 1993 1994 1995 1996
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Total population as of July 1 (thousands)
Farm
Farm
Farm
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Agricultural services, forestry, fisheries, and other
Metal mining
Coal mining
Oil and gas extraction
Nonmetallic minerals, except fuels
Construction
Construction
Construction
Construction
Manufacturing
Durable goods
Lumber and wood products
Furniture and fixtures
Stone, clay, and glass products
Primary metal industries
Fabricated metal products
Machinery, except electrical
Electric and electronic equipment
Motor vehicles and equipment
Transportation equipment, excluding motor vehicles
Instruments and related products
Miscellaneous manufacturing industries
Nondurable goods
Food and kindred products
Tobacco manufactures
Textile mill products
Apparel and other textile products
Paper and allied products
Printing and publishing
Chemicals and allied products
Petroleum and coal products
Rubber and miscellaneous plastic products
Leather and leather products
Leather and leather products
020
030
040
041
045
046
047
050
060
070
071
072
081
082
090
100
110
120
121
122
123
200
210
220
230
240
300
310
320
330
400
410
413
417
420
423
426
429
432
435
438
441
444
450
453
456
459
462
465
468
471
474
477
480
500
999
999
999
999
999
999
999
999
999
999
999
999
1,2
1,2
1,2
7-9
7-9
7-9
7-9
7-9
7-9
7-9
10
11,12
13
14
15-17
15-17
15-17
15-17
998
996
24
25
32
33
34
35
36
371
37
38
39
997
20
21
22
23
26
27
28
29
30
31
31
0
1
3,634
238
3,395
971
735
2,932
321
381
34
347
48
3,586
3,001
24
20
4
1
2
1
36
2
8
20
4
218
54
29
135
710
437
22
13
20
33
51
86
63
41
54
43
11
273
51
3
16
20
28
54
61
9
27
3
243
0
1
3,593
242
3,350
947
791
2,891
331
370
28
342
41
3,552
2,957
24
20
3
1
2
1
37
3
8
22
4
197
47
28
123
690
418
21
12
18
30
48
83
62
38
52
42
11
272
51
3
16
20
27
54
63
9
26
3
245
0
1
3,732
248
3,483
907
858
2,975
351
405
34
372
46
3,686
3,079
24
21
3
1
2
1
36
3
8
21
4
195
46
28
121
705
423
22
13
19
31
49
83
62
42
50
42
11
281
52
3
17
20
28
55
66
10
28
2
251
0
1
3,785
253
3,531
914
888
3,003
371
410
32
378
45
3,740
3,126
24
22
3
0
2
1
34
2
6
21
4
199
47
27
125
705
424
22
13
19
30
49
84
63
46
45
40
12
282
52
2
17
19
28
56
65
9
29
3
260
0
1
3,891
265
3,626
934
912
3,082
383
426
29
396
42
3,849
3,228
26
23
3
1
2
1
35
2
6
21
4
216
51
29
136
725
440
24
14
20
32
51
86
65
53
43
40
12
285
53
2
17
19
29
57
65
10
30
3
269
0
1
4,011
273
3,737
980
951
3,182
394
436
18
418
31
3,980
3,353
27
24
3
1
2
1
35
2
6
21
4
219
51
29
138
740
452
25
14
20
33
53
90
68
56
42
40
12
288
53
3
17
19
29
58
67
9
31
2
277
0
1
4,086
280
3,805
981
994
3,231
408
447
16
432
29
4,058
3,423
27
25
3
1
1
1
35
3
6
21
4
219
50
29
139
747
456
25
14
20
32
53
91
69
60
39
39
12
291
54
3
17
19
29
59
68
9
31
2
283
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-167
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-8 (continued)
Industry
LNUM
SIC
1990 1991 1992 1993 1994 1995 1996
Railroad transportation
Trucking and warehousing
Water transportation
Water transportation
Local and interurban passenger transit
Transportation by air
Pipelines, except natural gas
Transportation services
Communication
Electric, gas, and sanitary services
Wholesale trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Banking and credit agencies
Banking and credit agencies
Banking and credit agencies
Insurance
Insurance
Real estate
Holding companies and investment services
Services
Hotels and other lodging places
Personal services
Private households
Business and miscellaneous repair services
Auto repair, services, and garages
Auto repair, services, and garages
Amusement and recreation services
Amusement and recreation services
Health services
Legal services
Educational services
Social services and membership organizations
Social services and membership organizations
Social services and membership organizations
Social services and membership organizations
Miscellaneous professional services
Government and government enterprises
Federal, civilian
Federal, military
State and local
State and local
State and local
510
520
530
540
541
542
543
544
560
570
610
620
621
622
623
624
625
626
627
628
700
710
730
731
732
733
734
736
800
805
810
815
820
825
830
835
840
845
850
855
860
865
870
875
880
900
910
920
930
931
932
40
42
44
44
41
45
46
47
48
49
50,51
52-59
52-59
52-59
52-59
52-59
52-59
52-59
52-59
52-59
52-59
60,61
60,61
60,61
63,64
63,64
65,66
62,67
995
70
72
88
76
75
75
78,79
78,79
80
81
82
83,86
83,86
83,86
83,86
84, 87, 89
995
43,91,97
992
92-96
92-96
92-96
12
59
7
48
8
30
1
12
63
49
236
342
18
40
56
55
18
22
76
57
246
82
163
38
56
34
28
8
946
31
33
10
170
29
15
29
16
290
80
39
29
1
35
125
14
585
118
50
417
125
292
12
58
7
49
8
30
1
13
63
52
231
335
18
38
56
54
18
20
78
54
247
81
166
40
59
33
25
10
951
31
32
9
162
28
13
30
16
304
80
41
31
1
36
121
14
594
120
50
425
128
297
13
60
7
50
9
31
1
14
64
53
238
342
18
39
57
54
18
19
80
57
280
86
194
50
61
33
36
14
1,008
32
33
10
175
28
13
34
16
325
85
42
34
1
36
127
15
607
123
51
433
128
305
12
62
6
51
9
31
1
14
67
56
235
347
19
39
56
56
18
19
82
57
290
89
201
53
62
34
43
10
1,032
33
36
10
180
30
14
33
17
330
84
44
35
1
38
130
15
613
124
48
441
130
311
12
66
6
50
9
31
1
15
71
56
242
359
20
40
57
60
18
21
85
59
291
89
202
51
63
36
44
9
1,066
33
36
10
191
31
14
35
18
341
84
45
38
2
40
132
17
621
125
45
451
134
317
12
69
6
52
10
31
1
16
75
56
255
372
21
41
58
62
18
22
88
62
302
90
212
55
63
37
47
10
1,128
35
36
11
213
33
15
37
20
355
85
46
40
2
41
141
18
626
123
44
459
136
323
12
71
6
53
10
31
1
17
78
57
258
378
21
41
58
64
18
22
90
63
313
91
221
58
65
38
51
10
1,164
36
37
11
221
34
15
39
20
368
86
48
42
2
42
145
19
635
124
43
468
138
330
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-168
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-9. Area Source Listing by SCC and Growth Basis
sec
FILE
CODE
SCC
FILE
CODE
SCC
FILE
CODE
2401100000
2401200000
2420000999
2420010000
2401010000
2415045999
2415060000
2461800999
2495000000
2401085000
2401090000
2420000055
2420000370
2401080000
2415365000
2420000000
2401000000
2401001000
2401002000
2401005000
2401008000
2401015000
2401020000
2401025000
2401030000
2401035000
2401040000
2401045000
2401045999
2401050000
2401055000
2401060000
2401065000
2401070000
2401075000
BEA
BEA
SEDS
SEDS
BEA
BEA
BEA
SEDS
SEDS
BEA
BEA
SEDS
SEDS
BEA
BEA
SEDS
SEDS
SEDS
NG
BEA
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
400
400
TPOPP
TPOPP
459
400
400
TPOPP
TPOPP
438
444
TPOPP
TPOPP
438
820
TPOPP
TPOPP
TPOPP
825
TPOPP
413
417
417
465
477
426
426
426
426
429
432
432
435
438
2270002012
2401990000
2415000000
2415000385
2415000999
2415035000
2415045000
2415065000
2415100000
2415105000
2415110000
2415120000
2415125000
2415130000
2415135000
2415140000
2415145000
2415200000
2415230000
2415245000
2415260000
2415300000
2415305000
2415310000
2415315000
2415320000
2415325000
2415330000
2415335000
2415340000
2415345000
2415350000
2415355000
2415360000
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
300
400
400
400
400
438
444
413
400
417
423
426
429
432
438
441
444
438
432
444
825
438
417
423
423
426
429
432
438
441
444
510
620
825
2270005020
2420010055
2420010370
2420010999
2420020000
2420020055
2425000000
2425000999
2425010000
2425030000
2425040000
2430000000
2440000000
2440000999
2440020000
2460000000
2460000385
2461000000
2461020000
2461021000
2461022000
2461023000
2461050000
2461160000
2461600000
2461800000
2461850000
2465000000
2465100000
2465200000
2465400000
2465600000
2465800000
2465900000
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
81
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
820
820
820
820
820
477
444
444
444
TPOPP
TPOPP
300
300
300
300
300
300
300
300
300
300
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
NOTE(S): * BEA Code is equal to LNUM on previous table.
-------
Table 4.5-10. Emission Estimates Available from AIRS/FS by State, Year, and Pollutant
State
1990
C N S P T V
1991
C N S P T V
1992
C N S P T V
1993
C N S P T V
1994
C N S P T V
1995
Alabama
Alaska
Arizona
California
Colorado
Connecticut
Hawaii
Illinois
Louisiana
Michigan
Minnesota
Montana
Nebraska
Nevada
New Hampshire
New Mexico
North Dakota
Oregon
Pennsylvania
South Carolina
South Dakota
Texas
Utah
Vermont
Virginia
Washington
Wisconsin
Wyoming
Notes:
C = CO
= NO,
S = SO,
P = PM-10 T = TSP
V = VOC
Pennsylvania only includes Allegheny County (State 42, County 003); New Mexico only includes Albuquerque (State 35, County 001); Washington only includes Puget
Sound (State 53, County 033, 053, or 061); Nebraska includes all except Omaha City (State 31, County 055); the CO emissions in NET were maintained for South Dakota
(State 46).
-------
Table 4.5-11. Point Source Controls by Pod and Measure
POD PODNAME
MEASNAME
SOURCE
PTFYCE
42 Surface coating - thinning solvents
61 Open top degreasing
62 In-line degreasing
63 Cold cleaning
65 Open top degreasing - halogenated
66 In-line degreasing - halogenated
85 Misc organic solvent evaporation
91 Dry cleaning - perchloroethylene
93 Dry cleaning - other
RACT
MACT
MACT
MACT
MACT
MACT
SOCMI HON
MACT
MACT
Surface coating - thinning solvents 90
Open top degreasing 63
In-line degreasing 63
Cold cleaning 63
Open top degreasing - halogenated 63
In-line degreasing - halogenated 63
Misc organic solvent evaporation 79
Dry cleaning - perchloroethylene 44
Dry cleaning - other 44
Note(s): A pod is a group of SCCs with similar emissions and process characteristics for which common control measures (i.e., cost and emission reductions) can be applied.
-------
Table 4.5-12. Point Source SCC to Pod Match-up
sec
40100101
40100102
40100103
40100104
40100105
40100198
40100201
40100202
40100203
40100204
40100205
40100206
40100207
40100221
40100222
40100223
40100224
40100225
40100235
40100236
40100251
40100252
40100253
40100254
40100255
40100256
40100257
40100258
40100259
40100275
40100295
40100296
40100297
40100298
40100299
40100301
40100302
40100303
40100304
40100305
40100306
40100307
40100308
40100309
40100310
POD SCC
91 40188898
9240199999
91 40200101
9240200110
93 40200301
9340200310
61 40200401
6540200410
65 40200501
6540200510
65 40200601
61 40200610
65 40200701
62 40200706
66 40200707
6640200710
66 40200801
66 40200802
62 40200803
6240200810
61 40200898
65 40200998
6540201001
6540201002
6540201003
61 40201004
6540201101
61 40201103
61 40201105
61 40201112
6240201113
6240201114
61 40201115
6240201116
61 40201199
6340201201
6340201210
6340201301
6340201303
6340201304
61 40201305
6340201399
6340201401
6340201404
6340201405
POD SCC
6340201505
6340201531
3340201599
3340201601
3440201602
3440201603
3340201604
4040201605
3340201606
3340201607
3340201608
3340201609
3640201619
3640201620
3640201621
3640201622
3540201623
3540201625
3540201626
3540201627
3540201628
3340201629
8840201631
8840201632
8840201699
8840201702
41 40201703
41 40201704
41 40201705
41 40201721
41 40201722
41 40201723
41 40201724
41 40201725
41 40201726
41 40201727
41 40201728
3640201731
3640201732
3640201734
3640201735
3640201799
3740201801
3740201803
3740201805
POD SCC
37 40202031
37 40202033
37 40202099
3340202101
3340202103
3340202104
3340202105
3340202106
3340202107
3340202108
3340202109
3340202131
3340202132
3340202133
3340202199
33 40202201
33 40202202
33 40202203
33 40202205
33 40202299
33 40202301
33 40202302
33 40202305
33 40202306
33 40202399
34 40202401
34 40202402
34 40202403
34 40202405
34 40202406
34 40202499
34 40202501
34 40202502
34 40202503
34 40202504
34 40202505
34 40202531
34 40202532
34 40202533
34 40202534
34 40202537
34 40202598
37 40202599
37 40202601
37 40202605
POD SCC
3740500211
3740500212
37 40500299
40 40500301
40 40500303
40 40500304
40 40500305
40 40500306
40 40500307
40 4050031 1
4040500312
4040500314
40 40500401
40 4050041 1
4040500412
3840500413
3840500414
3840500416
3840500418
38 40500501
13240500502
13240500503
13240500506
13240500507
13240500510
52 4050051 1
5240500512
5240500513
5240500514
52 40500598
52 40500599
37 40500601
37 40500701
37 40500801
37 4050081 1
3740500812
37 40588801
37 40588802
37 40588803
37 40588804
37 40588805
3749000101
3749000103
3749000105
3749000199
POD
180
180
180
181
186
186
186
186
186
181
181
181
182
182
182
182
182
182
182
183
183
186
186
186
186
183
183
183
183
183
183
184
187
188
188
188
188
188
188
188
188
85
85
85
85
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-172
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-12 (continued)
sec
POD SCC
POD sec
POD SCC
POD SCC
POD
40100335
40100336
40100398
40100399
40100499
40100550
40188801
40188802
40188805
49000499
49000501
6340201406
6340201431
6340201432
6340201433
6340201435
6340201499
6340201501
6340201502
6340201503
85 49000599
8549090013
3740201806
3740201899
3740201901
3740201903
3740201904
3740201999
37 40202001
37 40202002
37 40202005
85 49090023
85
37 40202606
37 40202607
39 40202699
3940290013
3940500101
3940500199
37 40500201
37 40500202
37 40500203
85 49099998
37 49000201
37 49000202
37 49000203
88 49000204
18949000205
18949000206
18049000299
18649000399
18649000401
85 49099999
85
85
85
85
85
85
85
85
85
85
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-173
1985-1996 Methodology
Solvent Utilization
-------
POD
Table 4.5-13. Area Source VOC Controls by SCC and Pod
sec
SOURCE
MEASURE
PCTRD96
211
211
241
241
241
241
241
241
241
241
241
241
241
250
251
272
272
POD VOC
211
241
250
251
272
2420010055 Dry Cleaning - perchloroethylene
2420000055 Dry Cleaning - perchloroethylene
2415305000 Cold cleaning
2415310000 Cold cleaning
2415320000 Cold cleaning
2415325000 Cold cleaning
2415330000 Cold cleaning
2415335000 Cold cleaning
2415340000 Cold cleaning
2415345000 Cold cleaning
2415355000 Cold cleaning
2415360000 Cold cleaning
2415365000 Cold cleaning
2401075000 Aircraft surface coating
2401080000 marine surface coating
2461021000 Cutback Asphalt
2461020000 Cutback Asphalt
PODNAME
Dry Cleaning - perchloroethylene
Cold cleaning
Aircraft surface coating
marine surface coating
Cutback Asphalt
MACT
MACT
MACT
MACT
MACT
MACT
MACT
MACT
MACT
MACT
MACT
MACT
MACT
MACT
MACT
Switch to emulsified (CTG)
Switch to emulsified (CTG)
APPLICABLE
National
National
National
National
Marqinal+
44.0
44.0
35.0
35.0
35.0
35.0
35.0
35.0
35.0
35.0
35.0
35.0
35.0
0.0
0.0
100.0
100.0
Note(s): A pod is a group of SCCs with similar emissions and process characteristics for which common control measures (i.e., cost and
emission reductions) can be applied.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-174
1985-1996 Methodology
Solvent Utilization
-------
4.6 ON-ROAD VEHICLES
The "On-road Vehicle" heading includes the following Tier I and Tier II categories:
Tier I Category Tier II Category
(11) On-road Vehicles All
On-road vehicle emissions were calculated using a consistent methodology for all years from 1970
through 1996. Emissions were calculated by month, county, road type, and vehicle type for each of these
years. Emissions of volatile organic compounds (VOC), nitrogen oxides (NOX), and carbon monoxide
(CO) were calculated using monthly state-level emission factors from MOBILESa for the years 1970 to
1994 and MOBILESb for the years 1995 and 1996 by vehicle type while particulate matter less than
10 microns in aerodynamic diameter (PM-10), ammonia (NH3) and particulate matter less than
2.5 microns in aerodynamic diameter (PM-2.5) (1990 to 1996), and sulfur dioxide (SO2) emissions were
calculated using national annual emission factors by vehicle type. This section of the procedures
document discusses the methodology used for calculating on-road vehicle emissions.
The activity factor that is used to estimate on-road vehicle emissions is vehicle miles traveled
(VMT). The first section of this chapter discusses the development of the VMT data base. The next
section of this chapter discusses the development of the inputs used for the MOBILE modeling.
Estimation of the PM-10, PM-2.5, and SO2 emission factors are discussed next followed by NH3. Finally,
the emission calculation procedure is discussed.
4.6.1 VMT
Using state totals for each year, VMT were allocated by county, roadway type, and vehicle type for
each year between 1970 and 1996. Each state and county combination in the output files has 96 assigned
source classification codes (SCCs) representing the 6 rural and 6 urban roadway types, and 8 vehicles
types. The methodology used for calculating VMT from (1) 1980 to 1995 differs from the methodology
used for calculation of mileage totals from (2) 1970 to 1979 and for (3) 1996. Each of the three
approaches is described separately below.
4.6.1.1 Background on Highway Performance Monitoring System
The following sections describe the information contained within Highway Performance Monitoring
System (HPMS)1 which is used to create the county/roadway type/vehicle type level VMT data file, and
the problems with using this information.
4.6.1.1.1 Description of HPMS —
The HPMS is a national data collection and reporting system administered by the U.S. Department
of Transportation (DOT), Federal Highway Administration (FHWA) in cooperation with state highway
programs. The HPMS contains data on the mileage, extent, and usage of the various functional road
systems, the condition and performance of pavements, physical attributes of roads, road capacity and
improvement needs, and other data important to the structural integrity and operation of the nation's road
systems. The data that make up HPMS are submitted to FHWA annually by each state highway program.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-175 On-road Vehicles
-------
The HPMS has three main data components: (1) the universe data base, (2) the sample data base
(a subset of the universe data base), and (3) the areawide data base. The universe data base contains a
complete inventory of all mileage for all functional systems, except local roads. The sample data base
contains more detailed information for a subset of the highway sections in the universe data base. Each
record in the sample data base is part of a sample panel which can be expanded to represent the universe
of highway mileage. The areawide data base contains annual state-level summaries of the major
components of HPMS. Most of the state-level data in the areawide data base are divided into rural, small
urban, and individualized urban area components. Table 4.6-1 illustrates the main data components of
HPMS and the type of data they contain.
The travel data in HPMS are of great interest in estimating VMT. HPMS travel data are based on
samples of daily traffic counts taken at various points in a state's roadway network. These daily traffic
counts are expanded to annual average daily traffic (AADT). To calculate VMT for a specific section of
road, the AADT for that section of road is multiplied by the road length.2
4.6.1.1.2 Problems with Using HPMS to Estimate VMT —
There are several complexities associated with using HPMS data to estimate VMT for this
inventory. The county is the basic geographic unit in the 1990 Emission Trends inventory, while all data
in HPMS are divided into rural, small urban, and individualized urban geographic areas. In order to use
the HPMS data, a mechanism to distribute VMT from a rural, small urban, and individual urban area level
to a county level had to be developed. In addition, the level of detail of reporting in the sample data base
(the most detailed data base which contained VMT information) varied from state to state. Some states
reported data for each individual urban area, some states reported data for all individual urban areas
together, and some states reported data separately for some individual urban areas and reported data for
the remaining individual urban areas together. This made distributing VMT from the sample data base to
counties a difficult task. In the areawide data base, however, all states reported data for individual urban
areas separately. Finally, travel data for local road systems were only contained in the areawide data
base. Therefore, the areawide data base was used to generate county-level VMT estimates. The
methodology used to generate county-level VMT estimates is described below.
4.6.1.2 Distribution of HPMS VMT, 1980 to 1995
The FHWA supplied the latest mileage and daily travel summary areawide records that were
reported for the HPMS for the period 1980 through 1995. The HPMS files contain state-level summaries
of miles of daily travel by functional system and by rural, small urban (population of 5,000 to 49,999),
and individual urban (population of 50,000 and more) areas. Rural daily VMT (DVMT) is provided on a
state level for the following six roadway types: principal arterial-interstate, other principal arterial, minor
arterial, major collector, minor collector, and local. Small urban and urban area DVMT are provided for
the following six roadway types: principal arterial - interstate, principal arterial - other freeways and
expressways, other principal arterial, minor arterial, collector, and local.
VMT from the HPMS areawide data base was distributed to counties based on each county's rural,
small urban, and urban area population. Two tables in the Bureau of the Census 1980 Number of
Inhabitants (CNOI) documents3 were used as the source for population data for the years 1980 to 1994.
The 1980 population data had to be used to allocate the VMT because the Census Urbanized Area
boundaries were changed for the 1990 census. Although not exactly the same, the large urban area
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boundaries used in HPMS are based on the 1980 Census Urbanized Area boundaries. Use of the 1990
Census Urbanized Area boundaries would prevent a one-to-one match between HPMS large, urban-area
VMT and urbanized area population, making VMT distribution difficult.
The two CNOI tables used to distribute VMT to counties are:
Table 3: Population of Counties by Urban and Rural
Residence. This table lists the urban population
living inside census-defined urban areas, the urban
population living outside census-defined urban areas,
and the rural population for each county.
Table 13: Population of Urban Areas. This table divides an
urban area's population among the counties that
contain portions of that urban area.
County-level rural VMT, small urban VMT, and urbanized area VMT were calculated separately
using the following methodology. The methodology described below was performed for each functional
road system.
4.6.1.2.1 Rural VMT —
To calculate rural VMT by county, two steps were followed. First, the percentage of the state's
rural population in each county was calculated using county rural population data from CNOI Table 3.
Next, each county's rural VMT was calculated by distributing state rural VMT from the HPMS areawide
data base, based on the percentage of the state's rural population in each county using Equation 4.6-1.
POPRC
VMTR,c = VMTR^S x _?£ (Eq. 4.5.!)
where: VMTRC = Rural VMT in county C (calculated)
VMTR'S = Rural VMT, state total (HPMS)
P°PR c = Rural population in county C (CNOI)
P°PR s = Rural population, state total (CNOI)
4.6.1.2.2 Small Urban VMT—
A similar methodology was used to calculate each county's small urban VMT. First, the percentage
of the state's small urban population in each county was calculated using county urban population living
outside census-defined urbanized areas from CNOI Table 3. Next, each county's small urban VMT was
calculated by distributing state small urban VMT from the HPMS areawide data base based on the
percentage of the state's small urban population in each county using Equation 4.6-2.
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POPS
VMTSU>C = VMTSU>S x _ (Eq. 4.6.2)
""
where: VMTSU c = Small urban VMT in county C (calculated)
VMTSU^S = Small urban VMT, state total (HPMS)
POPsu,c = Small urban population in county C (CNOI)
POPSU;S = Small urban population, state total (CNOI)
4. 6. 1. 2. 3 Urban Area VMT —
The approach for allocating HPMS daily VMT (DVMT) reported for individual urban areas was
slightly different than the approach used to allocate rural and small urban DVMT. Each urban area in the
HPMS file is assigned a unique 3-digit code. To allocate DVMT totals by road type for each individual
urban area, an urban area population file was used which links a given urban area code to the
corresponding population in each component county. Because the boundaries of urban and small urban
areas changed from year to year, there were urban areas in the HPMS input files for which the population
for component counties was not available. In these cases, the VMT for this urban area was added to the
HPMS small urban VMT total by road category and allocated by small urban population ratios.
For each urban area, the percentage of its population in each county containing a portion of the
urban area was calculated using data from CNOI Table 13. Next, each county's share of an urban area's
VMT was calculated by distributing urban area VMT from the HPMS areawide data base based on the
percentage of the urban area's population in each county using Equation 4.6-3.
POPUAC
VMTUAf = VMTUAtS x ^ (Eq. 4.6_3)
"
where: VMTUAC = Urban area's VMT in county C (calculated)
VMTUAS = Urban area's VMT, state total (HPMS)
POPUAC = Urban area's population in county C (CNOI)
POPUAS = Urban area's population, state total (CNOI)
In a few cases, a single county contained parts of more than one urban area. For those counties,
urban VMT was calculated as the sum of the county's proportion of VMT from each of the large urban
areas in the county and the county's small urban VMT.
4.6.1.2.4 Determining VMT by Roadway Type and Vehicle Type —
The next step in calculating VMT at the county/roadway type/vehicle type level was to allocate the
DVMT totals in 12 rural and urban roadway categories among the 8 MOBILE model vehicle type
categories. For each year between 1980 and 1995, a percentage distribution was calculated for each
vehicle type for both the rural and urban classifications. The first step in the development of this
percentage distribution was to obtain the most recent VMT totals by vehicle type and by year from
FHWA's Highway Statistics.4 Rural and urban VMT in this publication are provided for the following
vehicles types: passenger cars, motorcycles, buses, two-axle/four-tire single-unit trucks, other single-unit
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trucks, and combination trucks. (In the years prior to 1990, a VMT breakdown between passenger cars
and motorcycles was not provided. A total VMT for Personal Passenger Vehicles is provided. It was
assumed that the division between passenger car VMT and motorcycle VMT is the same in earlier years
as was reported for 1990.) For each of the six vehicle type categories for which VMT is reported in
Highway Statistics, a percentage of the total was calculated for both rural and urban VMT. To convert
these percentages for the six HPMS categories to the eight MOBILE vehicle type categories, a
breakdown provided by the United States (U.S.) Environmental Protection Agency (EPA) was used
which reconciles the vehicle class categories used in the HPMS to those used in EPA's MOBILE model.5
This method of conversion from HPMS categories to MOBILE categories is based on a matching scheme
that allows states to apportion VMT as it is reported in HPMS categories to the eight MOBILE model
vehicle class categories. The apportionment percentages supplied by EPA are shown in table 4.6-2.
After allocating HPMS DVMT totals by county, roadway category, and vehicle type, the values
were converted to millions of annual VMT. This conversion was done by simply multiplying the DVMT
values by 365, since the DVMT values represent VMT for an average day. Quality assurance was
performed on the output files for each of the years by comparing state totals to the HPMS data provided
by state. (It is important to note that for certain years, slight discrepancies exist between the HPMS
totals and the totals reported in Highway Statistics.) The resulting annual county-level, vehicle, and
roadway type-specific VMT data were temporally allocated to months. Seasonal 1985 National Acid
Precipitation Assessment Program (NAPAP) temporal allocation factors7 were used to apportion the
VMT to the four seasons. Monthly VMT data were obtained using a ratio between the number of days in
a month and the number of days in the corresponding season. These temporal factors are shown in table
4.6-3.
4.6.1.3 Distribution of VMT, 1970 to 1979 and 1996
The methodology for allocating VMT totals for 1970 through 1979 was based on state totals which
were published in FHWA's Highway Statistics 1985. For each year, state totals were allocated by
county, roadway type, and vehicle type using a ratio from the 1980 VMT file for each state/county/SCC
combination expressed as a percentage of the 1980 state total. Quality assurance was performed by
comparing statewide totals for each year's output to the FHWA's state totals.
The 1995 VMT data base was grown to 1996 using preliminary State/roadway type totals for 1996
provided by FHWA.6 To accomplish this, the 1995 VMT data base was first totaled to the State and
roadway type level. Next, the preliminary 1996 State and roadway type VMT totals provided by FHWA
were divided by the corresponding 1995 VMT totals from the Trends 1995 VMT data base. This
resulted in 1995 and 1996 VMT growth factors at the State and roadway type level. The final step was
to multiply these growth factors by each VMT data point in the 1995 VMT data base, matching by State
and road type. This process is illustrated by Equation 4.6-4.
FHVMT96
TRVMT96sr,RTrr=TRVMT95sr,RTrr* „,_„_„ S'RT (Eq. 4.6-4)
^S,RT
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where: TRVMT96SCRTVT = Trends 1996 VMT for State S, county C, roadway type RT, and
vehicle type VT (millions of miles per year);
TRVMT95SCRTVT = Trends 1995 VMT for State S, county C, roadway type RT, and
vehicle type VT (millions of miles per year);
FHVMT96S RT = Federal Highway Administration preliminary 1996 VMT for State S
and roadway type RT (millions of miles per year); and
TRVMT95S RT = Trends 1995 VMT total for State S and roadway type RT (millions of
miles per year).
Table 4.6-4 shows the resulting 1995 to 1996 VMT growth factors by State and roadway type calculated
as FHVMT96S;RT/TRVMT95S;RT.
The resulting annual county-level vehicle and roadway type specific VMT data were temporally
allocated to months. Seasonal 1985 NAPAP temporal allocation factors7 were used to apportion the
VMT to the four seasons. Monthly VMT data were obtained using a ratio between the number of days in
a month and the number of days in the corresponding season.
4.6.1.4 State-Provided 1990 VMT
Thirteen of the 38 states supplied VMT estimates covering the entire state, an additional 3 states
supplied VMT estimates covering part of their state, and Emission Trends VMT was used for the
remaining 25 states. Fifteen of the 38 states in the Ozone Transport Assessment Group (OTAG) Domain
supplied MOBILES a input files for all or part of their state and input files developed for the Interim
Inventory were used for the remaining 23 states. Table 4.6-5 lists the state-level daily VMT totals in the
OTAG Inventory. Figure 4.6-1 is a map that displays which states supplied VMT.
4.6.2 Development of VOC, NOX, and CO Emission Factors
EPA's MOBILE5a for the years 1970 through 1994 and MOBILE5b for the years 1995 and 1996
mobile source emission factor model was used to calculate all emission factors.8 The pollutants modeled
were exhaust VOC, evaporative VOC (which includes resting loss, running loss, and evaporative
emissions), exhaust NOX, and exhaust CO. VOC emissions include aldehydes and hydrocarbons
measured by Flame lonization Detector (FID) testing.
4.6.2.1 Temperature
The temperature data used for Emission Trends inventory included an average daily maximum and
minimum temperature for each state for each month for each year from 1970 to 1996. The data were
obtained on diskette from the National Climatic Data Center.9 A single city was selected from each state
to represent the state's temperature conditions. The cities were selected to be the most representative of
the average conditions within the state, generally either centrally located cities or, in states with a
majority of VMT clustered in one area, the most populous cities. Because of the great variations of
temperature and the wide distribution of VMT throughout California, California was divided into two
geographic regions, with Los Angeles representing the southern and interior portions of the state and San
Francisco representing the northern coastal region of the state. Table 4.6-6 shows the cities that were
used to represent each state's temperature conditions. In cases where temperature data were missing for
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a month or more, 30-year average monthly maximum and minimum temperature values were used from
Statistical Abstracts.10 The allowable temperature range for input to the MOBILE model is 0°F to 100°F
for the minimum daily temperatures and 10°F to 110°F for the maximum daily temperatures. In the few
cases where the temperatures fell outside of these ranges, the endpoint of the range was substituted for
the actual temperatures.
4.6.2.2 RVP
This section describes the methodology used to apportion Reid vapor pressure (RVP) values to each
state by month. The steps involved in making these calculations were as follows: (1) assigning a January
and July RVP to each state, and (2) estimating the RVP for the other months for each state. In some
cases, adjustments were then made to the calculated RVP values to eliminate the effects of lower RVP
due to reformulated gasoline in areas not receiving reformulated gasoline. In addition, some states
provided summer RVP data to OTAG that differed from the values calculated here. The procedures used
to account for these factors are described below.
4.6.2.2.1 Apportioning RVP Data to Each State —
The first step in the process of determining monthly RVP values for each state was to assign a
weighted January and July RVP for each year to every state. EPA's Office of Mobile Sources (OMS)
provided spreadsheets of historic RVP data that included the average January and July RVP values
weighted by the market share of each type of gasoline (regular unleaded, intermediate unleaded, premium
unleaded, etc.) from each of the 23 cities included in the American Automobile Manufacturer's
Association (AAMA) fuel surveys.11 These data were provided for each year from 1970 through 1996.
Using these data, January and July RVP values were assigned to each state for each year. This was done
using a listing, provided by OMS, matching each nonattainment area and many Metropolitan Statistical
Areas (MSAs) throughout the United States with the corresponding AAMA survey city whose RVP
should be used to represent that nonattainment area. These assignments were based on pipeline
distribution maps and are shown in table 4.6-7. The corresponding January and July weighted RVP
values were then assigned to each of these nonattainment areas. The January or July RVP values for a
given year for all nonattainment areas and listed MSAs within a state were then averaged to estimate a
single statewide January or July RVP value. Several states had no nonattainment areas or MSAs included
in the OMS cross reference listing. Survey cities were assigned to these states by OMS based on a
combination of location and pipeline maps. These assignments were as follows:
State Survey City
Idaho Billings, MT and Seattle, WA
Iowa Minneapolis, MN
Nebraska Kansas City, MO and Minneapolis, MN
North Dakota Minneapolis, MN
South Dakota Minneapolis, MN
Wyoming Billings, MT and Denver, CO
For states where two survey cities are listed, the average of the RVP values for the two survey cities was
used. Alaska and Hawaii were not matched with survey cities but were assigned winter and summer RVP
values based on guidance from OMS. Alaska was assigned a winter RVP value of 14.5 psi and a summer
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RVP value of 12.5 psi while Hawaii was assigned a winter RVP value of 10.0 psi and a summer RVP
value of 9.5 psi. These assignments applied for each year from 1970 through 1996.
4.6.2.2.2 Estimating Monthly RVP for Each State —
The next step in the process of allocating RVP values was to estimate statewide RVP values for the
remaining months based on the January and July RVP values. The ASTM schedule of seasonal and
geographical volatility classes was used as the basis for the RVP allocation by month.12 This schedule
assigns one or two volatility classes to each state for each month of the year. Volatility classes are
designated by a letter (A through E), with A being the least volatile. Several states are divided into two
or more regions, with each region having its own set of volatility class guidelines. The MOBILE4 User's
Guide13 provides guidance on which ASTM class to assign to each state for each month when more than
one region is included for a state, or when two ASTM classes are listed for a given state in a given
month. This guidance was followed here to select a single ASTM class for each state and month. The
MOBILE4 User's Guide also lists RVP limits that correspond to each ASTM class. These RVP limits
are as follows:
ASTM class A = 9.0 psi
• ASTM class B = 10.0 psi
ASTM class C = 11.5 psi
• ASTM class D = 13.5 psi
ASTM class E = 15.0 psi
The January ASTM class designation was assigned to the January RVP value calculated for each state
and the July ASTM class designation was assigned to the July RVP value calculated for each state. Other
months with the same ASTM class designation as either January or July were assigned the January or July
RVP value for that state. The RVP values for months with intermediate ASTM class designations were
calculated by interpolation using the January and July RVP values and the ASTM class RVP limits.
Equation 4.6-5 was used for this interpolation.
IM = [(IA - SA) x (WM - SM) I (WA - SA)] + SM (Eq. 4.6-5)
where: IM = Intermediate month's (not January or July) RVP value
WM = Winter (January) RVP value
SM = Summer (July) RVP value
IA = Intermediate month's (not-January or July) ASTM RVP limit
WA = Winter (January) ASTM RVP limit
SA = Summer (July) ASTM RVP limit
Calculations were made for each intermediate month for each state. Starting in 1989, summer RVP
values were limited by EPA's Phase I RVP limits and in 1995 by the Phase II RVP limits. After the May
through September RVP values were calculated for each state using the procedure above, the values
were replaced by the state-specific monthly Phase I (for 1989 to 1991) or the Phase II (for 1992 through
1996) limit if the corresponding limit was lower than the calculated monthly RVP value.
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4.6.2.2.3 Eliminating RVP Effects of Reformulated Gasoline, 1995 and 1996 —
Several of the AAMA survey cities are areas that received reformulated gasoline in 1995 and 1996.
Because the July RVP of reformulated gasoline is almost always lower than the July RVP values of
regular gasoline that would be sold in the same geographic area, using a reformulated gasoline survey city
to represent RVP values for areas receiving regular gasoline would give inappropriately low RVP values
for these areas. To rectify this situation, for each of the AAMA survey cities receiving reformulated
gasoline in 1995 and 1996, OMS provided a substitute survey city to use when calculating the July RVP
values of areas without reformulated gasoline.14 This substitute survey city assignment is shown in table
4.6-8. The procedure discussed above for determining state-level July RVP values in states that receive
both reformulated gasoline and regular gasoline was modified to determine separate RVP values for both
types of areas. To calculate the July RVP of regular gasoline in the state, the RVP of the substitute
survey cities replaced the RVP of the original survey cities and the RVP was recalculated. This value was
then used for areas in the state that did not receive reformulated gasoline.
4.6.2.2.4 State-Supplied R VP Data —
Some states supplied summer 1995 RVP data for OTAG that differed from the values calculated
using the methodology discussed above. In these cases, the calculated 1995 and 1996 RVP values for the
months from May through September were replaced by the state-supplied data. In some cases, the
state-supplied data varied within a state. These distinctions were maintained in the Trends modeling.
The resultant 1995 and 1996 monthly RVP data for all areas are shown in tables 4.6-9 and 4.6-10,
respectively.
4.6.2.3 Speed
Representative national speeds were developed for each vehicle type/roadway type combination.
Average overall speed data, output from the HPMS impact analysis were obtained for the years 1987
through 1990.1 The average overall speed for each vehicle type varied less than one mile per hour (MPH)
over the four-year span. Therefore, the speed data from 1990 were used for all years from 1970 to 1996.
Table 4.6-11 lists the average overall speed output for 1990 from the HPMS impact analysis. To
determine the actual speeds to use in modeling the emission factors, HPMS vehicle types were chosen to
represent the speeds for each MOBILE vehicle type:
• passenger cars — used for light-duty gasoline vehicles (LDGVs), light-duty
diesel vehicles (LDDVs) and motorcycles (speeds for small and large cars were
the same)
• pickup trucks and vans — used for light-duty gasoline truck 1 (LDGT1 [trucks
less than 6,000 Ibs in weight]), LDGT2 (6,000 to 8,500 Ibs in weight), light-duty
diesel trucks (LDDTs)
• multi-trailer trucks with five or more axles — used for heavy-duty gasoline
vehicles (HDGVs) and heavy-duty diesel vehicles (HDDVs)
To reduce the number of speeds to be modeled, the HPMS speeds were rounded to the nearest
5 MPH. Local speeds, which were not included in the HPMS impact analysis output, were assumed to be
the same as minor collector speeds for rural roads and collector speeds for urban roads. Table 4.6-12
lists the average speed used for each road type/vehicle type combination. No state-supplied speed data
were used in the Trends calculations.
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It is recognized that the abolition of the national speed limit in 1995 may have caused overall speeds
to increase, particularly on rural interstates. However, little data are currently available to assess the
impacts of the change in speed limits on actual travel speeds. In addition, the maximum speed that can be
modeled in MOBILE 5b is 65 MPH, so that even if the speed data were available, emission factors for
these higher speeds could not currently be modeled with MOBILE5b.
4.6.2.4 Operating Mode
All MOBILE runs at all speeds were made using the operating mode assumptions of the Federal
Test Procedure (FTP) with the exception of Maryland and Texas, as described below. With the FTP,
20.6 percent of all VMT is accumulated in the cold start mode (or Bag 1 of the FTP), 27.3 percent of all
VMT is accumulated in the hot start mode (or Bag 3 of the FTP), and 52.1 percent of all VMT is
accumulated in the hot stabilized mode (or Bag 2 of the FTP).
Two states supplied their own data on operating modes—Maryland and Texas. These state-supplied
operating modes were substituted for the default FTP operating mode in the 1995 and 1996 MOBILE5b
input files for these states. The operating mode data modeled for these two states are shown in table
4.6-13.
4.6.2.5 Altitude
The entire states of Colorado, Nevada, New Mexico, and Utah were modeled as high altitude areas.
All other states were modeled as low altitude areas.
4.6.2.6 Registration Distribution/Month
A national registration distribution was included in all of the MOBILE input files. These registration
distributions varied by calendar year and show the fraction of vehicles registered in the given calendar
year by model year. Separate registration distributions are developed for each vehicle type (with a single
registration distribution for light duty gasoline and diesel vehicles and a single registration distribution for
light duty gasoline trucks I and light duty diesel trucks). Registration distributions developed under
earlier Emission Trends work assignments were used for calendar years 1970 through 1994. New
registration distributions were developed under this assignment for 1995 and 1996.
The main difference between the 1991 registration distribution and those of previous years is the
expansion from a 20-year distribution to a 25-year distribution. In addition to the development of the
1991 distribution, data used in the development of the 1990 registration distribution were updated with
more current vehicle sales figures. All registration distributions for the years 1980 through 1990 were
also expanded to a 25-year range.
The specific procedures used in each of the steps outlined above are discussed in detail in the
following sections. In some cases, the methods used for this version of Emission Trends inventory
correspond to procedures used in previous years, while in other cases, improvements have been made to
the estimation procedure. Both old and new methods are documented below.
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Vehicle registration distributions for 1991 through 1996 were developed using a dBase computer
program. (This program was developed to perform the computations that had been done for earlier
Emission Trends inventory in a spreadsheet model.) This registration distribution program estimates the
distribution of vehicles operating by model year in 1991 through 1996 for each of the eight MOBILE
vehicle types. For automobiles, the registration distribution is based on the number of cars in operation
by model year as reported in AAMA's Facts and Figures 1996n and sales data from Automotive News'
Market Data Book 1996.15 For each of the five MOBILE truck classes, the distribution is based on sales
figures from AAMA and Automotive News, as well as the number of trucks in operation by model year
from AAMA. For motorcycles, the registration distribution for these three years did not change from
previous years; this distribution was taken from the default distribution from the previous Emission
Trends procedures, which covered a 12-model-year range. The specific procedure used to calculate the
registration distribution for automobiles and trucks is discussed below.
4.6.2.6.1 Automobiles —
AAMA's Facts and Figures 1996 lists the number of cars in operation by model year. The most
recent calendar year for which data are available from this source is 1995. The number of cars in
operation in 1995 for each model year from 1980 through 1995 was used as a preliminary estimate of the
number of cars from these model years operating in 1995. (These will be updated in the next version of
Emission Trends inventory by AAMA's actual estimates for the 1996 calendar year.)
The earliest model year for which data were given on the number of cars operating in 1995 was the
1980 model year. The figure given for the number of model year 1980 cars operating in 1995 is actually
an aggregate figure of the number of cars from 1980 and all earlier model years still operating in 1995. A
methodology was developed to distribute the cars operating from model year 1980 and earlier years over
the remaining 9 years required for developing a 25-year registration distribution. To do this, a formula
was derived using automobile survival rates to project estimates of operation for these older cars by
model year to 1996.16 Based on AAMA data for previous years, the number of cars from each model
year from 1971 through 1980 still in operation in 1996 was estimated using Equation 4.6-6.
C
Model YearN Cars in Operation in Yearl996= AX — (Eq. 4.6-6)
B
where: A = AAMA number of Model YearN Cars Operating in YearY
B = Survival rate for ageY_N
C = Survival rate for age1996_N
Year = Last calendar year for which an estimate is available for this particular model
year (as of July 1)
N = Most current model year for which 'Number of Automobiles in Operation' are
available
For example, in calculating the 1995 registration distribution, the most recent calendar year
for which data on the number of 1976 model year cars still in operation is available is 1990. Facts
and Figures indicates that 2.981 million 1976 model year cars were operating in 1990. The car
survival rate from 1976 to 1995 (19 years of survival) is 0.10130.16 The car survival rate from
1976 to 1990 (14 years of survival) is 0.32221.16 Thus, of the 2.981 million 1976 model year cars
that survived to 1990, it is expected that 31 percent (0.10130/0.32221) or 0.937 million will survive
to 1995.
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To develop an estimate of the number of 1996 model year cars operating in 1996, the number of
1995 registrations of model year 1995 automobiles was multiplied by 0.75, since by July 1, three-quarters
of the car model year had passed (new model year automobiles are generally released in October).
Using this complete set of automobile registrations by model year for the 25-year period from 1972
to 1996, the registration distribution was calculated by dividing the number of cars in operation by model
year by the total number of cars operating over the 25-year period. This process was repeated to develop
a registration distribution for 1991 through 1995. The only difference for these years is that the number
of cars in operation in the most recent model year was available from AAMA for these previous years and
therefore, no projections of the number of cars in operation were made for the latest model year.
4.6.2.6.2 Trucks —
For each truck type, the 1995 registration distribution was calculated with truck sales figures by type
and model year, which were weighted by the distribution of truck registrations (the total over all truck
types) from AAMA's Facts and Figures 1996. The basic methodology for calculating this distribution is
outlined below.
The first step was to determine 1995 truck sales by MOBILE5b truck category. (Sales figures for
years prior to 1995 were not changed from those used in calculating previous years' registration
distributions.) Because AAMA's truck categories do not directly correspond to the categories used in
MOBILE5b. The method described below was used for allocating sales from AAMA's weight class
categories to the MOBILE truck categories. The data needed for the 1995 model year for each of the
formulas listed below were obtained from Facts and Figures 1996. The sales data for the earlier model
years needed for a 1995 registration distribution were already calculated for registration distributions
prepared for previous Trends inventories, and used similar data from earlier versions of Facts and
Figures. The equations used to estimate sales for each MOBILE5b truck category are listed below. The
formulas used for the 1991 through 1996 distribution are shown in Equations 4.6-7 through 4.6-11.
LDGT1 = Retail Sales (domestic + import)^ _6000lbs}- Diesel Factory Sales (Q_6ftmlbs) (Eq. 4.6-7)
n ., Diesel
LDGT2 = *„£"- VCC - M - (0.05 x CP) - Factory (Eq. 4.6-8)
^nlp?
outtj / (6,000-10,000/te)
where: VCC = Retail sales of van cutaway chassis
M = Retail sales of multi-stops
CP = Retail sales of conventional pickups
wnrr - (vrr + M + h n<; x r-Pl f Heavy-Duty] (Retail]
HDGT - (VCC + M + [0.05 x CP)(6000_10000/fa) - [DiesdTmcks) + [ Sales) ^tWMUa) ^ 4'6'9)
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LDDT = DieselFactorySales,Q_6fmlbs) + (Q.lQx Diesel Factory Sales\6>om_10>molbs) (Eq. 4.6-10)
HDDT = [0.9 x (pieselFactorySales\6>000_10>WKlbs) (Eq. 4.6-11)
Once AAMA sales data for the 1995 model year were converted into sales data by MOBILESb
truck categories, the fraction of total 1995 truck sales in each of these five MOBILESb truck categories
was calculated. This was done for each model year from 1971 through 1994, using data from earlier
versions of Facts and Figures.
Next, a full 25-year distribution of trucks in operation in 1995 by model year from the 1971 through
the 1995 model years was calculated. AAMA listed the total number of trucks (of all types) in operation
by model year in 1995 back to 1981. All trucks in operation from model years 1980 and earlier were
provided as an aggregate figure. The total number of trucks in operation from 1980 and earlier model
years was distributed to each model year from 1971 to 1980 using the method described above for
distributing the figure of cars in operation from the 1980 and earlier model years to the same set of model
years. The survival rates used for distributing the number of trucks in operation were specific to trucks,
rather than cars.
Using the fraction of truck sales by truck type for each of the 25 model years needed and the number
of total trucks in operation in 1995 for each of the 25 model years needed, separate 1995 registration
distributions were calculated for each truck type. This was accomplished by multiplying the total number
of trucks in operation in 1995 in a given model year by the fraction of truck sales of the specified truck
type in the given model year. For example, Equation 4.6-12 shows how the number of 1990 model year
LDGTls operating in 1995 was calculated.
1990 Model Year LDGTls = Total Model Year 1990 x 1990 Model Year LDGTls Sold
Operating in 1995 Trucks Operating in 1995 Totai 1990 Model Year Trucks Sold ^ q' 4-6'12)
This process was applied to all five truck types for model years 1971 through 1995. With the number of
trucks in operation 1995 by truck type and model year, the 1995 registration distribution for each truck
type was calculated by dividing the number of trucks operating in 1995 from a given model year by the
total number of trucks operating in 1995 for that particular truck category.
The 1996 truck registration distributions were projected from the data calculated for the 1995 truck
registration distributions. The calculated numbers of trucks in operation in 1995 for each truck class by
model year were projected to the numbers of trucks in operation in 1996 for each truck class by model
year by multiplying the number of trucks in operation in 1995 by truck survival rates (Miaou, 1990) to
obtain the corresponding numbers that would have survived to 1996. This is the same as the process
used to project the 1995 car registration distribution to 1996. As with the procedure for cars, estimates
of the number of 1995 and 1996 model year trucks operating in 1996 were calculated separately. All of
the 1995 model year trucks would not have been sold by the end of the 1995 calendar year. Therefore,
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the number of 1995 model year trucks operating in 1996 should represent an increase over the number of
1995 trucks operating in 1995, and a survival rate of 1995 cars to 1996 should be factored in. Truck
sales for 1996 were estimated as 50 percent of the 1995 sales figures for each of the truck categories.
(The truck model year is assumed to start in January, so half of the model year trucks would be sold by
July 1.) As with the development of the 1995 truck registration distributions, the last step in calculating
the 1996 truck registration distribution was to divide the number of trucks in operation in each model
year by the total number of estimated trucks in operation in 1996.
The PART5 modeling requires that user-supplied registration distributions include a separate
distribution for each of the five HDDV subcategories (Class2B HDDVs, Light HDDVs, Medium
HDDVs, Heavy HDDVs, and Buses). The procedures described above were used to calculate the
distributions for these additional vehicle subcategories. The table below shows how the sales for each of
these five HDDV categories were calculated. All of the relevant sales data came from Facts and Figures.
Once the sales data were extracted for each of these HDDV categories, the above procedures were
applied individually to each category to obtain the five separate HDDV registration distributions required
byPART5.
Truck Class Data Used to Calculate Truck Sales
2B HDDVs 0.90 *U.S. Factory Sales of Diesel Trucks 6,001 to 10,000 Ib GVWR
Light HDDVs U.S. Factory Sales of Diesel Trucks 10,001 to 19,500 Ib GVWR
Medium HDDVs U.S. Factory Sales of Diesel Trucks 19,501 to 33,000 Ib GVWR
Heavy HDDVs U.S. Factory Sales of Diesel Trucks 33,001 Ib GVWR - Factory Bus Sales
Buses Factory Bus Sales
Registration distributions input to MOBILE5a should be expressed as a July 1 registration
distribution. Internally, the model can than adjust this registration distribution to represent either a
January 1 or a July 1 registration distribution, depending on the user selected setting of the month flag.
When modeling months from January through June, the month flag within the MOBILE5a input files was
set to "1" to simulate January registration distributions. For months from July through December, the
flag was set to "2" to model July registration distribution.
4.6.2.6.3 Local Registration Distributions for 1990,1995, and 1996 —
For the 1990, 1995, and 1996 MOBILE5b modeling, the national registration distributions were
replaced in some states by state-provided data. The state-provided data were extracted from the
registration distributions provided by the states for the OTAG modeling. In some states, a single
registration distribution applied to the entire state. In other states, different registration distributions
applied to different groupings of counties, such as nonattainment areas or MS As. Since these
state-provided registration distributions did not vary by year, the same distributions were applied in 1995
and 1996. All of the state-supplied registration distributions included only a single distribution for
HDDVs, since they were all created for use with MOBILE. To use the state-supplied distributions in
PART5, the HDDV distributions were replicated for each of the PART5 HDDV subcategories.
Figure 4.6-1 shows each state-supplied registration distribution used in the Trends modeling, in
MOBILE5b format. Along with each distribution is a list of the state or counties that the distribution was
applied to.
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4.6.2.7 MONTH Flag
Registration distributions input to MOBILESb are expressed as July 1 registration distributions.
Internally, the model then adjusts this registration distribution to represent either a January 1 or a July 1
registration distribution, depending on the user selected setting of the MONTH flag. When modeling
months from January through June, the MONTH flag within the MOBILESb input files was set to "1" to
simulate January registration distributions. For months from July through December, the flag was set to
"2" to model July registration distributions.
4.6.2.8 Additional Area Specific Inputs from OTAG
In addition to the inputs discussed above, several additional MOBILESb inputs were supplied by the
states for the OTAG modeling and incorporated into the Trends MOBILESb input files. These inputs are
listed below followed by the states that provided the inputs:
• trip length distributions (DC, MD, TX, and VA)
• alcohol fuel market shares (GA, IL, IN, MI, MO, and WI)
• diesel sales shares (DE, MD, and VA)
The state-supplied trip length distribution data were applied in 1995, 1996, and the projection years.
Table 4.6-17 summarizes the state-supplied trip length distribution data. The alcohol fuel market share
data were applied only in the 1995 and 1996 modeling. Table 4.6-18 lists the alcohol fuel market share
data supplied by and modeled for the listed states. As with the alcohol fuel data, the state-supplied diesel
sales shares were modeled only in 1995 and 1996. Table 4.6-19 shows the diesel sales data modeled for
the listed states. For all other states, the MOBILE5b model defaults were assumed for these variables.
4.6.2.9 Control Program Inputs
4.6.2.9.1 Inspection and Maintenance (I/M) Programs —
Modeling an I/M program in MOBILE requires the most complex set of inputs of any highway
vehicle control program. The sources used for developing the necessary I/M program inputs included the
I/M program inputs supplied by states to the OTAG process, a summary prepared by OMS showing the
basic characteristics of I/M programs planned by the states,17 past OMS I/M program summaries showing
characteristics of historical or current I/M programs in each state, and inputs prepared for previous
Trends inventories.
For states that had an I/M program in place in one or more counties in the year being modeled, at
least one additional MOBILE input file was created that modeled the characteristics of the I/M program
in that state. All other inputs (such as temperature, RVP, speeds, etc.) were identical to the no I/M input
file modeled for the state in the year being analyzed. The determination of whether or not a county had
an I/M program in place in a given year was based on a series of I/M program summaries released by
OMS. Emission factors calculated with I/M benefits in a given inventory year were applied only to
counties having an I/M program in place in December of the prior year. I/M program characteristics
were also included in the I/M program summaries. These program characteristics vary by state and in
some cases by nonattainment area or county within a particular state. The effectiveness statistics used as
MOBILES inputs varied by state based on the characteristics of representative I/M programs in that state.
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For states where I/M programs varied within a given state, a single set of effectiveness statistics, based on
a combination of characteristics of all the I/M programs within the state, was used as an I/M input to the
model. In some cases, the characteristics of the different programs within a specific state could not be
adequately modeled using some average of the I/M program characteristics. In these cases, multiple I/M
programs were modeled for these states, with the appropriate I/M programs applied to the corresponding
counties.
A number of states provided data to OTAG that included MOBILE I/M program inputs and the
counties that these inputs should be applied to. These state-provided I/M inputs replaced the OMS I/M
program data for 1995 and 1996. states with I/M programs outside of the OTAG domain were modeled
according to the I/M program parameters supplied by OMS. The specific inputs modeled for each area's
I/M program in 1995 and 1996 are shown in table 4.6-14. This table also indicates whether the inputs
applied in 1995, 1996, or both years. Table 4.6-15 shows which counties each set of I/M programs
inputs were applied to.
4.6.2.9.2 Reformulated Gasoline —
Phase I of the Federal reformulated gasoline program began on January 1 of 1995. Phase I
reformulated gasoline provides year-round toxic emission reductions and additional VOC emission
reductions during the ozone season (May through September). The Clean Air Act Amendments of 1990
(CAAA) mandates that reformulated gasoline be applied in the nine most severe ozone nonattainment
areas and allows additional nonattainment areas to opt in to the program. OMS provided a list of areas
that participated in this program, which is included as table 4.6-20.
Reformulated gasoline was modeled in the appropriate MOBILE5b input files by setting the
reformulated gasoline flag to "2", including the appropriate ASTM class of the area being modeled (B or
C), and setting WINFLG (a hidden MOBILE5b flag) to "2". Setting WINFLG to "1" guarantees that the
summer reformulated gasoline reductions are modeled regardless of the setting of the MONTH flag. For
all other months, and for areas not included in the reformulated gasoline program, WINFLG is either set
to "2" or not included (in which case the model defaults to a setting of "2").
4.6.2.9.3 Oxygenated Fuels —
The oxygenated fuel requirements of the 1990 CAAA took effect beginning in late 1992. Therefore,
oxygenated fuel was modeled in the areas indicated by OMS, using the oxygenated fuel flag and the
oxygenated fuel market share and oxygen content inputs in MOBILE. OMS provided a listing of areas
participating in the oxygenated fuel program,18 the months that each area used oxygenated fuel, and
market share data indicating the percentage of ether blends versus alcohol blends in each oxygenated fuel
area. The average oxygen content of ether blend fuels for all areas, except California, was assumed to be
2.7 percent while alcohol blend fuels were assumed to have an oxygen content of 3.5 percent. For
California, the oxygen content of both ether blends and alcohol blends was modeled as 2 percent, based
on documentation from OMS on how to model reformulated and oxygenated fuels in the CALI5 model.
Table 4.6-16 lists the areas modeled with oxygenated fuels and the corresponding inputs used for these
areas.
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4.6.2.9.4 National Low Emission Vehicle (NLEV) Program —
A National Low Emission Vehicle (NLEV) program was modeled in the projection years, using
EPA's most current, at the time the modeling was performed, assumptions about the characteristics of the
proposed NLEV program. This program was modeled as starting in the Northeast Ozone Transport
Commission (OTC) states in 1999, and the remaining (non-California) states in 2001. States in the OTC
that had already adopted a LEV program on their own were modeled with the characteristics of the
OTC-LEV program until the start date of the NLEV program. These states included Massachusetts,
New York, and Connecticut. The implementation schedule of the NLEV program is shown below.
Model Year
1999
2000
2001 and later
Federal Tier I
Standards
30%
Transitional LEV
Standards
40%
40%
LEV Standards
30%
60%
100%
States in the OTC states that had already adopted a LEV program on their own at this time were
modeled with the characteristics of the OTC-LEV program until the start date of the NLEV program.
The states included Massachusetts, New York, and Connecticut (the program start years varied). The
programs in Massachusetts and New York began with the 1996 model year. The Connecticut program
began with the 1998 model year. The implementation schedule followed by these states prior to 1999
(the start year of the NLEV program) are based on the implementation schedule of the OTC-LEV
program, and is shown below. Only the 1998 model year is applicable in Connecticut.
Model
Year
1996
1997
1998
Federal Tier I
Standards
80%
73%
47%
TLEV
Standards
20%
Intermediate
LEV Standards
25%
LEV
Standards
51%
Intermediate
ULEV Standards
2%
ULEV Standards
2%
These LEV implementation schedules differ from the MOBILESb default LEV implementation
schedule, which was designed to model the California LEV program. For the model to access the
implementation schedule of the NLEV program, the PROMPT flag in the applicable MOBILESb input
files was set to '5' and the name of the file containing the NLEV implementation schedule was entered
when prompted by MOBILESb. In addition to setting the PROMPT flag, the REGION flag was set to
'4' to properly model the NLEV program in the MOBILESb input files. The setting of '4' for the
REGION flag indicates that an additional line is being added to the input file to model a LEV program.
The necessary inputs for this additional program line include the start year of the LEV program and
whether an "appropriate" I/M program will be implemented in conjunction with the LEV program. The
start year of the LEV program was set to "96" for input files modeling Massachusetts and New York,
"98" for input files modeling Connecticut, "99" for input files modeling all other states within the OTC
(including the Washington DC nonattainment area portion of Virginia), and "01" for all remaining states
(including the remainder of Virginia), excepting California. With an "appropriate" I/M program,
maximum benefits of the LEV program are modeled by MOBILESb, implementing a lower set of
deterioration rates.
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The following table shows the emission standards of the Federal Tier I program, the transitional
LEV (TLEV) standards, and LEV standards, and the Ultra-Low Emission Vehicle (ULEV) standards.
These standards apply to the LDGV and LDGTla classes of vehicles. The LDGTlb category is also
included in the NLEV program, but the emission standards for these vehicles are slightly less stringent
than those listed below for the lighter vehicles.
Emission Standard
Federal Tier 1
Transitional LEV (TLEV)
LEV
Ultra-Low Emission Vehicle
(ULEV)
Nonmethane Organic
Gas (NMOG)
0.250 grams/mile NMHC
0.125 grams/mile
0.075 grams/mile
0.040 grams/mile
CO
3.4 grams/mile
3.4 grams/mile
3.4 grams/mile
1.7 grams/mile
NOX
0.40 grams/mile
0.40 grams/mile
0.20 grams/mile
0.20 grams/mile
4.6.2.9.5 Heavy-Duty Diesel Engine Corrections and Controls —
A correction was made to the basic emission rates (BERs) for HDDVs and HDGVs as specified by
OMS. This correction modifies the default MOBILESb zero mile level (ZML) (the ZML is the emission
rate at the beginning of a vehicle's life) and DR (the DR reflects how quickly the emission rate of a
vehicle increases with time) for NOX for HDDVs and NOX and VOC for HDGVs. EPA believes that
these default ZMLs and DRs in MOBILESb are not reflective of actual heavy-duty vehicle emissions.19
The corrected BERs input to MOBILESb are shown below. These inputs were included in all of the
1995, 1996, and projection year input files, for both low and high altitude areas. In addition, the
NEWFLG in the MOBILESb input files was set to "2" to incorporate these additional input lines.
Vehicle Category
HDGV
HDGV
HDDV
Model Year
1998 +
1994 +
1994-2003
ZML
(g/bhp-hr)
3.19
NO,
DR
(g/bhp-hr/10k
mi)
0.045
VOC
ZML
(g/bhp-hr)
0.364
0.283
DR
(g/bhp-hr/10k
mi)
0.023
0.000
Note(s): g/bhp-hr = grams per brake horsepower-hour; k = 1,000
4.6.2.9.6 California —
California's highway vehicle fleet has been subject to different emission standards than the rest of the
country. To account for these differences in basic emission rates, an EPA-modified version of
MOBILES a, referred to as CALI5, was used for California. Input files used with this model are
essentially identical to MOBILESa input files. The model internally handles the different emission
standards. Temperature, RVP, speed, registration distribution, and operating mode inputs were
developed for California in the same manner as they were for the rest of the nation. The primary
difference in inputs is the earlier start date (1995) of the reformulated gasoline program in California.
Using CALI5, this was modeled in the summer months for 1995 by setting the reformulated gasoline flag
to "4". Phase II of California's reformulated gasoline program began on June 1, 1996. This was
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modeled by setting the reformulated gasoline flag to "5" starting with the June 1996 scenarios in the
CALI5 input files and in all of the projection year files. In addition, California was also divided into two
temperature regions to account for the differences in climate throughout the state.
California's low emission vehicle (LEV) program began in 1994. This was modeled in the CALI5
input files indicating a start year of 1994 for this program and minimum LEV credits. Because
MOBILESa did not include LDGT2s in the LEV modeling, this was carried forward to CALI5.
However, California's LEV program does include LDGT2s. To model the LDGT2s in the LEV
program, additional BER input lines were added that model the zero mile level (ZML) and deterioration
rate (DR) of the California LEV program standard for LDGT2s. Two sets of basic emission rates
(BERs) were developed—one modeling the maximum LEV benefits for LDGT2s and the other modeling
the minimum benefits. (The maximum LEV benefits were applied in areas modeled with the high
enhanced I/M program beginning in 2005.)
4.6.3 Development of PM and SO2 Emission Factors
In 1994, EPA released a computer model, with the acronym PARTS, that can be used to estimate
particulate emission rates from in-use gasoline and diesel-fueled motor vehicles.20 It calculates particle
emission factors in grams per mile from on-road automobiles, trucks, and motorcycles, for particle sizes
up to 10 microns. PARTS was used to calculate on-road vehicle PM-10 and PM-2.5 (PM-2.5 for the
years 1990-1996 only) emission factors from vehicle exhaust, brake wear, tire wear, and reentrained road
dust from paved and unpaved roads (see sections 4.8.2.3 and 4.8.2.4 for details on road dust emissions),
and SO2 vehicle exhaust emission factors.
Basic assumptions regarding inputs to PARTS were made that apply to all PARTS model runs, and
include the following:
• The transient speed cycle was used.
• Any county with an existing I/M program was given I/M credit from PARTS, regardless of the
details of the I/M program. PARTS gives credit based on the assumption that high emitting
vehicles will be forced to make emission reducing repairs and that an existing I/M program will
deter tampering. This only affects lead and sulfate emissions from gasoline-powered vehicles.
• Using the input parameter BUSFLG, bus emission factors for all rural road types, urban
interstates, and other freeways and expressways road types were modeled using the PARTS
transit bus emission factors, while bus emission factors for all other urban road types were
modeled using the PARTS Central Business District bus emission factors.
4.6.3.1 Registration Distribution
The vehicle registration distribution used was also common to all PARTS model runs. PARTS uses
the same vehicle classifications as the MOBILE model, except that the MOBILE HDDV class is broken
into five subclasses in PARTS. Table 4.6-21 lists each vehicle class in PARTS along with its FHWA class
and gross vehicle weight.
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To maintain consistency with the NET Inventory, the year specific vehicle registration distribution
used in the MOBILE modeling for the NET Inventory was adapted for this analysis. This registration
distribution was modified by distributing the MOBILE HDDV vehicle class distribution among the five
PARTS HDDV subclasses (2BHDDV, LHDDV, MHDDV, HHDDV, and BUSES). This was
accomplished using HDDV subclass-specific sales, survival rates, and diesel market shares.
4.6.3.2 Speed
The speed inputs documented in Section 4.6.2.3 were used in the PARTS modeling as well, with the
exception that the maximum allowable speed in PARTS is 55 mph, so the rural interstate speed was
changed from 60 mph to 55 mph for the PART5 modeling (see table 4.6-22). Emission factors were
calculated for each combination of state, I/M status, month, vehicle type, and speed. VMT data for each
county/month/vehicle type/road type were mapped to the appropriate emission factor.
4.6.3.3 HDDV Vehicle Class Weighting
After PART5 emission factors are generated, the PART5 HDDV subclass emission factors
(2BHDDV, LHDDV, MHDDV, HHDDV, and BUSES) are weighted together to develop a single
HDDV emission factor, to correspond with the VMT data already developed for the NET Inventory.
These weighting factors are based on truck VMT by weight and truck class from the Truck Inventory and
Use Survey2^ and FHWA's Highway Statistics.4
4.6.3.4 Exhaust PM Emissions
Monthly, county-level, SCC-specific PM emissions from on-road vehicle exhaust components were
calculated by multiplying year specific monthly county-level, SCC-specific VMT by year specific state-
level, SCC-specific exhaust PM emission factors generated using PART5. Since none of the inputs
affecting the calculation of the PM exhaust emission factors vary by month, only annual PM exhaust
emission factors were calculated. PART5 total exhaust emission factors are the sum of lead, soluble
organic fraction, remaining carbon portion, and direct SO4 (sulfates) emission factors.
4.6.3.5 Exhaust SO2 Emissions
National annual SO2 on-road vehicle exhaust emission factors by vehicle type and speed were
calculated using PART5. These emission factors calculated within PART5 vary according to fuel density,
the weight percent of sulfur in the fuel, and the fuel economy of the vehicle (which varies by speed).
None of these parameters vary by month or state. Monthly/county/SCC-specific SO2 emissions were
then calculated by multiplying each county's monthly VMT at the road type and vehicle type level by the
SO2 emission factor (calculated for each vehicle type and speed) that corresponds to the vehicle type and
road type.
4.6.3.6 PM Brake Wear Emissions
The PART5 PM emission factors for brake wear are 0.013 grams per mile for PM-10 and ? grams
per mile for PM-2.5. This value was applied to estimate brake wear emissions for all vehicle types.
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4.6.3.7 PM Tire Wear Emissions
PARTS emission factors for tire wear are proportional to the average number of wheels per vehicle.
The emission factor is 0.002 grams per mile per wheel for PM-10 and ? grams per mile per wheel for PM-
2.5. Therefore, separate tire wear emission factors were calculated for each vehicle type. Estimates of
the average number of wheels per vehicle by vehicle class were developed using information from the
Truck Inventory and Use Survey^ Tire wear PM emissions were then calculated at the
monthly/county/SCC level by multiplying the monthly/county/SCC level VMT by the tire wear emission
factor for the appropriate vehicle type.
4.6.3.8 1970 to 1984 PM and SO2 Emissions
Emission factors for 1970 to 1984 PM-10 and SO2 were not calculated with PARTS. Therefore,
PM-10 and SO2 emission factors using data from AP-42 and other applicable EPA documents. Emission
factors for both of these pollutants were developed on a national basis by vehicle type for each year. The
procedure followed for developing these emission factors is discussed below.
4.6.3.8.1 PM-10 Emission Factors —
On-road vehicle PM-10 emission factors were calculated using the methodology to develop the
Regional Particulate Inventory for 1990.22 National annual 1990 PM-10 emission factors were calculated
for this inventory by vehicle type. Gasoline PM-10 exhaust emission factors were based on exhaust
particulate emission factors specific to the technology type of the vehicle (i.e., catalyst vs. no catalyst)
and model year group.23 These basic exhaust emission factors were then applied within a spreadsheet to
the corresponding portion of the vehicle fleet for each model year from age 1 to 25 comprising the 1990
fleet. Model year specific data indicating the fraction of vehicles with catalysts were obtained from the
MOBILESa source code.8 After obtaining the model year weighted emission factor for each of the
gasoline vehicle types, the model year specific emission factors were then weighted by the model year
travel fraction, obtained using the by-model-year option in MOBILESa that lists VMT fractions for each
model year for the calendar year specified. These model year-weighted emission factors were then
summed to obtain the fleet average exhaust particulate emission factor for each of the gasoline vehicle
types. These particulate emission factors were then multiplied by the PM-10 particle size multiplier from
AP-42. The PM-10 emission factors calculated for LDGVs were also applied to motorcycles.
The same procedure was applied to obtain 1970 and 1984 PM-10 exhaust emission factors for
gasoline-fueled vehicles. PM-10 exhaust emission factors for the intermediate years were calculated by
straight line interpolation. Total PM-10 emission factors were then calculated by adding the brake and
tire wear PM-10 emission factors from AP-42 (which do not vary by year).
PM-10 emission factors from diesel vehicles were calculated using a similar methodology, but using
data by model year and vehicle type for diesel particulate emission factors and diesel travel fractions.24
Again, the particulate emission factors were multiplied by the AP-42 particle size multipliers to obtain
PM-10 exhaust emission factors, and PM-10 brake and tire wear emission factors were added to the
exhaust emission factors.
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The PM-10 emission factors by vehicle type and year used in Emission Trends inventory are shown
in table 4.6-23. These emission factors include the exhaust, brake, and tire wear components of PM-10.
4.6.3.8.2 SO2 Emission Factors —
Equation 4.6-13 was used to calculate the on-road vehicle SO2 emission factors by vehicle type.
SO-EF = SULFCONT x 0.98 x FUELDENS x 453.59 x ±
2 X,y y,z z FUELECON
where: SO2EFxy = SO2 emission factor for vehicle type x in year y (grams per mile)
SULFCONTyz = Sulfur content in year y for fuel type z (fractional value)
FUELDENSZ = Fuel density of fuel type z (pounds per gallon)
FUELECONxy = Fuel economy for vehicle type x in year y (miles per gallon)
The factor of 0.98 in the above equation represents the fraction of sulfur in the fuel that is converted to
SO225 while the 2 represents the weight molecular ratio of sulfur to SO2. The remaining term (453.59) is
the conversion from pounds to grams.
The value used for sulfur content of the fuel depends only on whether is gasoline-fueled or diesel-
fueled. A fuel sulfur content of 0.000339 was used for gasoline-fueled vehicles based on the fuel sulfur
content of EPA baseline fuel while a fuel sulfur content of 0.00226 was used for diesel-fueled vehicles
through September 1993. Fuel density values of 6.17 pounds per gallon for gasoline and 7.05 pounds per
gallon for diesel were used in all years.26
Fleet average fuel economy varies slightly from year to year for each vehicle type. The values used
for fuel economy from 1982 to 1984 were obtained from output from the draft MOBILE4.1 Fuel
Consumption Model27 for all vehicle types except motorcycles. 1982 was the earliest model year
included in this output. Fuel economy values for 1970 through 1981 were estimated using fuel economy
data from Highway Statistics.4 Adjustments were made to the Highway Statistics fuel economy data
since the vehicle classes included in Highway Statistics differ from the MOBILE vehicle classes and to
smooth out the discontinuity in fuel economy estimates between the two sources from 1981 to 1982.
This was done using Equation 4.6-14.
FE(FCM) 1QR9
FExy = FE(HS)xy x J.,_/*1982 (Eq. 4.6-1
where: FExy = Fuel economy value for vehicle type x in year y used SO2 emission
factor calculations (mpg)
FE(HS)xy = Highway Statistics fuel economy for vehicle type x in year y (mpg)
FE(FCM)X 1982 = MOBILE4.1 Fuel Consumption Model fuel economy for vehicle type x in
1982
FE(HS)X;1982 = Highway Statistics fuel economy for vehicle type x in 1982
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This equation was complicated by the differences in vehicle class definitions used in the MOBILE4.1 Fuel
Consumption Model versus those used in Highway Statistics. Therefore, a singe light duty vehicle and a
single light duty truck fuel economy value were calculated for each year. The weighing of gasoline and
diesel vehicles was made using the same OMS apportionment as was used for allocating the HPMS VMT
to the diesel and gasoline categories. Motorcycles were not included in the MOBILE4.1 Fuel
consumption Model. Therefore, a fuel economy value of 50 mpg was used for motorcycles in all years
from 1970 through 1984 based on AAMA motorcycle fuel economy data.11 The fuel economy values
used for each vehicle type and year are shown in table 4.6-24.
The resulting SO2 emission factors by vehicle type and year are shown in table 4.6-25.
4.6.4 Calculation of Ammonia (NH3) Emission Factors
Little research has been done to date on ammonia (NH3) emission factors from motor vehicles. The
most comprehensive vehicle testing including NH3 emission factors available for use in this analysis is
summarized in a report by Volkswagen AG.19 In the testing program described in this report, 18 different
Volkswagen/Audi vehicles from the 1978 through 1986 model years were tested. The vehicles were
selected to represent a cross-section of the Volkswagen/Audi passenger car production program. The
vehicles all had either 4 or 5 cylinder gasoline or diesel engines. Seven of the gasoline vehicles were
equipped with 3-way catalysts with oxygen sensors, seven of the vehicles were diesel-fueled, and the
remaining four vehicles were gasoline vehicles with no catalysts.
Emissions from each of these vehicles were measured using a chassis dynamometer over three
different test procedures: the U.S. FTP, the U.S. Sulfate Emission Test (SET), and the U.S. Highway
Driving Test. The FTP includes both cold and hot engine starts with a cumulative mileage of 11.1 miles
over 505 seconds. The SET simulates 13.5 miles of travel on a freeway in Los Angeles with heavy traffic
over a time of 1,398 seconds. The Highway Driving Test, also known as the Highway Fuel Economy
Test (HFET), results in an average speed of 48.1 mph over 10.2 miles with a maximum speed of 59.9
mph. Both the SET and the HFET are hot start tests (no cold starts are included). Each vehicle was
tested on all three test cycles on the same day, with three to five repeated measurements carried out for
each vehicle on consecutive days.
The mean results of Volkswagen's emission testing program were reported for each of the 18
vehicles tested and for each of the test cycles. The report also shows the total mean value over all three
tests by engine type (gasoline with catalyst, gasoline without catalyst, and diesel). These values
accounting for all three test cycles were used in this analysis to calculate NH3 emission since most types
of driving would be included in one of the three test cycles (i.e., urban driving would be represented by
the FTP; stop and go driving on expressways would be represented by the SET; and freeway driving
would be represented by the HFET). These mean emission factors are shown below.
Engine Type
Mean NH3 Emission Factor (grams/mile)
Gasoline Engine without Catalyst
Gasoline Engine with 3-Way Catalyst
Diesel Engine
0.00352
0.13743
0.00188
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-197
1985-1996 Methodology
On-road Vehicles
-------
Using the NH3 emission factors listed above, emission factors by vehicle type and model year were
calculated using MOBILESb data listing the fraction of vehicles with 3-way catalysts by vehicle type and
travel fractions from MOBILESb output by model year and vehicle type. For the Trends analysis,
motorcycles were assigned the non-catalyst gasoline engine emission factor while all diesel vehicle types
were assigned the diesel engine emission factor listed above.
To calculate the LDGV emission factor for 1995, a MOBILESb run was made to produce
by-model-year output for LDGVs in 1995. The by-model-year travel fractions were extracted from the
resulting MOBILESb output file. Then, for each of the 25 model years included in the by-model-year
output, a weighted emission factor was calculated by multiplying the fraction of LDGVs with 3-way
catalysts in that model year by the emission factor listed above for gasoline engines with 3-way catalysts
(i.e., 0.13743 g/mi) and adding to this the product of the fraction of LDGVs without 3-way catalysts in
that model year and the emission factor for gasoline engines without 3-way catalysts (i.e., 0.00352 g/mi).
This weighted emission factor was then multiplied by the LDGV travel fraction for that model year,
giving a model year-weighted emission factor. This procedure was repeated for each of the 25 model
years included in the by-model-year output for 1995 and the 25 model-year weighted emission factors
were then summed to give the composite 1995 LDGV NH3 emission factor.
The above procedure was repeated for 1995, 1996, and each projection year for LDGVs, LDGTls,
LDGT2s, and HDGVs. Table 4.6-26 summarizes the catalyst fractions used in this analysis by model
year and vehicle type. The resulting NH3 emission factors by year and vehicle type are shown in table
4.6-27. These emission factors were used in calculating NH3 highway vehicle emissions for all counties in
the United States without exception. Note that the NH3 emission factors for each gasoline vehicle type
increase with time as the fraction of vehicles with 3-way catalysts increases, since the Volkswagen study
showed that NH3 emission factors for gasoline vehicles with catalysts are significantly higher than those
for vehicles without catalysts.
4.6.5 Calculation of Emissions
Once the emission factors for all pollutants and VMT were calculated at the level of detail described
above for 1995, 1996, and each of the projection years, emissions were calculated by multiplying the
appropriate emission factors by the corresponding VMT values. Emissions for the MOBILE5b pollutants
(VOC, NOX, and CO) were calculated with emission factors and VMT at the month, county, roadway
type, and vehicle type (for the eight MOBILE5b vehicle types) level of detail. The emission factors for
the PART5 pollutants (PM-10, PM-2.5, and SO2) did not vary by month, so the same emission factors
were multiplied by the monthly VMT at the county, roadway type, and vehicle type (for the 12 PART5
vehicle types) level of detail. Ammonia emission factors varied only by vehicle type, so the eight emission
factors by vehicle type were multiplied by VMT representing the same vehicle type at the monthly,
county, and roadway type level of detail. Emissions for all pollutants were calculated by multiplying the
appropriate emission factor in grams per mile by the corresponding VMT in millions of miles, and then
converting the answer to units of tons of emissions.
Emission factors were not calculated separately for each county. To determine the emission factor
sets to be modeled in each State, a county-level database was prepared for each year modeled. For each
county, the control programs applicable in that year were indicated. The data base also included
information on non-default inputs to be modeled, such as registration distributions and other State-
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-198 On-road Vehicles
-------
supplied data from OTAG, for each county. Next, for each State, all unique combinations of control
programs and other non-default inputs were determined for each modeled year. MOBILESb model runs
were then made modeling each of these unique combinations. Each combination was identified using the
county code of one of the counties with this combination of controls and inputs. To apply the emission
factors to the appropriate counties, a county correspondence file was developed which mapped all
counties with the same unique set of input data and control programs to the MOBILESb emission factors
modeled for the county representing that unique combination of inputs and control programs. In some
States, a single set of emission factors was applied to all counties in the State, while in other States, a
separate set of emission factors was calculated for each county. Most States, however, fell in between
these two extremes with several sets of emission factors calculated for the State, with each set applying
to one or more counties within the State. A similar process was followed in mapping the PARTS
emission factors to the appropriate counties.
4.6.6 References
1. "Highway Performance Monitoring System Field Manual," Federal Highway Administration, U.S.
Department of Transportation, Washington, DC, December 1987.
2. "Traffic Monitoring Guide," Federal Highway Administration, U.S. Department of Transportation,
Washington, DC, June 1985.
3. "1980 Census of Population, Volume I Characteristics of Population, Chapter B Number of
Inhabitants," Bureau of the Census, U.S. Department of Commerce, Washington, DC, April 1983.
4. Highway Statistics 1985. Federal Highway Administration, U.S. Department of Transportation,
Washington, DC, 1986.
5. Letter from Mark Wolcott, Technical Support Branch, Office of Mobile Sources, U.S.
Environmental Protection Agency, to E.H. Pechan & Associates, Inc., dated January 5, 1994
6. "Traffic Volume Trends Table 5A and Traffic Volume Trends 5B," ASCII text files received by E.H.
Pechan & Associates, Inc. from Mr. Kenneth Welty of the Federal Highway Administration,
Washington, DC, March 1994.
7. "The 1985 NAPAP Emissions Inventory: Development of Temporal Allocation Factors," EPA-
600/7-89-0lOd, Air & Energy Engineering Research Laboratory, U.S. Environmental Protection
Agency, Research Triangle Park, NC, April 1990.
8. "User's Guide to MOBILES (Mobile Source Emission Factor Model)," U.S. Environmental
Protection Agency, EPA-AA-AQAB-94-01, Office of Mobile Sources, Ann Arbor, MI, May 1994.
9. National Climatic Center, data files to E.H. Pechan & Associates, Inc., Asheville, NC, 1994.
10. "National Data Book and Guide to Sources, Statistical Abstract of the United States - 1993," U.S.
Department of Commerce, Bureau of the Census, Washington, DC. 1994.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-199 On-road Vehicles
-------
11. "Facts and Figures 1996," American Automobile Manufacturers Association, Washington, DC,
1996.
12. "1988 Annual Book of ASTM Standards," American Society for Testing and Materials, (Section 5:
Petroleum Products, Lubricants, and Fossil Fuels; Volume 05.01: Petroleum Products and
Lubricants (I): D 56 - D 1947), Philadelphia, PA, 1988.
13. "User's Guide to MOBILE4 (Mobile Source Emission Factor Model)," EPA-AA-TEB-89-01, U.S.
Environmental Protection Agency, Office of Mobile Sources, Ann Arbor, MI, February 1989.
14. Table provided by Greg Janssen, Office of Mobile Sources, U.S. Environmental Protection Agency,
to E.H. Pechan & Associates, Inc., May 11, 1996.
15. "1996 Market Data Book," Automotive News, 1996: Automotive News, Detroit, MI, 1996.
16. "Study of Vehicle Scrappage Rates," Miaou, Shaw-Pin, ORNL, Oak Ridge National Laboratories,
Oak Ridge, TN, August 1990.
17. "Major Modeling Elements for Operating I/M Programs," table provided by Joseph Somers, Office
of Mobile Sources, U.S. Environmental Protection Agency, Ann Arbor, MI, to E.H. Pechan &
Associates, Inc., July 10, 1997.
18. "State Winter Oxygenated Fuel Programs," table provided by Joseph Somers, Office of Mobile
Sources, U.S. Environmental Protection Agency, Ann Arbor, MI, to E.H. Pechan & Associates,
Inc., February 25, 1997.
19. "Draft Regulatory Impact Analysis: NMHC+NOX Emission Standards for 2004 and Later Model
Year On-Highway Heavy Duty Engines," Office of Mobile Sources, U.S. Environmental Protection
Agency, Ann Arbor, MI, January 26, 1996.
20. "Draft User's Guide to PART 5: A Program For Calculating Particle Emissions From Motor
Vehicles," EPA-AA-AQAB-94-2, U.S. Environmental Protection Agency, Office of Mobile
Sources, Ann Arbor, MI, July 1994.
21. 1987 Census of Transportation: Truck Inventory and Use Survey - United States, TC87-T-52, U.S.
Department of Commerce, Bureau of the Census, August 1990.
22. E.H. Pechan & Associates, Inc., "Regional Particulates Inventory for the National Particulate Matter
Study," prepared for U.S. Environmental Protection Agency, Office of Policy, Planning and
Evaluation/Office of Policy Analysis, June 1994.
23. "Air Toxics Emissions from Motor Vehicles," U.S. Environmental Protection Agency, Office of
Mobile Sources, EPA-AA-TSS-PA-86-5, Ann Arbor, MI, September 1987.
24. "Motor Vehicle-Related Air Toxics Study," U.S. Environmental Protection Agency, Office of
Mobile Sources, Public Review Draft, Ann Arbor, MI, December 1992.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-200 On-road Vehicles
-------
25. "Regulatory Impact Analysis: Control of Sulfur and Aromatics Contents of On-Highway Diesel
Fuel," U.S. Environmental Protection Agency, Office of Mobile Sources, 1990.
26. Compilation of Air Pollutant Emission Factors, AP-42, U. S. Environmental Protection Agency,
1975.
27. "MOBILE4.1 Fuel Consumption Model (Draft)," U.S. Environmental Protection Agency, Office of
Mobile Sources, Ann Arbor, MI, August 1991.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-201 On-road Vehicles
-------
Table 4.6-1. Data Components of HPMS
Universe - All Road Mileage
Identification
System
Jurisdiction
Operation
Other
Contains state, county, and rural/small urbanized codes and a unique
identification of location reference.
Optionally, the latitude and longitude coordinates for the beginning and
ending points of universe and sample sections are provided.
Provides for coding of functional system and federal-aid system.
Provides for coding of state or local highway system and special funding
category.
Includes type of facility, truck prohibition, and toll.
Contains length of highway section and fields for the coding of AADT
and the number of through lanes.
Identification
Computational
Elements
Pavement Attributes
Improvements
Geometries/
Configuration
Traffic/Capacity
Environment
Supplemental Data
Contains unique identification for the sample section portion of the
record.
Provides data items used to expand sample information to universe
values.
Contains data items used to evaluate the physical characteristics of
pavement, pavement performance, and the need for pavement overlays.
Describes the improvement type for the year of the improvement
completion.
Describes the physical attributes used to evaluate the capacity and
operating characteristics of the facility.
Provides operational data items used to calculate the capacity of a
section and the need for improvements.
Contains items that marginally affect the operation of a facility but are
important to its structural integrity.
Provides linkage to existing structure and railroad crossing information
systems.
Mileage
Travel
Accidents
Injuries
Population
Road mileage
Vehicle miles traveled, percent travel by vehicle type
Number of accidents
Number of injuries
Area population
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-202
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-2. Apportionment Percentages for Conversion of HPMS Vehicle Type
Categories to MOBILESa Categories
HPMS Vehicle Type Category MOBILESa Vehicle Type Category and Apportionment Percentages
Motorcycle
Passenger Car
Other 2-Axle, 4-tire
Buses
Other Single Unit Trucks
Combination Trucks
MC
LDGV
LDDV
LDGT1
LDGT2
LDDT
HDGV
HDDV
HDGV
HDDV
HDDV
1.0000
0.9864
0.0136
0.6571
0.3347
0.0082
0.1028
0.8972
0.7994
0.2006
1.0000
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-203
1985-1996 Methodology
On-road Vehicles
-------
Vehicle Type
LDV, LOT, MC
LDV, LOT, MC
HDV
Vehicle Type
LDV, LOT, MC
LDV, LOT, MC
HDV
Table 4.6-3. VMT Seasonal and Monthly Temporal Allocation Factors
Roadway Seasonal VMT Factors
Type Winter Spring Summer Fall
Rural 0.2160 0.2390 0.2890 0.2560
Urban 0.2340 0.2550 0.2650 0.2450
All 0.2500 0.2500 0.2500 0.2500
Roadway Monthly VMT Factors: Non-Leap Years--1 995, 1 999, 2002, 2005, 2007, 201 0
Type Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov
Rural 0.0744 0.0672 0.0805 0.0779 0.0805 0.0942 0.0974 0.0974 0.0844 0.0872 0.0844
Urban 0.0806 0.0728 0.0859 0.0832 0.0859 0.0864 0.0893 0.0893 0.0808 0.0835 0.0808
All 0.0861 0.0778 0.0842 0.0815 0.0842 0.0815 0.0842 0.0842 0.0824 0.0852 0.0824
Dec
0.0744
0.0806
0.0861
Vehicle Type
LDV, LOT, MC
LDV, LOT, MC
HDV
Roadway Monthly VMT Factors: Leap Years--1996, 2000, 2008
Type Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov
Rural 0.0736 0.0688 0.0805 0.0779 0.0805 0.0942 0.0974 0.0974 0.0844 0.0872 0.0844
Urban 0.0797 0.0746 0.0859 0.0832 0.0859 0.0864 0.0893 0.0893 0.0808 0.0835 0.0808
All 0.0852 0.0797 0.0842 0.0815 0.0842 0.0815 0.0842 0.0842 0.0824 0.0852 0.0824
Dec
0.0736
0.0797
0.0852
-------
Table 4.6-4. 1995 to 1996 VMT Growth Factors by State and Roadway Type
State
Alabama
Alabama
Alabama
Alabama
Alabama
Alabama
Alaska
Alaska
Alaska
Alaska
Alaska
Alaska
Arizona
Arizona
Arizona
Arizona
Arizona
Arizona
Arkansas
Arkansas
Arkansas
Arkansas
Arkansas
Arkansas
California
California
California
California
California
California
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
DC
DC
DC
DC
Rural Roadway Type
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
Growth
Factor
1.021
0.986
1.005
1.035
0.999
1.005
0.993
0.991
1.026
1.022
1.001
1.007
1.023
0.981
1.006
1.011
1.017
1.013
1.033
1.028
1.011
1.009
0.970
1.012
1.041
1.009
1.028
1.028
1.028
1.028
1.034
1.010
1.025
0.977
1.020
1.013
1.029
1.026
1.014
0.986
1.016
1.016
NA
NA
NA
NA
Urban Roadway Type
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
Growth
Factor
1.000
1.006
0.999
0.989
0.983
1.005
1.018
NA
1.010
0.993
1.046
1.008
1.013
1.031
1.015
1.014
1.015
1.015
1.009
1.031
1.005
1.024
1.028
1.017
1.023
1.033
1.028
1.028
1.028
1.028
1.032
1.063
1.006
1.015
1.001
1.003
1.012
1.001
1.036
1.015
1.016
1.016
1.041
0.956
0.969
0.983
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-205
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
DC
DC
Delaware
Delaware
Delaware
Delaware
Delaware
Delaware
Florida
Florida
Florida
Florida
Florida
Florida
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Hawaii
Hawaii
Hawaii
Hawaii
Hawaii
Hawaii
Idaho
Idaho
Idaho
Idaho
Idaho
Idaho
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Indiana
Indiana
Indiana
Indiana
Indiana
Indiana
Iowa
Iowa
Iowa
Rural Roadway Type
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
Growth
Factor
NA
NA
NA
1.015
1.001
1.007
1.036
1.011
1.041
1.010
1.030
1.009
1.031
1.028
1.041
1.044
1.047
1.029
1.010
1.057
NA
0.971
1.018
0.980
0.984
0.981
1.022
0.999
1.015
1.025
1.012
1.013
1.021
1.042
1.014
0.997
1.018
1.019
1.001
1.004
1.006
0.998
1.001
1.001
1.020
1.024
1.009
Urban Roadway Type
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
Growth
Factor
0.985
0.987
1.013
1.066
1.017
1.004
0.975
1.011
1.043
1.028
1.029
1.016
1.051
1.031
1.050
1.061
1.014
1.048
1.017
1.011
0.980
0.935
0.974
0.979
0.979
0.979
1.041
NA
1.005
0.997
0.988
1.014
1.020
1.018
1.005
1.032
1.019
1.019
1.010
1.037
0.991
0.988
1.009
1.001
1.041
NA
1.015
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-206
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Iowa
Iowa
Iowa
Kansas
Kansas
Kansas
Kansas
Kansas
Kansas
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Louisiana
Louisiana
Louisiana
Louisiana
Louisiana
Louisiana
Maine
Maine
Maine
Maine
Maine
Maine
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Michigan
Michigan
Michigan
Michigan
Michigan
Michigan
Minnesota
Minnesota
Rural Roadway Type
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
Growth
Factor
1.009
1.036
0.913
1.034
1.023
1.009
0.988
1.012
1.011
1.030
1.012
1.005
1.013
1.018
1.015
1.043
1.050
1.033
1.014
1.046
1.022
1.035
1.017
1.011
1.012
1.028
1.034
1.015
1.018
1.007
1.021
1.061
1.016
1.028
1.012
0.992
1.015
1.013
1.014
1.013
1.013
1.015
1.014
1.001
1.001
1.012
1.022
Urban Roadway Type
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
Growth
Factor
0.991
1.090
1.001
1.041
1.091
0.996
0.991
0.947
0.956
1.016
0.991
1.025
1.006
0.992
1.009
1.023
1.029
1.013
1.043
1.007
1.029
1.039
0.998
1.000
1.000
1.062
1.021
1.016
1.021
1.009
1.016
0.998
1.016
1.015
1.020
1.022
1.000
1.015
1.014
1.010
1.001
0.965
1.021
1.001
0.960
1.025
1.010
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-207
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Minnesota
Minnesota
Minnesota
Minnesota
Mississippi
Mississippi
Mississippi
Mississippi
Mississippi
Mississippi
Missouri
Missouri
Missouri
Missouri
Missouri
Missouri
Montana
Montana
Montana
Montana
Montana
Montana
Nebraska
Nebraska
Nebraska
Nebraska
Nebraska
Nebraska
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
New Hampshire
New Hampshire
New Hampshire
New Hampshire
New Hampshire
New Hampshire
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Mexico
Rural Roadway Type
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
Growth
Factor
1.016
1.002
1.015
0.988
1.042
1.044
0.999
0.983
1.018
1.021
1.042
1.029
1.004
1.022
1.016
1.016
0.981
0.998
0.997
1.013
1.000
1.044
1.042
0.998
1.040
0.958
0.969
1.022
1.022
0.981
1.071
1.076
1.014
1.014
1.031
1.027
0.997
0.994
1.021
1.018
1.076
1.004
0.962
0.985
1.010
1.001
1.031
Urban Roadway Type
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
Growth
Factor
1.013
1.014
1.026
1.018
1.034
1.149
1.005
1.008
1.018
1.019
1.011
1.026
0.987
1.017
1.019
1.017
1.010
NA
0.984
1.000
0.886
1.000
1.053
1.020
1.028
1.027
1.051
1.022
1.034
1.081
0.983
0.981
1.013
1.013
1.028
1.059
1.011
1.031
1.021
1.021
1.008
1.008
1.003
0.970
1.002
1.001
1.044
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-208
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
New York
New York
New York
New York
New York
New York
North Carolina
North Carolina
North Carolina
North Carolina
North Carolina
North Carolina
North Dakota
North Dakota
North Dakota
North Dakota
North Dakota
North Dakota
Ohio
Ohio
Ohio
Ohio
Ohio
Ohio
Oklahoma
Oklahoma
Oklahoma
Oklahoma
Oklahoma
Oklahoma
Oregon
Oregon
Oregon
Oregon
Oregon
Oregon
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Rural Roadway Type
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
Growth
Factor
0.988
1.006
0.994
1.040
1.014
1.019
1.020
1.004
0.977
1.013
1.012
1.043
1.031
1.011
1.039
1.015
1.040
1.016
1.007
0.996
0.977
NA
1.017
1.043
1.017
1.032
1.044
0.985
1.010
1.047
1.044
1.044
1.023
1.050
1.024
0.997
0.995
1.017
0.988
1.011
1.010
1.021
1.007
1.012
1.018
1.077
1.010
Urban Roadway Type
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
Growth
Factor
0.694
1.002
1.023
1.014
1.014
1.018
1.015
1.011
1.011
1.010
1.011
1.037
1.033
1.004
1.026
1.038
1.025
1.001
NA
1.062
1.013
1.010
1.010
1.029
1.034
1.018
0.979
0.976
1.019
1.018
1.029
1.016
1.045
0.996
1.016
1.028
1.037
1.039
0.998
1.010
1.010
1.011
0.998
0.991
1.015
0.987
1.010
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-209
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Rhode Island
Rhode Island
Rhode Island
Rhode Island
Rhode Island
Rhode Island
South Carolina
South Carolina
South Carolina
South Carolina
South Carolina
South Carolina
South Dakota
South Dakota
South Dakota
South Dakota
South Dakota
South Dakota
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Texas
Texas
Texas
Texas
Texas
Texas
Utah
Utah
Utah
Utah
Utah
Utah
Vermont
Vermont
Vermont
Vermont
Vermont
Vermont
Virginia
Virginia
Virginia
Virginia
Virginia
Rural Roadway Type
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
Growth
Factor
1.021
1.018
1.047
1.051
1.013
1.026
1.036
1.057
1.038
1.058
1.042
1.042
1.035
1.019
1.005
0.970
0.954
1.009
1.043
1.021
0.984
1.049
0.893
1.017
1.042
1.052
1.044
1.030
1.059
1.030
1.041
1.035
1.032
0.994
1.029
1.030
1.024
1.008
1.009
1.006
1.012
1.012
1.006
1.004
0.988
1.000
0.993
Urban Roadway Type
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
Growth
Factor
1.037
1.002
0.985
0.999
1.013
1.014
1.041
1.037
1.034
1.025
1.041
1.042
1.020
1.024
1.004
1.004
0.937
1.010
1.012
1.017
1.015
1.017
1.061
1.017
1.023
1.016
1.013
1.045
1.007
1.031
1.028
1.019
1.010
1.041
1.029
1.029
1.022
1.008
1.025
1.005
1.013
1.012
1.000
0.994
1.004
0.999
1.006
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-210
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Virginia
Washington
Washington
Washington
Washington
Washington
Washington
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
Wisconsin
Wisconsin
Wisconsin
Wisconsin
Wisconsin
Wisconsin
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Wyoming
Rural Roadway Type
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
INTERSTATE
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
MAJOR COLLECTOR
MINOR COLLECTOR
LOCAL
Growth
Factor
0.998
1.000
1.000
0.984
0.980
1.008
1.008
1.024
1.011
1.013
1.024
1.031
1.009
1.012
1.030
1.035
1.015
1.029
1.028
1.018
1.011
1.014
1.006
1.048
1.015
Urban Roadway Type
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
Growth
Factor
1.002
1.017
1.013
1.024
1.008
1.008
1.008
1.018
1.005
1.006
0.999
0.986
1.013
1.047
1.018
1.020
1.042
1.028
1.027
1.032
0.968
1.003
0.999
0.976
1.008
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-211
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-5. State-level Daily VMT Totals in the OTAG Inventory
STATF
Alabama
Arkansas
Connecticut
Delaware
District of Columbia
Florida
Georgia
Illinois
Indiana
Iowa
Kansas
Kentucky
Louisiana
Maine
Maryland
Massachusetts
Michigan
Minnesota
Mississippi
Missouri
Nebraska
New Hampshire
New Jersey
New York
North Carolina
North Dakota
Ohio
Oklahoma
Pennsylvania
Rhode Island
South Carolina
South Dakota
Tennessee
Texas
Vermont
Virginia
West Virginia
Wisconsin
TOTAL
1990 VMT
WMT/SIIMMFR DAY!
130,293,139
64,893,375
80,795,439
21,688,232
9,512,227
301 ,401 ,066
215,733,554
254,405,708
146,238,700
70,914,717
70,274,093
103,468,764
85,036,022
36,687,471
124,790,087
128,906,395
244,651,250
119,486,368
75,306,141
144,836,950
42,949,068
30,337,965
177,882,767
327,206,333
159,748,582
18,241,880
249,268,477
101,777,917
262,877,528
22,482,474
106,001,636
21,648,546
143,924,247
456,338,143
18,055,581
184,879,090
47,716,623
116,510,029
4,917,166,586
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-212
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-6. Cities Used for Temperature Data Modeling from 1970 through 1996
State
Alabama
Alaska
Arizona
Arkansas
California
California
Colorado
Connecticut
Delaware
District of Columbia
Florida
Georgia
Hawaii
Idaho
Illinois
Indiana
Iowa
Kansas
Kentucky
Louisiana
Maine
Maryland
Massachusetts
Michigan
Minnesota
Mississippi
Missouri
Montana
Nebraska
Nevada
New Hampshire
New Jersey
New Mexico
New York
North Carolina
North Dakota
Ohio
Oklahoma
Oregon
Pennsylvania
Rhode Island
South Carolina
South Dakota
Tennessee
Texas
Utah
Vermont
Virginia
Washington
West Virginia
Wisconsin
Wyoming
City
Birmingham
Anchorage
Phoenix
Little Rock
Los Angeles
San Francisco
Denver
Hartford
Dover
Washington
Orlando (1974-1 993)
Atlanta
Honolulu
Boise
Springfield
Indianapolis
Des Moines
Topeka
Louisville
Baton Rouge
Portland
Baltimore
Boston
Detroit
Minneapolis
Jackson
Springfield
Billings
Lincoln
Las Vegas
Concord
Newark
Albuquerque
New York City
Greensboro
Bismarck
Columbus
Oklahoma City
Eugene
Harrisburg (1970-1 991),
Middletown (1991 -1993)
Providence
Columbia
Pierre
Nashville
Dallas/Fort Worth (1974-1993)
Salt Lake City
Montpelier
Richmond
Seattle
Charleston
Milwaukee
Casper
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-213
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-7. Surrogate City Assignment
Nonattainment Area/MSA
Albany-Schenectady-Troy, NY MSA
Albuquerque, NM MSA
Allentown-Bethlehem, PA-NJ MSA
Altoona, PA MSA
Anchorage, AK MSA
Anderson, SC MSA
Appleton-Oshkosh-Neenah, Wl MSA
Atlanta
Atlantic City, NJ MSA
Bakersfield, CA MSA
Baltimore, MD MSA
Baton Rouge
Beaumont-Port Arthur, TX MSA
Bennington Co., VT
Birmingham, AL MSA
Boston Metropolitan Area
Boston Metropolitan Area
Bowling Green, KY
Buffalo-Niagara Falls, NY CMSA
Canton, OH MSA
Charleston, WV MSA
Charlotte-Gastonia-Rock Hill, NC-SC MSA
Chattanooga, TN-GA MSA
Cherokee Co., SC
Chester Co., SC
Chicago-Gary-Lake County, IL-IN-WI CMSA
Chico, CA MSA
Cincinnati-Hamilton, OH-KY-IN CMSA
Cleveland Metropolitan Area
Clinton Co., OH
Colorado Springs, CO MSA
Columbia, SC MSA
Columbus, OH MSA
Dallas-Ft. Worth, TX CMSA
Dayton-Springfield, OH MSA
Denver-Boulder, CO CMSA
Detroit-Ann Arbor, Ml CMSA
Door Co., Wl
Duluth, MN-WI MSA
Edmonson Co., KY
El Paso, TX MSA
Erie, PA MSA
Essex Co., NY
Evansville, IN-KY MSA
Fairbanks, AK
Fayetteville, NC MSA
Flint, Ml MSA
State
NY
NM
PA-NJ
PA
AK
SC
Wl
GA
NJ
CA
MD
LA
TX
VT
AL
MA
MA-NH
KY
NY
OH
WV
NC
GA-TN
SC
SC
IL-IN-WI
CA
OH-KY-IN
OH
OH
CO
SC
OH
TX
OH
CO
Ml
Wl
MN
KY
TX
PA
NY
IN-KY
AK
NC
Ml
Survey City
New York City
Albuquerque
Philadelphia
Philadelphia
Cleveland
Atlanta
Chicago
Atlanta
Philadelphia
San Francisco
Washington, DC
New Orleans
Dallas
Boston
Atlanta
Boston
Boston
Chicago
New York City
Cleveland
Washington, DC
Atlanta
Atlanta
Atlanta
Atlanta
Chicago
San Francisco
Cleveland
Cleveland
Cleveland
Denver
Atlanta
Cleveland
Dallas
Cleveland
Denver
Detroit
Chicago
Minneapolis
Chicago
Albuquerque
Cleveland
New York City
Chicago
Cleveland
Atlanta
Detroit
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-214
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-7 (continued)
Nonattainment Area/MSA
Fort Collins-Loveland, CO MSA
Fresno, CA MSA
Glens Falls, NY MSA
Grand Rapids, Ml MSA
Great Falls, MT MSA
Greater Connecticut Metropolitan Area
Greeley, CO MSA
GreenbrierCo., WV
Greensboro-Winston-Salem-High Point PMSA
Greenville-Spartanburg, SC MSA
Hancock Co., ME
Harrisburg-Lebanon-Carlisle, PA MSA
Hartford-New Britain-Middletown, CT
Houston-Galveston-Brazoria, TX CMSA
Huntington-Ashland, WV-KY-OH MSA
Huntsville, AL MSA
Indianapolis, IN MSA
Jacksonville, FL MSA
Janesville-Beloit, Wl MSA
Jefferson Co., NY
Jersey Co., IL
Johnson City-Kingsport-Bristol, TN-VA MSA
Johnstown, PA MSA
Josephine Co., OR
Kansas City, MO-KS MSA
Kent and Queen Anne's Cos., MD
Kewaunee Co., Wl
Kings Co., CA
Klamath Co., OR
Knox Co., ME
Knoxville, TN MSA
Lafayette-West Lafayette, IN MSA
Lake Charles, LA MSA
Lake Tahoe South Shore, CA
Lancaster, PA MSA
Las Vegas, NV MSA
Lawrence Co., PA
Lewiston, ME
Lexington-Fayette, KY MSA
Lincoln Co., ME
Livingston Co., KY
Longmont, CO
Longview-Marshall, TX MSA
Los Angeles-Anaheim-Riverside, CA CMSA
Los Angeles-South Coast Air Basin, CA
Louisville, KY-IN MSA
Manchester, NH MSA
State
CO
CA
NY
Ml
MT
CT
CO
WV
NC
SC
ME
PA
CT
TX
WV-KY-OH
AL
IN
FL
Wl
NY
IL
TN
PA
OR
MO
MD
Wl
CA
OR
ME
TN
IN
LA
CA
PA
NV
PA
ME
KY
ME
KY
CO
TX
CA
CA
KY-IN
NH
Survey City
Denver
San Francisco
New York City
Chicago
Billings
Boston
Denver
Washington, DC
Atlanta
Atlanta
Boston
Philadelphia
Boston
Dallas
Washington, DC
Chicago
Chicago
Miami
Chicago
Philadelphia
Chicago
Atlanta
Philadelphia
Seattle
Kansas City
Philadelphia
Chicago
San Francisco
San Francisco
Boston
Atlanta
Chicago
New Orleans
San Francisco
Philadelphia
Las Vegas
Cleveland
Boston
Chicago
Boston
St. Louis
Denver
Dallas
Los Angeles
Los Angeles
Chicago
Boston
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-215
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-7 (continued)
Nonattainment Area/MSA
Manitowoc Co., Wl
Medford, OR MSA
Memphis, TN-AR-MS MSA
Miami-Fort Lauderdale, FL CMSA
Milwaukee Metropolitan Area
Minneapolis-St. Paul, MN-WI MSA
Missoula, MT
Mobile, AL MSA
Modesto, CA MSA
Montgomery, AL MSA
Muskegon, Ml MSA
Nashville, TN MSA
New Orleans, LA MSA
New York-Northern New Jersey-Long Island CMSA
Norfolk-Virginia Beach-Newport News, VA MSA
Northampton Co., VA
Oklahoma City, OK MSA
Owensboro, KY MSA
Paducah, KY
Parkersburg, WV
Parkersburg-Marietta, WV-OH MSA
Philadelphia Metropolitan Area
Phoenix, AZ MSA
Pittsburgh-Beaver Valley, PA CMSA
Portland, ME
Portland-Vancouver, OR-WA CMSA
Portsmouth-Dover-Rochester, NH-ME MSA
Poughkeepsie, NY MSA
Providence-Pawtucket-Fall River, RI-MA CMSA
Provo-Orem, UT MSA
Raleigh-Durham, NC MSA
Reading, PA MSA
Reno, NV MSA
Richmond-Petersburg
Rochester, NY MSA
Sacramento, CA MSA
Salt Lake City-Ogden, UT MSA
San Antonio, TX MSA
San Diego, CA MSA
San Francisco-Oakland-San Jose, CA CMSA
San Joaquin Valley, CA
Santa Barbara-Santa Maria-Lompoc, CA MSA
Scranton-Wilkes-Barre, PA MSA
Seattle-Tacoma, WA
Sheboygan, Wl MSA
Smyth Co., VA
South Bend-Elkhart, IN
State
Wl
OR
TN-AR-MS
FL
Wl
MN-WI
MT
AL
CA
AL
Ml
TN
LA
NY-NJ-CT
VA
VA
OK
KY
KY
WV
OH-WV
PA-NJ-DE-MD
AZ
PA
ME
OR-WA
ME-NH
NY
MA-RI
UT
NC
PA
NV
VA
NY
CA
UT
TX
CA
CA
CA
CA
PA
WA
Wl
VA
IN
Survey City
Chicago
San Francisco
St. Louis
Miami
Chicago
Minneapolis
Billings
New Orleans
San Francisco
Atlanta
Chicago
Atlanta
New Orleans
New York City
Washington, DC
Washington, DC
Dallas
Atlanta
Chicago
Cleveland
Cleveland
Philadelphia
Phoenix
Philadelphia
Boston
Seattle
Boston
New York City
Boston
Denver
Atlanta
Philadelphia
San Francisco
Washington, DC
Philadelphia
San Francisco
Denver
San Antonio
Los Angeles
San Francisco
San Francisco
Los Angeles
Philadelphia
Seattle
Chicago
Washington, DC
Chicago
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-216
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-7 (continued)
Nonattainment Area/MSA
State
Survey City
South Bend-Mishawaka, IN MSA
Southeast Desert Modified AQMA, CA
Spokane, WA MSA
Springfield, MA MSA
St. Louis, MO-IL MSA
Steubenville-Weirton, OH-WV MSA
Stockton, CA MSA
Sussex Co., DE
Syracuse, NY MSA
Tampa-St. Petersburg-Clearwater, MSA
Toledo, OH MSA
Tulsa, OK MSA
Ventura Co., CA
Visalia-Tulare-Porterville, CA MSA
Waldo Co., ME
Walworth Co., Wl
Washington, DC-MD-VA MSA
Wheeling, WV-OH MSA
Winnebago Co., Wl
Winston-Salem, NC
Worcester, MA MSA
Yakima, WA MSA
York, PA MSA
Youngstown-Warren, OH MSA
Yuba City, CA MSA
IN
CA
WA
MA
MO-IL
OH-WV
CA
DE
NY
FL
OH
OK
CA
CA
ME
Wl
DC-MD-VA
WV-OH
Wl
NC
MA
WA
PA
OH
CA
Chicago
Los Angeles
Seattle
Boston
St. Louis
Cleveland
San Francisco
Philadelphia
New York City
Miami
Detroit
Kansas City
Los Angeles
San Francisco
Boston
Chicago
Washington, DC
Cleveland
Chicago
Atlanta
Boston
Seattle
Philadelphia
Cleveland
San Francisco
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-217
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-8. Substitute Survey City Assignment
Nonattainment Area/MSA
Albany-Schenectady-Troy, NY MSA
Allentown-Bethlehem, PA-NJ MSA
Altoona, PA MSA
Appleton-Oshkosh-Neenah, Wl MSA
Beaumont-Port Arthur, TX MSA
Bennington Co., VT
Bowling Green, KY
Buffalo-Niagara Falls, NY CMSA
Charleston, WV MSA
Door Co., Wl
Edmonson Co., KY
Essex Co., NY
Evansville, IN-KY MSA
Glens Falls, NY MSA
Grand Rapids, Ml MSA
GreenbrierCo., WV
Harrisburg-Lebanon-Carlisle, PA MSA
State
NY
PA-NJ
PA
Wl
TX
VT
KY
NY
WV
Wl
KY
NY
IN-KY
NY
Ml
WV
PA
Huntington-Ashland, WV-KY-OH MSAWV-KY-OH
Huntsville, AL MSA
Indianapolis, IN MSA
Jefferson Co., NY
Jersey Co., IL
Johnstown, PA MSA
Kewaunee Co., Wl
Lafayette-West Lafayette, IN MSA
Lancaster, PA MSA
Longview-Marshall, TX MSA
Louisville, KY-IN MSA
Manitowoc Co., Wl
Muskegon, Ml MSA
Northampton Co., VA
Oklahoma City, OK MSA
Paducah, KY
Pittsburgh-Beaver Valley, PA CMSA
Reading, PA MSA
Rochester, NY MSA
Sheboygan, Wl MSA
Smyth Co., VA
South Bend-Elkhart, IN
South Bend-Mishawaka, IN MSA
Syracuse, NY MSA
Waldo Co., ME
Walworth Co., Wl
York, PA MSA
AL
IN
NY
IL
PA
Wl
IN
PA
TX
KY-IN
Wl
Ml
VA
OK
KY
PA
PA
NY
Wl
VA
IN
IN
NY
ME
Wl
PA
Original Survey City
New York City
Philadelphia
Philadelphia
Chicago
Dallas
Boston
Chicago
New York City
Washington, DC
Chicago
Chicago
New York City
Chicago
New York City
Chicago
Washington, DC
Philadelphia
Washington, DC
Chicago
Chicago
Philadelphia
Chicago
Philadelphia
Chicago
Chicago
Philadelphia
Dallas
Chicago
Chicago
Chicago
Washington, DC
Dallas
Chicago
Philadelphia
Philadelphia
Philadelphia
Chicago
Washington, DC
Chicago
Chicago
New York City
Boston
Chicago
Philadelphia
New Survey City
Cleveland
Cleveland
Cleveland
Minneapolis
New Orleans
Minneapolis
Cleveland
Cleveland
Cleveland
Minneapolis
Cleveland
Cleveland
Cleveland
Cleveland
Detroit
Cleveland
Cleveland
Cleveland
Atlanta
Cleveland
Cleveland
Cleveland
Cleveland
Minneapolis
Cleveland
Cleveland
New Orleans
Cleveland
Minneapolis
Detroit
Atlanta
St. Louis
Cleveland
Cleveland
Cleveland
Cleveland
Minneapolis
Atlanta
Cleveland
Cleveland
Cleveland
Minneapolis
Minneapolis
Cleveland
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-218
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-9. Monthly RVP Values Modeled in 1995
State
AL
AK
AZ
AR
CA
CA
CO
CT
DE
DC
FL
GA
HI
ID
IL
IL
IN
IA
KS
KY
KY
LA
ME
MD
MA
Ml
Ml
MN
MN
MS
MO
MO
MT
NE
NV
NH
NJ
NM
NY
NC
ND
Applicable
Counties
Entire State
Entire State
Entire State
Entire State
Los Angeles Region
San Francisco Region
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Madison, Monroe, St. Clair
Rest of State
Entire State
Entire State
Entire State
Boone, Campbell, Kenton
Rest of State
Entire State
Entire State
Entire State
Entire State
Macomb, Oakland, Wayne
Rest of State
Anoka, Carver, Dakota, Hennepin,
Ramsey, Scott, Washington, Wright
Rest of State
Entire State
Franklin, Jefferson, St. Charles, St.
Louis, St. Louis City
Rest of State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
1995 Monthly RVP (psi)
Jan
12.1
14.1
8.7
13.8
11.5
11.3
13.4
12.4
12.3
12.9
11.7
12.0
10.0
14.1
13.9
13.9
14.3
15.0
13.2
14.0
14.0
12.4
12.5
12.6
12.1
14.0
14.0
15.0
15.0
13.8
13.5
13.5
13.6
14.1
10.7
12.1
13.0
11.3
14.1
12.0
15.0
Feb Mar
12.1 9.3
14.1 14.1
7.9 7.2
13.8 10.0
11.5 11.5
11.3 11.3
12.4 11.1
12.4 10.5
12.3 10.5
10.5 10.5
11.7 7.5
12.0 9.2
10.0 10.0
12.5 12.5
13.9 11.5
13.9 11.5
14.3 12.2
15.0 13.4
11.5 9.3
11.8 11.8
11.8 11.8
12.4 9.7
12.5 10.6
12.6 10.5
12.1 10.3
14.0 11.8
14.0 11.8
15.0 12.6
15.0 12.6
13.8 10.0
11.7 11.7
11.7 11.7
13.6 12.1
14.1 12.5
9.4 8.4
12.1 10.3
13.0 11.1
11.3 10.0
14.1 12.0
12.0 12.0
15.0 13.4
Apr
9.3
14.1
7.2
10.0
9.2
11.3
11.1
10.5
10.5
7.2
7.5
9.2
10.0
10.3
11.5
11.5
12.2
11.2
9.3
8.9
8.9
9.7
10.6
10.5
10.3
11.8
11.8
12.6
12.6
10.0
9.2
9.2
10.1
10.3
8.4
10.3
11.1
9.0
12.0
9.2
13.4
May
7.8
13.0
6.8
7.1
7.5
9.0
9.0
8.6
8.5
7.5
7.4
7.6
10.0
8.7
7.1
8.4
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.7
8.9
9.3
9.0
7.1
7.1
7.3
8.6
8.4
7.8
8.6
8.6
8.4
8.7
7.6
9.0
Jun
7.8
13.0
6.8
7.1
7.5
7.5
7.8
8.6
8.5
7.5
7.4
7.6
10.0
8.7
7.1
8.4
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.7
8.9
9.3
9.0
7.1
7.1
7.3
8.6
8.4
7.8
8.6
8.6
7.8
8.7
7.6
9.0
Jul
7.8
13.0
6.8
7.1
7.5
7.5
7.8
8.6
8.5
7.5
7.4
7.6
9.5
8.7
7.1
8.4
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.7
8.9
9.3
9.0
7.1
7.1
7.3
8.6
8.4
7.8
8.6
8.6
7.8
8.7
7.6
9.0
Aug
7.8
13.0
6.8
7.1
7.5
7.5
7.8
8.6
8.5
7.5
7.4
7.6
10.0
8.7
7.1
8.4
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.7
8.9
9.3
9.0
7.1
7.1
7.3
8.6
8.4
7.8
8.6
8.6
7.8
8.7
7.6
9.0
Sep
7.8
13.0
6.8
7.1
7.5
7.5
7.8
8.6
8.5
7.5
7.4
7.6
10.0
8.7
7.1
8.4
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.7
8.9
9.3
9.0
7.1
7.1
7.3
8.6
8.4
7.8
8.6
8.6
7.8
8.7
7.6
9.0
Oct
9.3
14.1
6.8
10.0
7.4
7.4
10.1
10.5
8.1
7.2
7.5
9.2
10.0
8.7
8.2
8.2
9.3
11.2
7.6
8.9
8.9
9.7
10.6
7.7
10.3
11.8
11.8
9.5
9.5
10.0
9.2
9.2
10.1
8.6
7.8
10.3
11.1
9.0
12.0
9.2
11.2
Nov Dec
9.3 12.1
14.1 14.1
7.2 7.9
13.8 13.8
9.2 11.5
9.1 11.3
11.1 12.4
10.5 12.4
10.5 12.3
10.5 12.9
7.5 11.7
9.2 12.0
10.0 10.0
10.3 12.5
11.5 13.9
11.5 13.9
12.2 14.3
13.4 15.0
9.3 11.5
11.8 14.0
11.8 14.0
9.7 12.4
10.6 12.5
10.5 12.6
10.3 12.1
11.8 14.0
11.8 14.0
12.6 15.0
12.6 15.0
10.0 13.8
11.7 11.7
11.7 11.7
12.1 13.6
10.3 12.5
8.4 9.4
10.3 12.1
11.1 13.0
10.0 11.3
12.0 14.1
12.0 12.0
13.4 15.0
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-219
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-9 (continued)
State
OH
OH
OK
OR
PA
PA
Rl
SC
SD
TN
TX
TX
TX
UT
VT
VA
WA
WV
Wl
WY
Applicable
Counties
Butler, Cuyahoga, Hamilton, Lake,
Lorain
Rest of State
Entire State
Entire State
Clarion, Crawford, Elk, Erie, Forest,
Jefferson, Lawrence, McKean, Mercer,
Venango, Warren
Rest of State
Entire State
Entire State
Entire State
Entire State
El Paso
Hardin, Harris, Jefferson, Orange
Rest of State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
1995 Monthly RVP (psi)
Jan
14.4
14.4
13.5
13.2
14.1
14.1
12.1
12.0
15.0
12.4
11.6
11.6
11.6
13.4
15.0
12.5
14.5
14.4
14.5
13.5
Feb Mar
14.4 12.3
14.4 12.3
13.5 10.0
11.0 11.0
14.1 12.0
14.1 12.0
12.1 10.3
12.0 12.0
15.0 13.4
12.4 12.4
11.6 9.4
11.6 9.4
11.6 9.4
12.4 12.4
15.0 12.6
10.2 10.2
14.5 12.0
14.4 12.3
14.5 12.1
13.5 12.2
Apr
12.3
12.3
10.0
11.0
12.0
12.0
10.3
9.2
11.2
9.4
9.4
9.4
9.4
11.1
12.6
7.2
12.0
12.3
12.1
10.4
May
9.3
9.0
7.4
8.1
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
9.0
8.6
7.5
8.7
8.5
9.0
9.0
Jun
9.3
9.0
7.4
7.8
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
7.8
8.6
7.5
8.7
8.5
9.0
9.0
Jul
9.3
9.0
7.4
7.8
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
7.8
8.6
7.5
8.7
8.5
9.0
9.0
Aug
9.3
9.0
7.4
7.8
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
7.8
8.6
7.5
8.7
8.5
9.0
9.0
Sep
9.3
9.0
7.4
7.8
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
7.8
8.6
7.5
8.7
8.5
9.0
9.0
Oct
9.4
9.4
7.4
8.1
12.0
12.0
10.3
9.2
9.5
9.4
7.8
7.8
7.8
10.1
12.6
7.2
8.7
9.5
9.0
9.0
Nov Dec
12.3 14.4
12.3 14.4
10.0 13.5
11.0 13.2
12.0 14.1
12.0 14.1
10.3 12.1
12.0 12.0
11.2 13.4
12.4 12.4
9.4 11.6
9.4 11.6
9.4 11.6
11.1 12.4
12.6 15.0
10.2 12.5
12.0 14.5
12.3 14.4
12.1 14.5
10.4 12.2
Note: May through September RVP values modeled for areas receiving reformulated gasoline are set within
MOBILE5b and are not reflected here.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-220 On-road Vehicles
-------
Table 4.6-10. Monthly RVP Values Modeled in 1996
State
AL
AK
AZ
AR
CA
CA
CO
CT
DE
DC
FL
GA
HI
ID
IL
IL
IN
IA
KS
KY
KY
LA
ME
MD
MA
Ml
MN
MN
MS
MO
MO
MT
NE
NV
NH
NJ
NM
NY
NC
ND
OH
Applicable
Counties
Entire State
Entire State
Entire State
Entire State
Los Angeles Region
San Francisco Region
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Madison, Monroe, St. Clair
Rest of State
Entire State
Entire State
Entire State
Boone, Campbell, Kenton
Rest of State
Entire State
Entire State
Entire State
Entire State
Entire State
Anoka, Carver, Dakota, Hennepin,
Ramsey, Scott, Washington, Wright
Rest of State
Entire State
Franklin, Jefferson, St. Charles, St.
Louis, St. Louis City
Rest of State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Butler, Cuyahoga, Hamilton, Lake,
Lorain
1996 Monthly RVP (psi)
Jan
12.4
14.1
8.7
13.7
11.9
11.7
13.2
13.0
13.5
12.8
11.8
12.4
10.0
13.9
14.1
14.1
14.5
14.9
14.0
14.2
14.2
12.4
13.2
13.2
12.9
14.1
14.9
14.9
13.7
13.9
13.9
13.8
14.5
10.5
12.9
13.7
11.7
14.3
12.4
14.9
14.6
Feb Mar
12.4 9.5
14.1 14.1
7.9 7.2
13.7 9.8
11.9 11.9
11.7 11.7
12.1 10.7
13.0 10.8
13.5 11.1
10.3 10.3
11.8 7.4
12.4 9.4
10.0 10.0
12.3 12.3
14.1 11.4
14 1 114
14.5 12.0
14.9 13.3
12.1 9.5
11.7 11.7
11.7 11.7
12.4 9.6
13.2 11.0
13.2 10.8
12.9 10.7
14.1 11.2
14.9 12.6
14.9 12.6
13.7 9.8
11.9 11.9
11.9 11.9
13.8 12.3
14.5 12.7
9.2 8.2
12.9 10.7
13.7 11.3
11.7 10.2
14.3 11.9
12.4 12.4
14.9 13.3
14.6 12.1
Apr
9.5
14.1
7.2
9.8
9.0
11.7
10.7
10.8
11.1
7.0
7.4
9.4
10.0
10.2
11.4
11 4
12.0
11.2
9.5
8.4
8.4
9.6
11.0
10.8
10.7
11.2
12.6
12.6
9.8
9.2
9.2
10.2
10.4
8.2
10.7
11.3
9.1
11.9
9.4
13.3
12.1
May
7.8
13.0
6.8
7.1
6.9
9.0
9.0
8.6
8.5
7.5
7.4
7.6
10.0
8.6
7.1
84
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.9
9.3
9.0
7.1
7.1
7.3
8.7
8.4
7.6
8.6
8.6
8.4
8.7
7.6
9.0
9.3
Jun
7.8
13.0
6.8
7.1
6.9
6.9
7.8
8.6
8.5
7.5
7.4
7.6
10.0
8.6
7.1
84
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.9
9.3
9.0
7.1
7.1
7.3
8.7
8.4
7.6
8.6
8.6
7.8
8.7
7.6
9.0
9.3
Jul
7.8
13.0
6.8
7.1
6.9
6.9
7.8
8.6
8.5
7.5
7.4
7.6
9.5
8.6
7.1
84
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.9
9.3
9.0
7.1
7.1
7.3
8.7
8.4
7.6
8.6
8.6
7.8
8.7
7.6
9.0
9.3
Aug
7.8
13.0
6.8
7.1
6.9
6.9
7.8
8.6
8.5
7.5
7.4
7.6
10.0
8.6
7.1
84
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.9
9.3
9.0
7.1
7.1
7.3
8.7
8.4
7.6
8.6
8.6
7.8
8.7
7.6
9.0
9.3
Sep
7.8
13.0
6.8
7.1
6.9
6.9
7.8
8.6
8.5
7.5
7.4
7.6
10.0
8.6
7.1
84
9.0
9.0
7.4
9.3
8.6
7.3
8.6
7.8
8.6
8.9
9.3
9.0
7.1
7.1
7.3
8.7
8.4
7.6
8.6
8.6
7.8
8.7
7.6
9.0
9.3
Oct
9.5
14.1
6.8
9.8
6.9
7.0
9.6
10.8
7.9
7.0
7.4
9.4
10.0
8.6
7.8
78
8.7
11.2
7.6
8.4
8.4
9.6
11.0
7.5
10.7
11.2
9.6
9.6
9.8
9.2
9.2
10.2
8.6
7.6
10.7
11.3
9.1
11.9
9.4
11.2
8.7
Nov Dec
9.5 12.4
14.1 14.1
7.2 7.9
13.7 13.7
9.0 11.9
9.0 11.7
10.7 12.1
10.8 13.0
11.1 13.5
10.3 12.8
7.4 11.8
9.4 12.4
10.0 10.0
10.2 12.3
11.4 14.1
114 14 1
12.0 14.5
13.3 14.9
9.5 12.1
11.7 14.2
11.7 14.2
9.6 12.4
11.0 13.2
10.8 13.2
10.7 12.9
11.2 14.1
12.6 14.9
12.6 14.9
9.8 13.7
11.9 11.9
11.9 11.9
12.3 13.8
10.4 12.7
8.2 9.2
10.7 12.9
11.3 13.7
10.2 11.7
11.9 14.3
12.4 12.4
13.3 14.9
12.1 14.6
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-221
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-10 (continued)
State
OH
OK
OR
PA
PA
Rl
SC
SD
TN
TX
TX
TX
UT
VT
VA
WA
WV
Wl
WY
Applicable
Counties
Rest of State
Entire State
Entire State
Clarion, Crawford, Elk, Erie, Forest,
Jefferson, Lawrence, McKean, Mercer,
Venango, Warren
Rest of State
Entire State
Entire State
Entire State
Entire State
El Paso
Hardin, Harris, Jefferson, Orange
Rest of State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
1996 Monthly RVP (psi)
Jan
14.6
13.9
13.1
14.4
14.4
12.9
12.4
14.9
12.7
12.2
12.2
12.2
13.2
14.9
12.6
14.0
14.6
14.6
13.5
Feb Mar
14.6 12.1
13.9 10.1
10.8 10.8
14.4 12.0
14.4 12.0
12.9 10.7
12.4 12.4
14.9 13.3
12.7 12.7
12.2 10.0
122 100
12.2 10.0
12.1 12.1
14.9 12.6
10.2 10.2
14.0 11.6
14.6 12.1
14.6 12.2
13.5 12.1
Apr
12.1
10.1
10.8
12.0
12.0
10.7
9.4
11.2
9.5
10.0
100
10.0
10.7
12.6
7.1
11.6
12.1
12.2
10.2
May
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
74
7.7
9.0
9.0
7.5
8.5
8.8
9.0
8.8
Jun
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
74
7.7
7.8
9.0
7.5
8.5
8.8
9.0
8.8
Jul
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
74
7.7
7.8
9.0
7.5
8.5
8.8
9.0
8.8
Aug
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
74
7.7
7.8
9.0
7.5
8.5
8.8
9.0
8.8
Sep
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
74
7.7
7.8
9.0
7.5
8.5
8.8
9.0
8.8
Oct
8.7
7.2
7.7
12.0
12.0
10.7
9.4
9.6
9.5
8.3
83
8.3
9.6
12.6
7.1
8.5
8.8
9.0
8.8
Nov Dec
12.1 14.6
10.1 13.9
10.8 13.1
12.0 14.4
12.0 14.4
10.7 12.9
12.4 12.4
11.2 13.3
12.7 12.7
10.0 12.2
100 122
10.0 12.2
10.7 12.1
12.6 14.9
10.2 12.6
11.6 14.0
12.1 14.6
12.2 14.6
10.2 12.1
Note: May through September RVP values modeled for areas receiving reformulated gasoline are set within
MOBILE5b and are not reflected here.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-222 On-road Vehicles
-------
Table 4.6-11. HPMS Average Overall Travel Speeds for 1990
(MPH)
Rural
Urban
Vehicle Type
Small Pass. Cars
Large Pass. Cars
Pickups & Vans
Single 2 Axle
Single 3+ Axle
Multi 4+ Axle
Multi 5+ Axle
Principal
Interstate Arterial
58.4 46.5
58.4 46.5
56.7 45.6
55.7 44.5
53.3 43.0
43.0 34.0
41.8 33.4
Minor
Arterial
40.1
40.1
39.7
38.8
37.6
30.7
30.2
Major
Collector
35.4
35.4
35.3
32.6
33.1
27.9
26.9
Minor
Collector
30.3
30.3
30.5
24.1
29.8
25.7
22.5
Other
Freeways
Interstate Expressways
46.3 42.4
46.3 42.4
45.4 41.9
47.1 42.9
45.4 41.5
37.2 34.4
36.4 33.8
Principal
Arterial
18.7
18.7
19.5
18.1
18.0
14.7
14.6
Minor
Arterial
19.3
19.3
20.1
18.2
18.1
14.6
14.5
Collecto
r
19.5
19.5
20.3
18.0
18.1
14.5
14.3
-------
Table 4.6-12. Average Speeds by Road Type and Vehicle Type
(MPH)
Rural
Principal Minor Major Minor
Interstate Arterial Arterial Collector Collector Local
LDV
LOT
HDV
60
55
40
45
45
35
40
40
30
35
35
25
30
30
25
30
30
25
Urban
Other Freeways Principal Minor
Interstate & Expressways Arterial Arterial Collector Local
LDV
LOT
HDV
45
45
35
45
45
35
20
20
15
20
20
15
20
20
15
20
20
15
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-224 On-road Vehicles
-------
Table 4.6-13. State-Supplied Operating Mode Inputs
State
County
Percent of VMT Accumulated by:
Non-catalyst
Vehicles in
Cold Start Mode
Catalyst Equipped
Vehicles in
Hot Start Mode
Catalyst Equipped
Vehicles in
Cold Start Mode
Texas Brazoria Co
Chambers Co
Fort Bend Co
Galveston Co
Harris Co
Liberty Co
Montgomery Co
Waller Co
16.0
14.3
23.3
Texas
Collin Co
Dallas Co
Denton Co
Tarrant Co
16.5
14.6
24.9
Maryland
Allegany Co
Anne Arundel Co
Baltimore Co
Caroline Co
Carroll Co
Cecil Co
Dorchester Co
Garrett Co
Harford Co
Howard Co
Kent Co
Queen Annes Co
St. Mary's Co
Somerset Co
Talbot Co
Washington Co
Wicomico Co
Worcester Co
Baltimore
22.3
14.6
22.3
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-225
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-14. I/M Program Documentation (1995 and 1996)
I/M Program Name
I/M Proqram Parameters
Program Start Year
Stringency Level (Percent)
Model Years Covered
Waiver Rate For Pre-1981 Model Years (%)
Waiver Rate For 1981 and Later Models (%)
Compliance Rate (%)
Program Type
Inspection Frequency
Vehicle Types Inspected
LDGV
LDGT1
LDGT2
HDGV
Test Type
I/M Cutpoints
Effectiveness Rates (% HC/CO/NOx)
I/M Proqram Parameters
Program Start Year
Stringency Level (Percent)
Model Years Covered
Waiver Rate For Pre-1981 Model Years (%)
Waiver Rate For 1981 and Later Models (%)
Compliance Rate (%)
Program Type
Inspection Frequency
Vehicle Types Inspected
LDGV
LDGT1
LDGT2
HDGV
Test Type
I/M Cutpoints
Effectiveness Rates (% HC/CO/NOx)
Anti-Tamperinq Proqram Parameters
Program Start Year
Model Years Covered
Vehicle Types Inspected
LDGV
LDGT1
LDGT2
HDGV
Program Type
Effectiveness Rate
Inspection Frequency
Compliance Rate (%)
Inspections Performed
Air Pump System
AK1IMATP
1986
20
1968-2020
15
15
95
TRC
Biennial
YES
YES
YES
NO
2500/ldle Test
220/1 .2/999
0.85/0.85/0.85
0.85/0.85/0.85
1986
1968-2020
YES
YES
YES
NO
TRC
0.85
Biennial
95
YES
AKIMATP
1986
20
1975-2020
15
15
95
TRC
Biennial
YES
YES
YES
NO
2500/ldle Test
220/1 .2/999
0.85/0.85/0.85
0.85/0.85/0.85
1986
1975-2020
YES
YES
YES
NO
TRC
0.85
Biennial
95
YES
AZPIMATP
1978
20
1967-1980
3
3
96
TO
Annual
YES
YES
YES
YES
Idle Test
220/1 .2/999
1.00/1.00/1.00
1978
20
1981-2020
3
3
96
TO
Biennial
YES
YES
YES
YES
Transient Test
1.20/20.0/3.00
1.00/1.00/1.00
1988
1984-2020
YES
YES
YES
YES
TO
1.00
Biennial
96
YES
AZTIMATP
1978
31
1967-2020
8
8
96
TO
Biennial
YES
YES
YES
YES
Idle Test
220/1 .2/999
1.00/1.00/1.00
1.00/1.00/1.00
1988
1967-2020
YES
YES
YES
YES
TO
1.00
Biennial
96
YES
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-226
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-14 (continued)
I/M Program Name
Catalyst
Fuel Inlet Restrictor
Tailpipe Lead Deposit Test
EGR System
Evaporative Emission Control System
PCV System
Gas Cap
AK1IMATP
YES
NO
NO
YES
YES
YES
YES
AKIMATP AZPIMATP AZTIMATP
YES
NO
NO
YES
YES
YES
YES
YES
NO
NO
NO
YES
YES
YES
YES
NO
NO
NO
NO
NO
NO
Functional Pressure Test Program Parameters
Program Start Year 1995 1995
Model Years Covered 1983-2020 1967-2020
Effectiveness Rate 1.00 0.40
Vehicle Types Tested
LDGV YES YES
LDGT1 YES YES
LDGT2 YES YES
HDGV YES YES
Program Type TO TRC
Inspection Frequency Biennial Biennial
Compliance Rate (%) 96 96
Purge Test Program Parameters
Program Start Year 1995
Model Years Covered 1986-2020
Effectiveness Rate 1.00
Vehicle Types Tested
LDGV YES
LDGT1 YES
LDGT2 YES
HDGV YES
Program Type TO
Inspection Frequency Biennial
Compliance Rate (%) 96
Years of Program Usage 95,96 95,96 95,96 95,96
Notes:
TO=Test Only
TRC=TestAnd Repair (Computerized)
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-227 On-road Vehicles
-------
Table 4.6-15. Counties Included in 1995 and 1996 I/M Programs
I/M Program Name Included Counties
AK1IMATP Anchorage Ed
AKIMATP Fairbanks Ed
AZPIMATP Maricopa Co
AZTIMATP Pima Co
CAIMATP Fresno Co, Kern Co, Los Angeles Co, Napa Co, Sacramento Co, San Diego Co,
San Francisco Co
CODIMATP Adams Co, Arapahoe Co, Boulder Co, Denver Co, Douglas Co, Jefferson Co
COSIMATP El Paso Co, Larimer Co, Teller Co, Weld Co,
CTIMATP Fairfield Co, Hartford Co, Litchfield Co, Middlesex Co, New Haven Co,
New London Co, Tolland Co, Windham Co
DCIMATP Washington
DEIMATP1 Kent Co, Sussex Co
DEIMATP2 New Castle Co
FLIMATP Broward Co, Dade Co, Duval Co, Hillsborough Co, Palm Beach Co, Pinellas Co
GAIM95 Cobb Co, De Kalb Co, Fulton Co, Gwinnett Co
GAIM96 Cobb Co, De Kalb Co, Fulton Co, Gwinnett Co
IDIMATP Ada Co
ILIM95 Cook Co, Du Page Co, Lake Co, Madison Co, St. Clair Co
ILIM952 Grundy Co, Kane Co, Kendall Co, McHenry Co, Will Co
INIMATP Clark Co, Floyd Co, Lake Co, Porter Co
KYIMATP1 Boone Co, Campbell Co, Kenton Co
KYIMATP2 Jefferson Co
LAIMATP Ascension Par, Calcasieu Par, East Baton Rouge Par, Iberville Par, Livingston Par,
Pointe Coupee Par, West Baton Rouge Par
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-228
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-15 (continued)
I/M Program Name Included Counties
MAIM95
MDIM95
M DIM ATP
MIIM95
MNIMATP
MOIMATP1
MOIMATP2
NCIM931
NCIM932
NCIMATP3
NHIM95
NJIMATP
NMIMATP
NVIMATP
NYIMATP2
NYIMATP3
OHIM96
OHIMATP1
OHIMATP2
Barnstable Co, Berkshire Co, Bristol Co, Dukes Co, Essex Co, Franklin Co,
Hampden Co, Hampshire Co, Middlesex Co, Nantucket Co, Norfolk Co, Plymouth Co,
Suffolk Co, Worcester Co
Calvert Co, Cecil Co, Charles Co, Frederick Co, Queen Annes Co, Washington Co
Anne Arundel Co, Baltimore, Baltimore Co, Carroll Co, Harford Co, Howard Co,
Montgomery Co, Prince Georges Co
Macomb Co, Oakland Co, Wayne Co
Anoka Co, Carver Co, Dakota Co, Hennepin Co, Ramsey Co, Scott Co, Washington Co,
Wright Co
Jefferson Co, St. Charles Co, St. Louis, St. Louis Co
Franklin Co
Wake Co
Mecklenburg Co
Davidson Co, Davie Co, Durham Co, Forsyth Co, Gaston Co, Granville Co, Guilford Co
Hillsborough Co, Rockingham Co
Atlantic Co, Bergen Co, Burlington Co, Camden Co, Cape May Co, Cumberland Co,
Essex Co, Gloucester Co, Hudson Co, Hunterdon Co, Mercer Co, Middlesex Co,
Monmouth Co, Morris Co, Ocean Co, Passaic Co, Salem Co, Somerset Co, Sussex Co,
Union Co, Warren Co
Bernalillo Co
Clark Co, Washoe Co
Albany Co, Allegany Co, Broome Co, Cattaraugus Co, Cayuga Co, Chautauqua Co,
Chemung Co, Chenango Co, Clinton Co, Columbia Co, Cortland Co, Delaware Co,
Dutchess Co, Erie Co, Essex Co, Franklin Co, Fulton Co, Genesee Co, Greene Co,
Hamilton Co, Herkimer Co, Jefferson Co, Lewis Co, Livingston Co, Madison Co,
Monroe Co, Montgomery Co, Niagara Co, Oneida Co, Onondaga Co, Ontario Co,
Orange Co, Orleans Co, Oswego Co, Otsego Co, Putnam Co, Rensselaer Co,
Saratoga Co, Schenectady Co, Schoharie Co, Schuyler Co, Seneca Co, St. Lawrence Co,
Steuben Co, Sullivan Co, Tioga Co, Tompkins Co, Ulster Co, Warren Co,
Washington Co, Wayne Co, Wyoming Co, Yates Co
Bronx Co, Kings Co, Nassau Co, New York Co, Queens Co, Richmond Co,
Rockland Co, Suffolk Co, Westchester Co
Butler Co, Cuyahoga Co, Hamilton Co, Lake Co, Lorain Co
Butler Co, Hamilton Co, Lake Co, Lorain Co
Cuyahoga Co
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-229
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-15 (continued)
I/M Program Name Included Counties
OKIMATP1
OKIMATP2
ORIMATP
PAIMATP
RIIMATP
TNIM951
TNIM952
TXIMATP2
TXIMATP3
TXIMATP4
UT1IMATP
UT2IMATP
UT3IMATP
UT4IMATP
VAIM95
WAIMATP
WIIM93
WIIM96
WIIMSHEB
Creek Co, Osage Co, Rogers Co, Tulsa Co, Wagoner Co
Canadian Co, Cleveland Co, Kingfisher Co, Lincoln Co, Logan Co, McClain Co,
Oklahoma Co, Pottawatomie Co
Clackamas Co, Jackson Co, Multnomah Co, Washington Co
Allegheny Co, Beaver Co, Bucks Co, Chester Co, Delaware Co, Lehigh Co,
Montgomery Co, Northampton Co, Philadelphia Co, Washington Co, Westmoreland Co
Bristol Co, Kent Co, Newport Co, Providence Co, Washington Co
Davidson Co
Shelby Co
Harris Co
Collin Co, Denton Co, Ellis Co, Johnson Co, Kaufman Co, Parker Co, Rockwall Co
Dallas Co, Tarrant Co
Utah Co
Weber Co
Davis Co
Salt Lake Co
Alexandria, Arlington Co, Fairfax, Fairfax Co, Falls Church, Manassas, Manassas Park,
Prince William Co
King Co, Snohomish Co, Spokane Co
Kenosha Co, Milwaukee Co, Ozaukee Co, Racine Co, Washington Co, Waukesha Co
Kenosha Co, Milwaukee Co, Ozaukee Co, Racine Co, Sheboygan Co, Washington Co,
Waukesha Co
Shebovgan Co
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-230
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-16. Oxygenated Fuel Modeling Parameters
State
Alaska
Arizona
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Colorado
Connecticut
Minnesota
Minnesota
Minnesota
Minnesota
Minnesota
Minnesota
Minnesota
Minnesota
Minnesota
Minnesota
Montana
Nevada
Nevada
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New York
New York
New York
New York
New York
New York
New York
New York
New York
New York
New York
Oregon
Oregon
Oregon
Oregon
Oregon
Oregon
Oregon
Texas
Utah
Washington
Washington
Wisconsin
County
Anchorage Ed
Maricopa Co
Adams Co
Arapahoe Co
Boulder Co
Douglas Co
Jefferson Co
Denver Co
El Paso Co
Larimer Co
Fairfield Co
Anoka Co
Carver Co
Dakota Co
Hennepin Co
Ramsey Co
Scott Co
Washington Co
Wright Co
Chisago Co
Isanti Co
Missoula Co
Clark Co
Washoe Co
Bergen Co
Essex Co
Hudson Co
Hunterdon Co
Middlesex Co
Monmouth Co
Morris Co
Ocean Co
Passaic Co
Somerset Co
Sussex Co
Union Co
Bronx Co
Kings Co
Nassau Co
New York Co
Queens Co
Richmond Co
Rockland Co
Suffolk Co
Westchester Co
Orange Co
Putnam Co
Clackamas Co
Jackson Co
Multnomah Co
Washington Co
Josephine Co
Klamath Co
Yamhill Co
El Paso Co
Utah Co
Clark Co
Spokane Co
St. Croix Co
Market Shares (%)
MTBE Alcohol Blends
0
80
75
75
75
75
75
75
75
75
90
10
10
10
10
10
10
10
10
10
10
0
0
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
95
1
1
1
1
1
1
1
15
20
1
1
10
100
20
25
25
25
25
25
25
25
25
10
90
90
90
90
90
90
90
90
90
90
100
100
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
99
99
99
99
99
99
99
85
80
99
99
90
Oxygen Content (%)
MTBE Alcohol Blends
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.7
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
Oxygenated
Fuel Season
NOV-FEB
OCT-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
OCT - JAN
OCT - JAN
OCT - JAN
OCT - JAN
OCT - JAN
OCT - JAN
OCT - JAN
OCT - JAN
OCT - JAN
OCT - JAN
NOV-FEB
OCT - MAR
OCT - JAN
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
NOV-FEB
SEP-FEB
OCT - JAN
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-231
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-17. State-Supplied Trip Length Distribution Inputs
State
Georgia
Illinois
Illinois
Indiana
Michigan
Missouri
Wisconsin
Wisconsin
Nonattainment
Area
Washington, DC/MD/VA
Baltimore
Houston
Dallas
Table 4.6-1 8
Applicable Area
Entire State
Percentage of Total VMT Accumulated in Trips of:
< 10 1 1 to 20 21 to 30 31 to 40 41 to 50 > 50
Minutes Minutes Minutes Minutes Minutes Minutes
16.6 33.9 23.4 13.3 6.1 6.7
15.1 31.7 26 13.3 6.5 7.4
14.8 27.9 22.4 14.3 8.5 12.1
9.8 19 23.8 19.4 13.6 14.4
. State-Supplied Alcohol Fuels Data
Ether Alcohol Oxygen Oxygen
Blends Blends Content of Content of
Market Market Ether Alcohol
Share (%) Share (%) Blends (%) Blends (%)
0.0 2.5 3.5
Chicago Nonattainment Area 17.0 83.0 2.1 3.5
Rest of State
Entire State excluding RFC
Entire State
Entire State
0.0 33.0 3.5
Counties 0.0 19.0 3.5
0.0 12.7 3.5
0.0 33.0 3.5
Milwaukee Nonattainment Area 17.0 83.0 2.1 3.5
Rest of State excluding St.
Croix County 0.0 10.0 3.5
1.0 psi
RVP
Waiver
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-232
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6.19. State-Provided Diesel Sales Inputs
Delaware-Kent County
.000.000.000.000.000.000.000.000.000.000.000.000.001.032.001.015.004.015.001.009
.002.005.000.008.003.005.002.004.004.009.010.007.011.015.020.017.033.020.004.003
.001.000.002.003.001.002.002.000.006.000
Delaware-New Castle County
.000.000.000.000.000.000.000.000.000.000.000.000.001.011.002.010.002.009.001.009
.001.003.000.006.001.004.001.005.003.005.004.005.008.009.014.014.019.014.000.000
.001.000.000.000.000.000.000.000.000.000
Delaware-Sussex County
.000.050.000.050.000.050.000.050.000.050.000.050.001.022.002.010.005.008.001.010
.001.005.000.008.003.003.002.005.005.010.007.010.009.011.019.022.020.036.014.002
.000.000.000.000.000.000.000.000.000.000
Maryland-Baltimore, Carroll, Harford, and Howard Counties, and Baltimore City
.000.001.000.001.000.001.000.001.000.001.000.001.001.007.000.006.003.007.004.012
.014.015.018.024.021.027.040.074.055.055.048.028.023.012.011.005.008.001.010.001
.014.001.007.001.003.000.004.000.001.001
Maryland-Calvert County
.001.002.001.002.001.002.001.002.001.002.001.002.000.005.000.004.002.003.003.016
.019.032.020.051.027.042.025.145.041.122.031.106.015.019.009.000.004.000.005.000
.005.038.000.000.000.000.000.000.000.000
Maryland-Charles County
.000.003.000.003.000.003.000.003.000.003.000.003.000.003.000.005.003.010.002.009
.007.007.008.030.006.031.017.085.020.055.013.051.006.011.004.000.000.000.000.000
.006.000.003.000.003.000.000.000.004.048
Maryland-Frederick County
.000.005.000.005.000.005.000.005.000.005.000.005.001.003.000.002.001.006.004.011
.008.020.009.032.005.046.014.082.022.142.021.057.007.016.005.009.003.000.005.000
.003.000.002.000.000.000.000.000.000.023
Maryland-Montgomery County
.001.004.001.004.001.004.001.004.001.004.001.004.001.009.000.008.006.009.006.026
.019.027.026.053.033.059.052.207.065.174.056.130.044.022.021.019.018.006.023.006
.022.006.011.000.003.006.003.000.002.000
Maryland-Prince Georges County
.001.010.001.010.001.010.001.010.001.010.001.010.001.019.000.013.005.019.005.033
.013.044.018.064.022.076.038.195.050.146.039.108.019.025.012.021.006.005.005.018
.010.008.006.000.001.005.003.000.001.000
Virginia-Alexandria City
.001.000.001.000.001.000.001.000.001.000.001.000.001.000.000.000.003.002.005.005
.014.017.019.029.022.067.041.193.046.172.038.010.019.009.011.000.007.000.009.024
.009.017.006.000.001.000.002.000.004.019
Virginia-Arlington County
.000.006.000.006.000.006.000.006.000.006.000.006.001.002.000.001.002.007.004.014
.013.017.021.057.020.068.038.221.049.248.032.070.023.013.015.007.009.000.010.000
.010.000.004.009.002.000.005.013.006.000
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-233 On-road Vehicles
-------
Table 4.6-19 (continued)
Virginia-Fairfax County and Fairfax City
.001.002.001.002.001.002.001.002.001.002.001.002.001.005.000.002.003.006.005.013
.015.014.022.032.028.041.048.124.062.154.054.035.030.011.015.005.009.002.013.006
.017.000.007.000.005.000.004.000.005.008
Virginia-Prince William County
.001.003.001.003.001.003.001.003.001.003.001.003.001.003.000.003.001.005.005.011
.011.014.019.029.022.048.046.114.062.154.043.021.020.020.010.003.004.004.004.000
.010.000.004.009.001.000.003.000.003.007
Virginia-Loudoun County
.002.003.002.003.002.003.002.003.002.003.002.003.002.001.001.001.004.006.007.010
.013.024.023.029.029.033.049.101.066.134.043.033.027.009.012.009.006.006.008.007
.010.070.008.000.006.009.002.000.003.000
Virginia-Stafford County
.003.002.003.002.003.002.003.002.003.002.003.002.002.003.000.000.002.003.007.008
.016.007.022.032.030.045.060.155.063.080.045.018.017.005.005.004.005.005.004.000
.005.000.004.014.001.000.006.000.002.000
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-234 On-road Vehicles
-------
Table 4.6-20. Counties Modeled with Federal Reformulated Gasoline
State (ASTM Class)/
Nonattainment Area County
State (ASTM Class)/
Nonattainment Area County
Arizona (B)
Phoenix
Maricopa Co
Connecticut ©
Greater Connecticut
Hartford Co
Litchfield Co
Middlesex Co
New Haven Co
New London Co
Tolland Co
Windham Co
New York-Northern New Jersey-Long Island
Fairfield Co
District of Columbia (B)
Washington DC
Washington
Delaware ©
Philadelphia-Wilmington-Trenton
Kent Co
New Castle Co
Sussex County
Sussex Co
Illinois ©
Chicago-Gary-Lake County
Cook Co
Du Page Co
Grundy Co
Kane Co
Kendall Co
Lake Co
McHenry Co
Will Co
Indiana©
Chicago-Gary-Lake County
Lake Co
Porter Co
Kentucky ©
Cincinnati-Hamilton
Boone Co
Campbell Co
Kenton Co
Maine©
Knox & Lincoln Counties
Knox Co
Lincoln Co
Lewiston-Auburn
Androscoggin Co
Kennebec Co
Portland
Cumberland Co
Sagadahoc Co
York Co
Maryland (B)
Baltimore
Anne Arundel Co
Baltimore
Baltimore Co
Carroll Co
Harford Co
Howard Co
Kent & Queen Annes Counties
Kent Co
Queen Annes Co
Philadelphia-Wilmington-Trenton
Cecil Co
Washington DC
Calvert Co
Charles Co
Frederick Co
Montgomery Co
Prince Georges Co
Massachusetts ©
Boston-Lawrence-Worcester-Eastern MA
Barnstable Co
Bristol Co
Dukes Co
Essex Co
Middlesex Co
Nantucket Co
Norfolk Co
Plymouth Co
Suffolk Co
Worcester Co
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-235
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-20 (continued)
State (ASTM Class)/
Nonattainment Area County
State (ASTM Class)/
Nonattainment Area County
Louisville
Bullitt Co
Jefferson Co
Oldham Co
New Hampshire ©
Manchester
Hillsborough Co
Merrimack Co
Portsmouth-Dover-Rochester
Rockingham Co
Strafford Co
New Jersey ©
Allentown-Bethlehem-Easton
Warren Co
Atlantic City
Atlantic Co
Cape May Co
New York-Northern New Jersey-Long Island
Bergen Co
Essex Co
Hudson Co
Hunterdon Co
Middlesex Co
Monmouth Co
Morris Co
Ocean Co
Passaic Co
Somerset Co
Sussex Co
Union Co
Philadelphia-Wilmington-Trenton
Burlington Co
Camden Co
Cumberland Co
Gloucester Co
Mercer Co
Salem Co
New York ©
New York-Northern New Jersey-Long Island
Bronx Co
Kings Co
Nassau Co
New York Co
Springfield/Pittsfield-Western MA
Berkshire Co
Franklin Co
Hampden Co
Hampshire Co
New York ©
Poughkeepsie
Dutchess Co
Putnam Co
Pennsylvania ©
Philadelphia-Wilmington-Trenton
Bucks Co
Chester Co
Delaware Co
Montgomery Co
Philadelphia Co
Rhode Island ©
Providence
Bristol Co
Kent Co
Newport Co
Providence Co
Washington Co
Texas(B)
Dallas-Fort Worth
Collin Co
Dallas Co
Denton Co
Tarrant Co
Houston-Galveston-Brazoria
Brazoria Co
Chambers Co
Fort Bend Co
Galveston Co
Harris Co
Liberty Co
Montgomery Co
Waller Co
Virginia (B)
Norfolk-Virginia Beach-Newport News
Chesapeake
Hampton
James City Co
Newport News
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-236
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-20 (continued)
State (ASTM Class)/
Nonattainment Area County
State (ASTM Class)/
Nonattainment Area County
Orange Co
Queens Co
Richmond Co
Rockland Co
Suffolk Co
Westchester Co
Norfolk
Poquoson
Portsmouth
Suffolk
Virginia Beach
Williamsburg
York Co
Virginia (B)
Richmond-Petersburg
Washington DC
Charles City Co
Chesterfield Co
Colonial Heights
Hanover Co
Henrico Co
Hopewell
Richmond
Alexandria
Arlington Co
Fairfax
Fairfax Co
Falls Church
Loudoun Co
Manassas
Manassas Park
Prince William Co
Stafford Co
Wisconsin ©
Milwaukee-Racine
Kenosha Co
Milwaukee Co
Ozaukee Co
Racine Co
Washington Co
Waukesha Co
Notes: Reformulated gasoline was only modeled in Phoenix beginning with the projection years, as the opt-in date for
Phoenix was 1997. California reformulated gasoline was modeled statewide in California.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-237
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-21 PARTS Vehicle Classes
Vehicle
LDGV
LDGT1
LDGT2
HDGV
MC
LDDV
LDDT
Class
light-duty gasoline vehicles
light-duty gasoline trucks, I
light-duty gasoline trucks, II
heavy-duty gasoline trucks
motorcycles
light-duty diesel vehicles
light-duty diesel trucks
2BHDDV class 2B heavy-duty diesel vehicles
LHDDV
MHDDV
HHDDV
BUSES
light heavy-duty diesel vehicles
medium heavy-duty diesel vehicles
heavy heavy-duty diesel vehicles
buses
FHWA
Class
1
2A
2B-8B
1
2A
2B
3,4,5
6,7,8A
8B
Gross Vehicle
Weiaht Ubs)
<6,000
6,001-8,500
>8,500
<6,000
6,001-8,500
8,501-10,000
10,001-19,500
19,501-33,000
33,000+
Table 4.6-22 Average Speeds by Road Type and Vehicle Type
Rural Road Speeds (mph)
Vehicle
Tvoe
LDV
LOT
HDV
Vehicle
Tvoe
LDV
LOT
HDV
Interstate
60
55
40
Interstate
45
45
35
Principal
Arterial
45
45
35
Urban
Other Freeways
& Exoresswavs
45
45
35
Minor
Arterial
40
40
30
Major
Collector
35
35
25
Minor
Collector
30
30
25
Local
30
30
25
Road Speeds (mph)
Principal
Arterial
20
20
15
Minor
Arterial
20
20
15
Collector
20
20
15
Local
20
20
15
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-238
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-23. PM-10 Emission Factors used in the Emission Trends Inventory
Emission Factor (grams per mile)
Year
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
LDGV
0.070
0.066
0.063
0.060
0.057
0.054
0.051
0.048
0.045
0.042
0.039
0.036
0.033
0.030
0.026
LDGT1 LDGT2
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
Table 4
069
066
063
060
057
054
051
049
046
043
040
037
034
032
029
0.070
0.067
0.064
0.062
0.059
0.057
0.054
0.052
0.049
0.047
0.044
0.042
0.039
0.037
0.034
HDGV
0.062
0.062
0.062
0.062
0.062
0.062
0.062
0.062
0.062
0.062
0.062
0.062
0.062
0.062
0.062
LDDV
0.615
0.615
0.615
0.615
0.615
0.615
0.615
0.585
0.555
0.525
0.495
0.465
0.435
0.405
0.375
LDDT
0.615
0.615
0.615
0.615
0.615
0.615
0.615
0.583
0.552
0.520
0.489
0.457
0.426
0.395
0.363
HDDV
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
367
367
367
367
351
335
319
303
287
271
255
239
223
207
191
MC
0.070
0.066
0.063
0.060
0.057
0.054
0.051
0.048
0.045
0.042
0.039
0.036
0.033
0.030
0.026
.6-24. Fuel Economy Values Used in Calculation of SO2
Emission
Factors
for the
Emission
Trends Inventory
Fuel Economy (miles/gallon)
Year
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
LDGV
12.68
12.70
12.57
12.48
12.59
12.68
12.69
12.94
13.17
13.52
14.50
14.95
15.49
16.13
16.78
LDGT
10.18
10.39
10.51
10.69
11.15
11.40
11.39
11.63
11.81
12.00
12.54
12.72
12.96
13.42
13.90
HDGV
6.79
6.85
6.86
6.90
7.11
7.16
7.05
7.05
6.97
6.94
7.13
7.07
7.65
7.96
8.15
LDDV
12.68
12.70
12.57
12.48
12.59
12.68
12.69
12.94
13.17
13.52
14.50
14.95
24.90
25.10
25.21
LDDT
10.18
10.39
10.51
10.69
11.15
11.40
11.39
11.63
11.81
12.00
12.54
12.72
24.59
24.85
24.96
HDDV
5.05
5.17
5.27
5.32
5.47
5.62
5.47
5.47
5.45
5.45
5.64
5.56
5.30
5.44
5.57
MC
50.00
50.00
50.00
50.00
50.00
50.00
50.00
50.00
50.00
50.00
50.00
50.00
50.00
50.00
50.00
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-239
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-25. SO2 Emission Factors used in the Emission Trends Inventory
Emission Factor (grams per mile)
Year
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
LDGV
0.147
0.146
0.148
0.149
0.148
0.147
0.147
0.144
0.141
0.138
0.128
0.124
0.120
0.115
0.111
LDGT1
0.183
0.179
0.177
0.174
0.167
0.163
0.163
0.160
0.158
0.155
0.148
0.146
0.144
0.139
0.134
LDGT2
0.183
0.179
0.177
0.174
0.167
0.163
0.163
0.160
0.158
0.155
0.148
0.146
0.144
0.139
0.134
HDGV
0.274
0.272
0.271
0.270
0.262
0.260
0.264
0.264
0.267
0.268
0.261
0.263
0.243
0.234
0.228
LDDV
0.989
0.987
0.997
1.004
0.996
0.989
0.988
0.969
0.952
0.927
0.865
0.839
0.503
0.499
0.497
LDDT
1.231
1.207
1.193
1.173
1.124
1.100
1.101
1.078
1.061
1.045
1.000
0.986
0.510
0.504
0.502
HDDV
2.482
2.425
2.379
2.356
2.292
2.231
2.292
2.292
2.300
2.300
2.223
2.255
2.365
2.304
2.251
MC
0.037
0.037
0.037
0.037
0.037
0.037
0.037
0.037
0.037
0.037
0.037
0.037
0.037
0.037
0.037
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-240
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-26. Fractions of Vehicles Equipped with 3-Way Catalysts by
Vehicle Type and Model Year
Model
Year
1990 and
later
1989
1988
1987
1986
1985
1984
1983
1982
1981
1980
1979 and
earlier
LDGVs
With Without
Catalyst Catalyst
1.00 0.00
1.00 0.00
1.00 0.00
1.00 0.00
1.00 0.00
1.00 0.00
1.00 0.00
0.88 0.12
0.86 0.14
0.07 0.93
0.07 0.93
0.00 1.00
LDGT1
With Without
Catalyst Catalyst
0.95 0.05
0.95 0.05
0.95 0.05
0.95 0.05
0.50 0.50
0.40 0.60
0.30 0.70
0.20 0.80
0.10 0.90
0.05 0.95
0.00 1.00
0.00 1.00
LDGT2
With Without
Catalyst Catalyst
0.85 0.15
0.85 0.15
0.85 0.15
0.85 0.15
0.50 0.50
0.40 0.60
0.30 0.70
0.10 0.90
0.00 1.00
0.00 1.00
0.00 1.00
0.00 1.00
HDGVs
With Without
Catalyst Catalyst
0.25 0.75
0.15 0.85
0.15 0.85
0.15 0.85
0.00 1.00
0.00 1.00
0.00 1.00
0.00 1.00
0.00 1.00
0.00 1.00
0.00 1.00
0.00 1.00
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-241
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-27. Ammonia Emission Factors by Year and Vehicle Type
Year
1999
2000
2002
2005
2007
2008
2010
LDGV
0.13429
0.13510
0.13610
0.13691
0.13738
0.13744
0.13746
LDGT1
0.11845
0.12135
0.12513
0.12816
0.12925
0.12959
0.13019
Ammonia Emission
LDGT2 HDGV
0.
0.
0.
0.
0.
0.
0.
10175
10505
10967
11352
11497
11575
11660
0.02425
0.02579
0.02881
0.03216
0.03356
0.03411
0.03486
0.
0.
0.
0.
0.
0.
0.
Factor
LDDV
.00188
.00188
.00188
.00188
.00188
.00188
.00188
(g/mi)
LDDT
0.
0.
0.
0.
0.
0.
0.
.00188
.00188
.00188
.00188
.00188
.00188
.00188
HDDV
0.00188
0.00188
0.00188
0.00188
0.00188
0.00188
0.00188
MC
0.00352
0.00352
0.00352
0.00352
0.00352
0.00352
0.00352
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-242 On-road Vehicles
-------
Figure 4.6-1. State-Provided Registration Distributions
State: Delaware
Counties: Kent Co
.0020.0630.0690.0720.0750.0810.0860.0840.0820.0750
.0680.0440.0320.0280.0240.0250.0190.0140.0090.0050
.0050.0050.0050.0040.0240
.0010.0550.0720.0730.0710.0900.0900.0870.0810.0600
.0540.0370.0260.0210.0210.0310.0260.0200.0140.0090
.0080.0070.0070.0060.0330
.0070.0360.0560.0620.0790.0820.0820.0540.0770.0590
.0430.0380.0330.0280.0220.0470.0330.0310.0220.0150
.0170.0150.0110.0090.0420
.0020.0480.0430.0440.0590.0590.0600.0560.0720.0590
.0490.0320.0250.0370.0230.0420.0300.0340.0240.0290
.0320.0300.0200.0150.0760
.0020.0630.0690.0720.0750.0810.0860.0840.0820.0750
.0680.0440.0320.0280.0240.0250.0190.0140.0090.0050
.0050.0050.0050.0040.0240
.0010.0550.0720.0730.0710.0900.0900.0870.0810.0600
.0540.0370.0260.0210.0210.0310.0260.0200.0140.0090
.0080.0070.0070.0060.0330
.0030.0260.0320.0400.0370.0660.0710.0560.0610.0580
.0570.0310.0400.0270.0520.0780.0590.0260.0140.0350
.0210.0270.0130.0070.0630
.0060.0490.0580.0590.0470.0770.0350.0530.0820.0570
.0370.4400.0000.0000.0000.0000.0000.0000.0000.0000
.0000.0000.0000.0000.0000.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-243 On-road Vehicles
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Figure 4.6-2. OTAG Inventory Source of Data - VMT
D STATE SUBMITTED
D INTERIM INVENTORY
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-244
1985-1996 Methodology
On-road Vehicles
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4.7 NON-ROAD ENGINES AND VEHICLES
The "Non-road Engines and Vehicles" heading includes the following Tier I and Tier II categories:
Tier 1 Category Tier II Category
(11) Non-road Engines and Vehicles All
The Tier II category includes the estimated emissions from aircraft, commercial marine vessels,
railroads, and all other non-road vehicles and equipment. The methodology used to generate the
emissions for these sources is described in this section.
4.7.1 1990 Interim Inventory
The 1990 emissions from aircraft, commercial marine vessels, and railroads have been estimated
from the area source portion of the 1985 National Acid Precipitation Assessment Program (NAPAP)
inventory by the process described in section 4.7.1.2. The bases for the remaining non-road categories
are the emission inventories1 prepared by the United States (U.S.) Environmental Protection Agency's
(EPA) Office of Mobile Sources (OMS) for 27 nonattainment areas (NAAs). These inventories were
combined and used to create national county-level emissions. These emissions are detailed in section
4.7.1.1.
4.7.1.1 Non-road Engines and Vehicle Emissions
Non-road engines and vehicles include motorized vehicles and equipment that are not normally
operated on public roadways to provide transportation. The non-road mobile source emissions in the
1990 Interim inventory are based on 1990 non-road emissions2 compiled by EPA's Emission Factors and
Inventory Group (EFIG). The EFIG non-road data contains total emissions for non-road sources at the
county level. These emissions include all non-road sources except aircraft, commercial marine vessels,
and railroads. The EFIG non-road emissions were developed from non-road emission inventories for 27
ozone NAAs by OMS. The OMS inventories contained 1990 emissions at the SCC-level for each county
within one of the 27 NAAs. These non-road data do not include emissions for sulfur dioxide (SO2). The
SO2 emissions in the 1985 NAPAP inventory from the non-road sources were approximately 92,000
short tons and are not included in the NET inventory.
A two step process was used to convert the OMS NAA emissions to county-SCC-level emissions
needed for the NET inventory. The first step, performed by EFIG, used the OMS 1990 non-road
emissions for the 27 ozone NAAs to estimate non-road emissions for the rest of the country. The second
step used the EFIG total non-road emissions for each county to create 1990 county-SCC-level non-road
emissions.
Step 1. Creation of National County-Level 1990 Non-road Emissions
OMS prepared 1990 non-road emission inventories for 27 ozone and six carbon monoxide (CO)
NAAs. (Data from the CO NAAs were not used because it did not include VOC and NOX emissions.)
Table 4.7-1 lists the 27 ozone NAAs for which non-road inventories were compiled. Each NAA
inventory contained county-level emissions for 279 different equipment/engine type combinations for
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-245 Non-road Sources
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each county in the NAA. For this information to be useful for the 1990 Interim inventory, non-road
emissions were needed for the entire country (excluding Alaska and Hawaii). The following
methodology was used to create 1990 non-road emissions for the entire country:
(a) volatile organic compounds (VOC), nitrogen oxides (NOX), and CO per capita emission factors
were developed for each NAA by summing each pollutant's emissions for all equipment/engine
categories for all counties within the NAA and dividing by the NAA population
(b) for counties entirely within one of the 27 NAAs, the emissions in the OMS inventories were
used
(c) for counties partially in one of the 27 NAAs, emissions were calculated by multiplying the NAA
per capita emission factor by the total county population
(d) all other counties were assigned a "surrogate NAA" based on geography and climate, emissions
were calculated by multiplying the surrogate NAA per capita emission factors by the total
county population. Figure 4.7-1 shows the surrogate NAA each area of the country was
assigned.
Step 2. Distribution of Total Non-road Emissions to SCCs
The resulting emissions from step 1 above, represent total county non-road emissions. To be
incorporated into the 1990 Interim inventory, these emissions must be distributed to the appropriate
SCCs. The following methodology was used to distribute total non-road emissions to SCCs:
(a) an SCC was assigned to each of the 279 equipment/engine type combinations in the OMS
inventories; the 27 SCCs used are listed in Table 4.7-2
(b) for each of the 27 OMS inventories, the percentage of emissions from sources assigned to each
of the 27 SCCs was calculated
(c) each county's total non-road emissions were distributed to the 27 SCCs using the SCC
percentages from its surrogate NAA.
4.7.1.2 Aircraft, Marine Vessels and Railroads
The area source emissions from the 1985 NAPAP inventory have been projected to the year 1990
based on BEA historic earnings data or other growth indicators. The specific growth indicator was
assigned based on the source category. The Bureau of Economic Analysis (BEA) earnings data were
converted to 1982 dollars as described in section 4.7.1.2.2. All growth factors were calculated as the
ratio of the 1990 data to the 1985 data for the appropriate growth indicator.
When creating the 1990 emissions inventory, changes were made to emission factors from the 1985
inventory for some sources. The 1990 emissions for CO, NOX, SO2, and VOC were calculated using the
following steps: (1) projected 1985 controlled emissions to 1990 using the appropriate growth factors,
(2) calculated the uncontrolled emissions using control efficiencies from the 1985 NAPAP inventory, and
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(3) calculated the final 1990 controlled emissions using revised emission factors. The 1990 PM-10
emissions were calculated using the total suspended particulates (TSP) emissions from the 1985 NAPAP
inventory. The 1990 uncontrolled TSP emissions were estimated in the same manner as the other
pollutants. The 1990 uncontrolled particulate matter less than 10 microns in aerodynamic diameter
(PM-10) estimates were calculated from these TSP emissions by applying source classification code-
(SCC-) specific uncontrolled particle size distribution factors.3 The controlled PM-10 emissions were
estimated in the same manner as the other pollutants.
4.7.1.2.1 Emission Factor Changes —
Emission factors for several sources were updated to reflect recent technical improvements in AP-42
and other emission inventory guidance documents. Emission factors for all four pollutants were updated
for railroads. The SO2 emission factors for aircraft were also updated.
Railroad emission factors in NAPAP were derived from data in AP-42. Improved emission factors
for railroad locomotives have recently been developed in a revision to EPA's mobile source emission
inventory guidance.4 These updated emission factors were incorporated into the 1990 Interim estimates.
Railroad emission factors are summarized in Table 4.7-3 for line-haul locomotives and yard (switch)
locomotives. Because only one set of emission factors is required for railroads, the separate emission
factors for line-haul and yard locomotives were weighted by fuel usage. The Association of American
Railroads (AAR) provided data on fuel consumption by line-haul and yard locomotives for Class I
railroads for 1985 through 1990, as shown in Table 4.7-4.
AP-42 SO2 emission rates were compared with emission rates published in EPA's emission inventory
guidance.5 SO2 rates were on average 54 percent lower, due to changes in fuel sulfur content. This
change was incorporated into the aircraft emissions for the 1990 Interim inventory. (Although new data
were available only for civil aircraft, the emission factor change was incorporated for all aircraft).
Aircraft emission factors for VOC, NOX, and CO have not changed. Table 4.7-5 compares SO2 emission
rates from aircraft.
4.7.1.2.2 1990 Growth Indicators for Aircraft, Marine Vessels, and Railroads —
Emissions from the 1985 NAPAP inventory were grown to the 1990 Interim inventory years based
on historical BEA earnings data or other category-specific growth indicators. Table 4.7-6 shows the
growth indicators used for each area source by NAPAP category.
Activity levels for aircraft are measured by the number of landing-takeoff operations (LTOs).
Annual LTO totals are compiled by the Federal Aviation Administration (FAA) on a regional basis.
Commercial aircraft growth is derived by summing the air carrier and air taxi regional totals of LTOs
from FAA-operated control towers and FAA traffic control centers.6 Since these data are compiled on a
regional basis, the regional trends were applied to each state. Civil aircraft growth indicators were also
developed from regional LTO totals. Civil aircraft activity levels were determined from terminal area
activity for the years 1985 through 1989, and from a 1990 forecast of terminal area activity.73 Since
military aircraft LTO totals were not available, BEA data were used.
The changes in the military aircraft emissions were equated with the changes in historic earnings by
state and industry. Emissions in the 1985 NAPAP inventory were projected to the years 1985 through
1991 based on the growth in earnings by industry (two-digit SIC code). Historical annual state and
National Air Pollutant Emission Trends 1985-1996 Methodology
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industry earnings data from BEA's Table SA-5 (Reference 8) were used to represent growth in earnings
from 1985 through 1990.
The 1985 through 1990 earnings data in Table SA-5 are expressed in nominal dollars. To estimate
growth, these values were converted to constant dollars to remove the effects of inflation. Earnings data
for each year were converted to 1982 constant dollars using the implicit price deflator for PCE.9 The
PCE deflators used to convert each year's earnings data to 1982 dollars are:
Year 1982 PCE Deflator
1985 111.6
1987 114.3
1988 124.2
1989 129.6
1990 136.4
Several BEA categories did not contain a complete time series of data for the years 1985 through
1990. Because the SA-5 data must contain 1985 earnings and earnings for each inventory year (1985
through 1990) to be useful for estimating growth, a log linear regression equation was used where
possible to fill in missing data elements. This regression procedure was performed on all categories that
were missing at least one data point and which contained at least three data points in the time series.
Each record in the point source inventory was matched to the BEA earnings data based on the state
and the two-digit SIC. Table 4.7-7 shows the BEA earnings category used to project growth for each of
the two-digit SICs found in the 1985 NAPAP inventory. No growth in emissions was assumed for all
point sources for which the matching BEA earnings data were not complete. Table 4.7-7 also shows the
national average growth and earnings by industry from BEA Table SA-5.
Railroad data are provided by the Association of American Railroads (AAR). National totals of
revenue-ton-miles for the years 1985 through 1990 are used to estimate changes in activity during this
period. The national growth is therefore applied to each state and county.10
Marine vessel activity is recorded annually by the U.S. Army Corp of Engineers. Cargo tonnage
national totals are used to determine growth in diesel- and residual-fueled vessel use through the year
1989." Since gasoline-powered vessels are used predominantly for recreation, growth for this category is
therefore based on population.
4.7.1.2.3 Emissions Calculations —
A four-step process was used to calculate emissions incorporating rule effectiveness. First, base
year controlled emissions are projected to the inventory year using the following equation (Equation
4.7-1).
CE. = CEBY + (CEBY x EGt) (Eq. 4.7-1)
National Air Pollutant Emission Trends 1985-1996 Methodology
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where: CE; = Controlled Emissions for inventory year I
CEBY = Controlled Emissions for base year
EG; = Earnings Growth for inventory year I
Earnings growth is calculated using Equation 4.7-2.
DAT.
(Eq-4-7-2)
BY
where: EG; = Earnings growth for year I
DAT; = Earnings data for inventory year I
DATBY = Earnings data in the base year
Second, uncontrolled emissions in the inventory year are back-calculated from the controlled emissions
based on the control efficiency using Equation 4.7-3.
CE.
UE; =
1 _ CEFF\ (Eq. 4.7-3)
I " 100 J
where: UE; = Uncontrolled Emissions for inventory year I
CE; = Controlled Emissions for inventory year I
CEFF = Control Efficiency (percent)
For aircraft, marine vessels, and railroads this equation reduces to Equation 4.7-4 since the control
efficiency is equal to zero.
UE. = CEi (Eq. 4.7-4)
Third, controlled emissions are recalculated incorporating revised emission factors using the following
equation (Equation 4.7-5).
( EFi \
CERt= UCt * —M (Eq. 4.7-5)
I EFBY)
where: CER; = Controlled Emissions Incorporating Rule Effectiveness
UQ = Uncontrolled Emissions
EF; = Emission factor for inventory year I
EFBY = Emission factor for base year
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The last step in the creation of the inventory was matching the NAPAP categories to the new AMS
categories. This matching is provided in Table 4.7-8. Note that there is not always a one-to-one
correspondence between NAPAP and AMS categories.
4.7.2 Emissions, 1970 through 1989
The non-road emissions for the years 1970 through 1989 have been based on the 1990 estimates.
Historic Economic Growth Analysis System (E-GAS) growth factors12 were obtained by representative
NAA and rest of state counties and by Bureau of Labor Statistics (BLS) codes and then correlated to the
non-road SCCs and counties.
Emissions (countytSCCtyear} = Growth(countytSCCyear} x Emissions(counly>scc>1990) (Eq. 4.7-6)
4.7.3 1990 National Emissions Trends
The 1990 National Emission Trends (NET) data base is based primarily on state data, with the
Interim data filling in the data gaps. The state data were extracted from the Ozone Transport Assessment
Group (OTAG) inventory. As part of the OTAG Inventory development, 24 states submitted emission
estimates for non-road sources. Of these states, 17 submitted emission estimates for the entire state and
7 submitted emission estimates for a portion of their state. Since the goal of the OTAG Inventory
development effort was to create an inventory of ozone season daily (OSD), daily emission estimates
were submitted by all states, except Texas which submitted annual emissions. Daily emissions were
converted to annual emissions using EPA's default SCC-specific temporal allocation factors. Table 4.6-7
shows which states submitted non-road estimates for the OTAG Inventory and what type of data they
submitted.
The actual incorporation of emission estimates from the OTAG Inventory was performed by
determining the counties for which state submitted data was available from the OTAG Inventory.
Emission estimates for those counties were then removed from the Trends Inventory. Then the county/
SCC-level emission estimates from the OTAG Inventory were added to the Trends Inventory. Since the
OTAG Inventory was primarily an inventory of VOC, NOX, and CO, very little SO2 or PM emission
estimates were included in the state submissions. In cases where SO2 and/or PM emission estimates were
submitted they were used, otherwise the SO2 and PM emission estimates from the Interim Inventory were
kept.
The final 1990 non-road diesel emission estimates were adjusted so that the national emissions in the
Trends report would be consistent with national emissions estimated by OMS as part of the EPA Notice
of Proposed Rulemaking (NPRM) for non-road diesel engine.13 The methods used for developing 1995
emission estimates are documented in the next section of this chapter. Making this adjustment for 1995
resulted in a large discontinuity in the emission estimates between 1995 and the years preceding it. To
remove this large discontinuity, emission estimates for years prior to 1995 (including the base year, 1990)
were adjusted to be consistent with the final 1995 emissions. This adjustment was implemented by
multiplying the emissions for each county by the following ratio:
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-250 Non-road Sources
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FinalNationall 995Estimates
(Eq. 4.7-7)
PreliminaryNational\995Estimates
The final 1995 national estimates are after adjusting for emissions for consistency with the NPRM
emissions and the preliminary 1995 national estimates are prior to adjusting to the NPRM emissions.
Applying this ratio maintains the geographic distribution of the base year estimates while adjusting the
size of the emission estimates to be consistent with the 1995 emissions from the NPRM.
4.7.4 Emissions, 1991 through 1994
The 1991 through 1994 area source emissions were grown in a similar manner as the 1985 through
1989 estimates, except for using a different base year inventory. The base year for the 1991 through
1994 emissions is the 1990 NET inventory.
Base year emission estimates were projected to 1991 through 1994 using BEA historical earnings
data as a surrogate for growth. Historical earnings for the years 1990 through 1995 were obtained from
BEA's Table SA-5 - Total Personal Income by Major Sources.8 The BEA earnings data is by state and
2-digit SIC. There were three steps taken in using the BEA data to project growth: (1) BEA data was
converted from nominal dollars to constant dollars, (2) 1996 growth factors were developed based on the
1990 through 1995 normalized data, and (3) growth factors were applied to 1990 emissions based on a
SIC to SCC crosswalk.
The earnings data in BEA Table SA-5 is in nominal dollars. In order to use the data to generate
growth factors it was converted to 1992 constant dollars to remove the effects of inflation. Earnings data
for each year was converted to 1992 constant dollars using the implicit price deflator for PCE. The PCE
deflators used to convert earnings to 1992 dollars are:
Year 1992 PCE Deflator
1990 93.6
1991 97.3
1992 100.0
1993 102.6
1994 104.9
1995 107.6
The BEA earnings data for 1996 were not published or available for use on this project. 1996
earnings data were estimated by linear growth in earnings from 1990 to 1995. The following equation
was used to estimate the 1996 earnings:
l996Earnings = 1995Earnings + ^ Earnings - 199Q Earnings ^ 4 ?_g)
1995 and 1996 growth factors were calculated based on the change in earnings from the base year
(1990) to the year emissions were being estimated for (1995 or 1996). For each county-level emission
National Air Pollutant Emission Trends 1985-1996 Methodology
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estimate, the appropriate growth factor was selected based on the state and SCC. The crosswalk
between SCC and growth factors is displayed in Table 4.7-10. The growth factor was then multiplied by
the 1990 emissions resulting in the 1995 or 1996 emissions. The following equation was used.
Earnings^
Emissions95 96 = Emissions^*- (Eq. 4.7-9)
Earnmgs95or96
Tables 4.7-11 and 4.7-12 lists the 1990 through 1996 growth indicators by BEA earnings and population.
Commercial aircraft emissions were projected using FAA estimates of LTOs for the years 1990 through
1996.7b'7c
The 1991 through 1995 emissions for NOX locomotive and all commercial aircraft emission estimates
were developed using 1990 Interim Inventory emissions and applying growth factors using Equation
4.7-5. The growth factors were obtained from the prereleased E-GAS, version 2.O.12 The E-GAS
generates growth factors at the SCC-level for counties representative of all counties within each ozone
nonattainment area classified as serious and above and for counties representative of all counties within
both the attainment portions and the marginal and moderate nonattainment areas within each state. The
appropriate growth factors were applied by county and SCC to the 1990 emissions as shown by Equation
4.7-5.
There are approximately 150 representative counties in E-GAS and 2000 SCCs present in the base
year inventory. This yields a matrix of 300,000 growth factors generated to determine a single year's
inventory. To list all combinations would be inappropriate.
The final 1991-1994 non-road diesel emission estimates were adjusted so that the national emissions
in the Trends report would be consistent with national emissions estimated by OMS as part of the EPA
NPRM for non-road diesel engines.13 The methods used for developing 1995 emission estimates are
documented in the next section of this chapter. Making this adjustment for 1995 resulted in a large
discontinuity in the emission estimates between 1995 and the years preceding it. To remove this large
discontinuity, emission estimates for years prior to 1995 (including the base year, 1990) were adjusted to
be consistent with the final 1995 emissions. This adjustment was implemented by multiplying the
emissions for each county by the following ratio:
Final National 1995 Estimates
Preliminary National 1995 Estimates
The final 1995 national estimates are after adjusting for emissions for consistency with the NPRM
emissions and the preliminary 1995 national estimates are prior to adjusting to the NPRM emissions.
Applying this ratio maintains the geographic distribution of the base year estimates while adjusting the
size of the emission estimates to be consistent with the 1995 emissions from the NPRM.
National Air Pollutant Emission Trends 1985-1996 Methodology
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4.7.5 1995 Emissions
The 1995 emission estimates were derived in a similar manner as the 1991 through 1994 estimates.
Exceptions are noted in section 4.7.7.
4.7.6 1996 Emissions
The 1996 emission estimates were derived in a similar manner as the 1995 emissions. The following
three subsections describe the projected 1996 emissions.
4. 7. 6. 1 Grown Estimates
The 1996 area source emissions were grown using the 1995 NET inventory as the basis. The
algorithm for determining the estimates is detailed in section 4.7.1.2.3 and is described by the equation
below. The 1990 through 1996 SEDS and BEA data are presented in Tables 4.7-1 1 and 4.7-12. The
1996 BEA and SEDS data were determined using linear interpretation of the 1988 through 1995 data.
Equation 4.7-11 describes the calculation used to estimate the 1996 emissions.
1QQfi 1QQ,
1996 1995
where: CER1996 = controlled emissions incorporating rule effectiveness
UC1995 = uncontrolled emissions
GS = growth surrogate (either BEA or SEDS data)
REFF = rule effectiveness (percent)
CEFF = control efficiency (percent)
RP = rule penetration (percent)
The rule effectiveness for 1996 was always assumed to be 100 percent. The control efficiencies and rule
penetrations are detailed in the following subsections.
4. 7.6.2 Non-road Engine Controls-Sp ark-Ignition Engines < 25 hp
EPA is currently in the process of developing regulations for spark ignition engines less than
25 horsepower (hp) that are designed to reduce hydrocarbons (HC), NOX, and CO emissions. Expected
to be included under these rules are most general utility equipment (i.e., lawn and garden and light
commercial/industrial equipment), as well as farm and construction engines less than 25 hp.
A 3 percent reduction to the VOC emissions was applied nationally for all two-stroke gasoline
engines (SCC = 2260xxxxxx) and all four-stroke gasoline engines (SCC = 2265xxxxxx). An additional
3.3 percent reduction was added to areas with reformulated gasoline. The counties with reformulated
gasoline programs are listed in Table 4.7-13.
National Air Pollutant Emission Trends 1985-1996 Methodology
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4.7.6.3 Non-road Diesel Engines
A 37 percent reduction to the NOX emissions was applied nationally to all diesel compression ignition
engines. A rule effectiveness of 100 percent was applied as well as a rule penetration rate of between 0.5
and 1 percent, depending on type of equipment. Table 4.7-14 lists the reductions by SCC.
4.7.7 1995 and 1996 Emission Revisions
As an update to portions of the NET non-road inventory, OMS agreed to provide emission estimates
from their models and analyses being used for the Regulatory Impact Analysis (RIA) documents.
Categories for which OMS provided data are non-road diesel engines, non-road spark-ignition marine
engines, and locomotives. For each of these categories OMS provided national/SCC level emission
estimates. For the diesel non-road engines the pollutants covered included VOC, NOX, CO, PM-10, and
PM-2.5. For the non-road spark-ignition marine engines, only VOC and NOX were provided. For
locomotives, only NOX and PM-10 were provided
These national OMS numbers were used to update the 1995 and 1996 NET emission estimates such
that the sum of the county/SCC level NET estimates would equal the national/SCC level OMS estimates.
Listed below is the procedure used to incorporate the national OMS emission estimates.
1. 1995 and 1996 county/SCC level emission estimates were developed from the 1990 NET emissions
using the normal procedure (i.e., BEA growth factors were applied and applicable credits for control
programs were accounted for.)
2. The 1995 and 1996 county/SCC level emission estimates developed in Step 1 were aggregated to
national/SCC level emission estimates. This was done at the equipment level (e.g., construction,
agriculture, lawn and garden, etc.) rather than the specific engine level; although the OMS data was
supplied at the specific engine level, a large portion of the NET emission estimates are at the engine
category level.
3. Pollutant-specific adjustment factors for each applicable engine category were developed by
calculating the ratio of the OMS estimate to the NET estimate.
4. The NET county/SCC level estimates developed in Step 1 were then multiplied by the appropriate
adjustment factor resulting in final NET county/SCC level estimates that equal the OMS estimates
when aggregated to the national level.
For locomotives, the national OMS estimates were close to the national NET estimates prior to any
adjustments for all pollutants except PM-10. Therefore, only PM-10 and PM-2.5 (calculated as
92 percent of the revised PM-10) were adjusted for locomotives. For non-road diesel engines and non-
road spark-ignition marine engines, adjustments were made to all pollutants for which OMS provided
information (VOC, NOX, CO, PM-10, and PM-2.5 for non-road diesel, VOC and NOX for non-road
spark-ignition marine engines.)
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Tables 4.7-15 through 4.7-17 show the national NET estimates prior to adjustments and the OMS
provided estimates for non-road diesel engines, non-road spark-ignition marine engines, and locomotives,
respectively.
One final adjustment was made to the 1995 and 1996 emission estimates. Emissions from non-road
agricultural engines were re-allocated to the county level based on county level acres of crops harvested
in the 1992 Census of Agriculture.14 This adjustment was performed because the methods used to
allocated emissions from non-road agricultural engines for the Interim Inventory were thought to be
deficient. Since the geographic allocation of the non-road emissions in the Interim Inventory were based
on emissions in 27 urban nonattainment areas and most farm equipment usage occurs in rural areas, the
Interim Inventory allocation of emissions from non-road farm may not be accurate. This adjustment was
performed by aggregating the emissions from non-road farm equipment to the national level for each
pollutant. The national level emissions were then allocated to the county level based on the numbers of
acres harvested in that county. This adjustment was made for both gasoline and diesel engines.
4.7.8 References
1. Documentation for Estimation of Non-road Emission Estimates for the United States, U.S.
Environmental Protection Agency, Research Triangle Park, NC, November 1992.
2. Non-road Engine Emission Inventories for CO and Ozone Nonattainment Boundaries, U.S.
Environmental Protection Agency, Ann Arbor, MI, October 1992.
3. Barnard, W.R., and P. Carlson, PM-10 Emission Calculation, Tables 1 and 4, E.H. Pechan &
Associates, Inc. Contract No. 68-DO-1020, U.S. Environmental Protection Agency, Emission
Factor and Methodologies Section, Research Triangle Park, NC. June 1992.
4. Procedures for Emission Inventory Preparation, Volume IV: Mobile Sources, Draft revision,
Chapter 6, U.S. Environmental Protection Agency, Office of Mobile Sources, Ann Arbor, MI, 1991.
5. Procedures for Emission Inventory Preparation, Volume IV: Mobile Sources, Draft revision,
Chapter 5, U.S. Environmental Protection Agency, Office of Mobile Sources, Ann Arbor, MI,
November 1991.
6. Air Traffic Activity, U.S. Department of Transportation, Federal Aviation Administration,
Washington, DC, 1991.
7. Terminal Area Forecasts, FY1991-2005, FAA-APO-91-5, U.S. Department of Transportation,
Federal Aviation Administration, Washington, DC, July 1991.
a. July 1991
b. February 1992, Table 27
c. March 1997, Table 28
8. Table SA-5 — Total Personal Income by Major Sources 1969-1990, data files, U.S. Department of
Commerce, Bureau of Economic Analysis, Washington, DC, September 1991.
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9. Survey of Current Business, U.S. Department of Commerce, Bureau of Economic Analysis,
Washington, DC, July 1986, July 1987, July 1988, July 1989, July 1990, July 1991.
10. Railroad Ten-Year Trends 1981-1990, Association of American Railroads, Washington, DC, 1991.
11. Waterborne Commerce of the United States, Calendar Year 1989, WRSC-WCUS-89, Part 5, U.S.
Army Corp of Engineers, New Orleans, LA, June 1991.
12. E-GAS Growth Factors and BLS to SCC Cross Reference. Computer PC model and files received
by E.H. Pechan & Associates, Inc. from TRC Environmental Corporation, Chapel Hill, NC.
June 1994.
13. "Emission Inventories Used in the Nonroad Diesel Proposed Rule," Office of Mobile Sources, U.S.
Environmental Protection Agency, Ann Arbor, MI. E-mail to Sharon Nizich, Office of Air Quality
Planning and Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC,
August 27, 1997.
14. "1994 Census of Agriculture - Geographic Area Series 1A, IB, and 1C," (CD-ROM), Bureau of the
Census, U.S. Department of Commerce, 1995.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-256 Non-road Sources
-------
Table 4.7-1. Ozone Nonattainment Areas with QMS-Prepared Non-road Emissions
Atlanta, GA
Baltimore, MD
Baton Rouge, LA
Beaumont, TX
Boston, MA
Chicago, IL
Cleveland, OH
Denver, CO
El Paso, TX
Hartford, CT
Houston, TX
Miami, FL
Milwaukee, Wl
Muskegon, Ml
New York, NY
Philadelphia, PA
Phoenix, AZ
Portsmouth, NH
Providence, Rl
San Diego, CA
San Joaquin, CA
Seattle, WA
Sheboygan, Wl
South Coast, CA
Springfield, MA
St. Louis, MO
Washington, DC
Figure 4.7-1. Assignment of Surrogate Nonattainment Areas
•Boston
•Providence
(art fond
San jSSduin
Philadelphia / f. ^NewYor*
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-257
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-2. Source Categories Used for Nonroad Emissions
AMS SCC
Category Description
2260001000
2260002000
2260003000
2260004000
2260005000
2260006000
2260007000
2260008000
2265001000
2265002000
2265003000
2265004000
2265005000
2265006000
2265007000
2265008000
2270001000
2270002000
2270003000
2270004000
2270005000
2270006000
2270007000
2270008000
2282005000
2282010000
2282020000
Recreational Vehicles: Gasoline, 2-Stroke
Construction Equipment: Gasoline, 2-Stroke
Industrial Equipment: Gasoline, 2-Stroke
Lawn & Garden Equipment: Gasoline, 2-Stroke
Farm Equipment: Gasoline, 2-Stroke
Light Commercial: Gasoline, 2-Stroke
Logging Equipment: Gasoline, 2-Stroke
Airport Service Equipment: Gasoline, 2-Stroke
Recreational Vehicles: Gasoline, 4-Stroke
Construction Equipment: Gasoline, 4-Stroke
Industrial Equipment: Gasoline, 4-Stroke
Lawn & Garden Equipment: Gasoline, 4-Stroke
Farm Equipment: Gasoline, 4-Stroke
Light Commercial: Gasoline, 4-Stroke
Logging Equipment: Gasoline, 4-Stroke
Airport Service Equipment: Gasoline, 4-Stroke
Recreational Vehicles: Diesel
Construction Equipment: Diesel
Industrial Equipment: Diesel
Lawn & Garden Equipment: Diesel
Farm Equipment: Diesel
Light Commercial: Diesel
Logging Equipment: Diesel
Airport Service Equipment: Diesel
Recreational Marine Vessels: Gasoline, 2-Stroke
Recreational Marine Vessels: Gasoline, 4-Stroke
Recreational Marine Vessels: Diesel
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-258
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-3. Railroad Locomotives Diesel Fuel Consumption, 1985 to 1990
(million gallons)
Year
1985
1990
Source:
Line-Haul
2,889
2,876
"Railroad Ten- Year Trends 1981-1990,"
Switch
255
258
Association of
American Railroads, Washington, DC, 1991.
Table 4.7-4. Railroad Emission Factors
(lbs/1,000 gallons)
Wtg. Factor NO, CO HC SO,
NAPAP
Revised
Line-haul
Yard
New Wtd. Avg.
370
2,876 493.1
258 504.4
494
130
62.6
89.4
65
90
20.1
48.2
22
57
36.0
36.0
36
Source: "Procedures for Emission Inventory Preparation, Volume IV: Mobile Sources," Draft revision,
Chapter 5, Office of Mobile Sources, U.S. Environmental Protection Agency, Ann Arbor, Ml,
November 1991.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-259 Non-road Sources
-------
Table 4.7-5. Civil Aircraft SO, Emission Factors
Engine
Type
250B17B
501D22A
TPE-331-3
JT3D-7
JT9D-7
PT6A-27
Fuel
Rate
(Ibs/hr)
63
265
245
85
610
2376
2198
1140
112
458
409
250
1013
9956
8188
3084
1849
16142
13193
4648
115
425
400
215
AP-42 SO2
Emission
Factor
(Ibs/hr)
0.06
0.27
0.25
0.09
0.61
2.38
2.2
1.14
0.11
0.46
0.41
0.25
1.01
9.96
8.19
3.08
1.85
16.14
13.19
4.65
0.12
0.43
0.4
0.22
New SO2
Emission
Factor
(Ibs/hr) Enqine Type
0.03 PT6A-41
0.14
0.13
0.05
0.33 Dart RDa7
1.28
1.19
0.62
0.06 0-200
0.25
0.22
0.14
0.55 TSIO-360C
5.38
4.39
1.67
1 .00 0-320
8.72
7.12
2.51
0.06
0.23
0.22
0.12
Fuel
Rate
(Ibs/hr)
147
510
473
273
411
1409
1248
645
8.24
45.17
45.17
25.5
11.5
133
99.5
61
9.48
89.1
66.7
46.5
AP-42 SO2
Emission
Factor
(Ibs/hr)
0.15
0.51
0.47
0.27
0.41
1.41
1.25
0.65
0
0.01
0.01
0.01
0
0.03
0.02
0.01
0
0.02
0.01
0.01
New SO2
Emission
Factor
(Ibs/hr)
0.08
0.28
0.26
0.15
0.22
0.76
0.67
0.35
0.00
0.00
0.00
0.00
0.00
0.01
0.01
0.01
0.00
0.01
0.01
0.01
Source: "Supplement D to Compilation of Air Pollutant Emission Factors, Volume I: Stationary Point and Area
Sources," AP-42, U.S. Environmental Protection Agency, Research Triangle Park, NC, September
1991.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-260
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-6. Area Source Growth Indicators
NAPAP
SCC
Category Description
Data
Source
Growth Indicator
45 Railroad Locomotives
46 Aircraft LTOs - Military
47 Aircraft LTOs - Civil
48 Aircraft LTOs - Commercial
49 Vessels - Coal
50 Vessels - Diesel Oil
51 Vessels - Residual Oil
AAR
BEA
FAA
FAA
Corp of
Engineers
Railroad ton-miles (national)
Military
Aircraft - civil
Aircraft - commercial
Cargo tonnage (national)
Cargo tonnage (national)
Cargo tonnage (national)
Table 4.7-7. Bureau of Economic Analysis's SA-5 National Changes in Earnings by
Industry
Industry
SIC
Percent Growth
1985 to 1987
1987 to 1988
1988 to 1989
1989 to 1990
Federal, military
97
1.96
- 1.07
- 1.58
-3.19
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-261
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-8. AMS to NAPAP Source Category Correspondence
AMS
SCC
Category
NAPAP
SCC Category
Mobile Sources
2275001001 Aircraft - Military Aircraft (LTOs)
2275020000 Aircraft - Commercial Aircraft (LTOs)
2275050000 Aircraft - Civil Aircraft (LTOs)
2280001000 Marine Vessels - Coal
2280002000 Marine Vessels - Diesel
2280003000 Marine Vessels - Residual Oil
2285002000 Railroads - Diesel
2260001000 Recreational Vehicles: Gasoline, 2-Stroke
2260002000 Construction Equipment: Gasoline, 2-Stroke
2260003000 Industrial Equipment: Gasoline, 2-Stroke
2260004000 Lawn & Garden Equipment: Gasoline, 2-Stroke
2260005000 Farm Equipment: Gasoline, 2-Stroke
2260006000 Light Commercial: Gasoline, 2-Stroke
2260007000 Logging Equipment: Gasoline, 2-Stroke
2260008000 Airport Service Equipment: Gasoline, 2-Stroke
2265001000 Recreational Vehicles: Gasoline, 4-Stroke
2265002000 Construction Equipment: Gasoline, 4-Stroke
2265003000 Industrial Equipment: Gasoline, 4-Stroke
2265004000 Lawn & Garden Equipment: Gasoline, 4-Stroke
2265005000 Farm Equipment: Gasoline, 4-Stroke
2265006000 Light Commercial: Gasoline, 4-Stroke
2265007000 Logging Equipment: Gasoline, 4-Stroke
2265008000 Airport Service Equipment: Gasoline, 4-Stroke
2270001000 Recreational Vehicles: Diesel
2270002000 Construction Equipment: Diesel
2270003000 Industrial Equipment: Diesel
2270004000 Lawn & Garden Equipment: Diesel
2270005000 Farm Equipment: Diesel
2270006000 Light Commercial: Diesel
2270007000 Logging Equipment: Diesel
2270008000 Airport Service Equipment: Diesel
2282005000 Recreational Marine Vessels: Gasoline, 2-Stroke
2282010000 Recreational Marine Vessels: Gasoline, 4-Stroke
2282020000 Recreational Marine Vessels: Diesel
46 Aircraft LTOs - Military
48 Aircraft LTOs - Commercial
47 Aircraft LTOs - Civil
49 Vessels - Coal
50 Vessels - Diesel Oil
51 Vessels - Residual Oil
45 Railroad Locomotives
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
39 Non-road Sources Gasoline Vehicles
44 Non-road Sources Diesel Vehicles
44 Non-road Sources Diesel Vehicles
44 Non-road Sources Diesel Vehicles
44 Non-road Sources Diesel Vehicles
44 Non-road Sources Diesel Vehicles
44 Non-road Sources Diesel Vehicles
44 Non-road Sources Diesel Vehicles
44 Non-road Sources Diesel Vehicles
52 Marine Vessels - Gasoline
52 Marine Vessels - Gasoline
N/A
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-262
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-9. Non-road Data Submitted for OTAG Inventory
State
Connecticut
Delaware
District of Columbia
Florida
Georgia
Illinois
Indiana
Kentucky
Louisiana
Maine
Maryland
Michigan
New Hampshire
New Jersey
New York
North Carolina
Ohio
Pennsylvania
Rhode Island
Texas
Vermont
Virginia
West Virginia
Wisconsin
Data Source/Format
State - EPS Workfile
State - EPS Workfile
State - Hard copy
AIRS-AIMS - Ad hoc retrievals
State - State format
State - State format
State - State format
State - State Format
State - State Format
State - EPS Workfile
State - EPS Workfile
State - State Format
State - EPS Workfile
State - EPS Workfile
State - EPS Workfile
State - EPS Workfiles
State - Hard copy
State - EPS Workfile
State - EPS Workfile
State - State Format
State - EPS Workfile
State - EPS Workfile
AIRS-AIMS - Ad hoc retrievals
State - State Format
Temporal
Resolution
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Annual
Daily
Daily
Daily
Daily
Geographic Coverage
Entire State
Entire State
Entire State
Jacksonville, Miami/
Ft. Lauderdale, Tampa
Atlanta Urban Airshed
(47 Counties)
Entire State
Entire State
Kentucky Ozone Nonattainment
Areas
Baton Rouge Nonattainment
Area (20 Parishes)
Entire State
Entire State
49 Southern Michigan Counties
Entire State
Entire State
Entire State
Entire State
Canton, Cleveland Columbus,
Dayton, Toledo, and Youngstown
Entire State
Entire State
Entire State
Entire State
Entire State
Charleston, Huntington/Ashland,
and Parkersburg (5 counties
total)
Entire State
Adjustments to Data
None
None
None
Added Nonroad emission estimates
from Int. Inventory to Jacksonville
(Duval County)
None
None
Nonroad emissions submitted were
county totals. Nonroad emissions
distributed to specific SCCs based
on Int. Inventory
None
None
None
None
None
None
None
None
Mone
Assigned SCCs and converted from
-------
Table 4.7-10. Area Source Listing by SCC and Growth Basis
SCC
FILE CODE
SCC
FILE CODE
SCC
FILE CODE
2260000000 SEDS TPOPP
2260001000 SEDS TPOPP
2260001010 SEDS TPOPP
2260001020 SEDS TPOPP
2260001030 SEDS TPOPP
2260001050 SEDS TPOPP
2260001060 SEDS TPOPP
2260002000 BEA 300
2260002006 BEA 300
2260002009 BEA 300
2260002021 BEA 300
2260002033 BEA 300
2260003000 BEA 400
2260003010 BEA 400
2260003020 BEA 400
2260003030 BEA 400
2260003040 BEA 400
2260004000 SEDS TPOPP
2260004010 SEDS TPOPP
2260004015 SEDS TPOPP
2260004020 SEDS TPOPP
2260004025 SEDS TPOPP
2260004030 SEDS TPOPP
2260004035 SEDS TPOPP
2260004050 SEDS TPOPP
2260004075 SEDS TPOPP
2260005000 BEA 081
2260006000 BEA 400
2260006005 BEA 400
2260006010 BEA 400
2260006015 BEA 400
2260006020 BEA 400
2260007000 BEA 100
2260007005 BEA 100
2260008000 BEA 542
2260008010 BEA 542
2265000000 SEDS TPOPP
2265001000 SEDS TPOPP
2265001010 SEDS TPOPP
2265001030 SEDS TPOPP
2265001040 SEDS TPOPP
2265001050 SEDS TPOPP
2265001060 SEDS TPOPP
2265002000 BEA 300
2265002021 BEA 300
2265002024 BEA 300
2265002027 BEA 300
2265002030 BEA 300
2265002033 BEA 300
2265002039 BEA 300
2265002042 BEA 300
2265002045 BEA 300
2265002054 BEA 300
2265002057 BEA 300
2265002060 BEA 300
2265002066 BEA 300
2265002072 BEA 300
2265002078 BEA 300
2265002081 BEA 300
2265003000 BEA 400
2265003010 BEA 400
2265003020 BEA 400
2265003030 BEA 400
2265003040 BEA 400
2265003050 BEA 400
2265004000 SEDS TPOPP
2265004010 SEDS TPOPP
2265004015 SEDS TPOPP
2265004025 SEDS TPOPP
2265004030 SEDS TPOPP
2265004035 SEDS TPOPP
2265004040 SEDS TPOPP
2265004045 SEDS TPOPP
2265004050 SEDS TPOPP
2265004055 SEDS TPOPP
2265004060 SEDS TPOPP
2265004065 SEDS TPOPP
2265004070 SEDS TPOPP
2265004075 SEDS TPOPP
2265005000 BEA 081
2265005010 BEA 081
2265005015 BEA 081
2265005020 BEA 081
2265005030 BEA 081
2265005035 BEA 081
2265005040 BEA 081
2265005045 BEA 081
2265005050 BEA 081
2265006015 BEA 400
2265006025 BEA 400
2265006030 BEA 400
2265007000 BEA 100
2265007010 BEA 100
2265008000 BEA 542
2265008005 BEA 542
2265008010 BEA 542
2270000000 SEDS TPOPP
2270001000 SEDS TPOPP
2270001010 SEDS TPOPP
2270001050 SEDS TPOPP
2270001060 SEDS TPOPP
2270002000 BEA 300
2270002003 BEA 300
2270002009 BEA 300
2270002012 BEA 300
2270002015 BEA 300
2270002018 BEA 300
2270002021 BEA 300
2270002027 BEA 300
2270002030 BEA 300
2270002033 BEA 300
2270002036 BEA 300
2270002039 BEA 300
2270002042 BEA 300
2270002045 BEA 300
2270002048 BEA 300
2270002051 BEA 300
2270002054 BEA 300
2270002057 BEA 300
2270002060 BEA 300
2270002063 BEA 300
2270002066 BEA 300
2270002069 BEA 300
2270002072 BEA 300
2270002075 BEA 300
2270002078 BEA 300
2270002081 BEA 300
2270003000 BEA 400
2270003010 BEA 400
2270003020 BEA 400
2270003030 BEA 400
2270003040 BEA 400
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-264
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-10. (continued)
SCC
FILE CODE
SCC
FILE CODE
SCC
FILE CODE
2265002003 BEA 300
2265002006 BEA 300
2265002009 BEA 300
2265002015 BEA 300
2270004055 SEDS TPOPP
2270004060 SEDS TPOPP
2270004065 SEDS TPOPP
2270004070 SEDS TPOPP
2270004075 SEDS TPOPP
2270005000 BEA 081
2270005015 BEA 081
2270005020 BEA 081
2270005025 BEA 081
2270005035 BEA 081
2270005045 BEA 081
2270005050 BEA 081
2270005055 BEA 081
2270006000 BEA 400
2270006005 BEA 400
2270006010 BEA 400
2270006015 BEA 400
2270006025 BEA 400
2270006030 BEA 400
2270007000 BEA 100
2270007015 BEA 100
2270007020 BEA 100
2265005055 BEA 081
2265006000 BEA 400
2265006005 BEA 400
2265006010 BEA 400
2270008000 BEA 542
2270008005 BEA 542
2270008010 BEA 542
2275000000 BEA 542
2275001000 BEA 920
2275020000 BEA 542
2275020021 BEA 542
2275050000 BEA 542
2275060000 BEA 542
2275070000 BEA 542
2275900000 BEA 542
2275900101 BEA 542
2275900102 BEA 542
2280000000 BEA 530
2280001000 BEA 530
2280002000 BEA 530
2280002010 BEA 530
2280002020 BEA 530
2280002040 BEA 530
2280003000 BEA 530
2280003010 BEA 530
2280003020 BEA 530
Table 4.7-11. SEDS National Fuel Consumption,
Fuel Tvoe End-User Code
Population
TPOPP
Table 4.7-1 2. BEASA-5
Industry
Farm
Agricultural services, forestry, fisheries, and other
Construction
Manufacturing
Railroad transportation
Water transportation
Transportation by air
Federal, military
1990 1991 1992
248,709 252,131 255,025
2270003050 BEA 400
2270004000 SEDS TPOPP
2270004010 SEDS TPOPP
2270004040 SEDS TPOPP
2280003030 BEA 530
2280004020 BEA 530
2282000000 SEDS TPOPP
2282005000 SEDS TPOPP
2282005010 SEDS TPOPP
2282005015 SEDS TPOPP
2282005025 SEDS TPOPP
2282010000 SEDS TPOPP
2282010005 SEDS TPOPP
2282010010 SEDS TPOPP
2282010015 SEDS TPOPP
2282010020 SEDS TPOPP
2282010025 SEDS TPOPP
2282020000 SEDS TPOPP
2282020005 SEDS TPOPP
2282020010 SEDS TPOPP
2282020020 SEDS TPOPP
2282020025 SEDS TPOPP
2283002000 BEA 920
2285000000 BEA 510
2285002000 BEA 510
2285002005 BEA 510
2285002010 BEA 510
1990-1 996 (trillion Btu)
1993 1994 1995 1996
257,785 259,693 261,602 263,510
National Earnings by Industry, 1990-1996 (million $)
LNUM SIC 1990
81 1,2 48
100 7-9 24
300 15-17 218
400 998 710
510 40 12
530 44 7
542 45 30
920 992 50
1991 1992 1993 1994 1995 1996
41 46 45 42 31 29
24 24 24 26 27 27
197 195 199 216 219 219
690 705 705 725 740 747
12 13 12 12 12 12
776666
30 31 31 31 31 31
50 51 48 45 44 43
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-265
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-13. Counties in the United States with Stage II Programs
that use Reformulated Gasoline
State
County
State
County
State
County
6
6
6
6
6
6
6
9
9
9
9
9
9
9
9
10
10
10
11
17
17
17
17
17
17
17
17
18
18
21
21
21
21
21
21
23
23
23
23
23
23
23
24
24
24
24
24
24
24
24
24
24
24
24
24
California
California
California
California
California
California
California
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Delaware
Delaware
Delaware
Dist. Columbia
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Indiana
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Maine
Maine
Maine
Maine
Maine
Maine
Maine
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
Maryland
19
29
37
55
67
73
75
1
3
5
7
9
11
13
15
1
3
5
1
31
43
63
89
93
97
111
197
89
127
15
29
37
111
117
185
1
5
11
13
15
23
31
3
5
9
13
15
17
21
25
27
29
31
33
35
Fresno Co
Kern Co
Los Angeles Co
Napa Co
Sacramento Co
San Diego Co
San Francisco Co
Fairfield Co
Hartford Co
Litchfield Co
Middlesex Co
New Haven Co
New London Co
Tolland Co
Windham Co
Kent Co
New Castle Co
Sussex Co
Washington
Cook Co
Du Page Co
Grundy Co
Kane Co
Kendall Co
Lake Co
McHenry Co
Will Co
Lake Co
Porter Co
Boone Co
Bullitt Co
Campbell Co
Jefferson Co
Kenton Co
Oldham Co
Androscoggin Co
Cumberland Co
Kennebec Co
KNOX Co
Lincoln Co
Sagadahoc Co
York Co
Anne Arundel Co
Baltimore Co
Calvert Co
Carroll Co
Cecil Co
Charles Co
Frederick Co
Harford Co
Howard Co
Kent Co
Montgomery Co
Prince George's Co
Queen Annes Co
24
25
25
25
25
25
25
25
25
25
25
25
25
25
25
33
33
33
33
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
34
36
36
36
36
36
36
36
36
36
36
36
36
42
42
42
Maryland
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
Massachusetts
New Hampshire
New Hampshire
New Hampshire
New Hampshire
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New York
New York
New York
New York
New York
New York
New York
New York
New York
New York
New York
New York
Pennsylvania
Pennsylvania
Pennsylvania
510
1
3
5
7
9
11
13
15
17
19
21
23
25
27
11
13
15
17
1
3
5
7
9
11
13
15
17
19
21
23
25
27
29
31
33
35
37
39
41
5
27
47
59
61
71
79
81
85
87
103
119
17
29
45
Baltimore
Barnstable Co
Berkshire Co
Bristol Co
Dukes Co
Essex Co
Franklin Co
Hampden Co
Hampshire Co
Middlesex Co
Nantucket Co
Norfolk Co
Plymouth Co
Suffolk Co
Worcester Co
Hillsborough Co
Merrimack Co
Rockingham Co
Strafford Co
Atlantic Co
Bergen Co
Burlington Co
Camden Co
Cape May Co
Cumberland Co
Essex Co
Gloucester Co
Hudson Co
Hunterdon Co
Mercer Co
Middlesex Co
Monmouth Co
Morris Co
Ocean Co
Passaic Co
Salem Co
Somerset Co
Sussex Co
Union Co
Warren Co
Bronx Co
Dutchess Co
Kings Co
Nassau Co
New York Co
Orange Co
Putnam Co
Queens Co
Richmond Co
Rockland Co
Suffolk Co
Westchester Co
Bucks Co
Chester Co
Delaware Co
42
42
44
44
44
44
44
48
48
48
48
48
48
48
48
48
48
48
48
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
51
55
55
55
55
55
55
Pennsylvania
Pennsylvania
Rhode Island
Rhode Island
Rhode Island
Rhode Island
Rhode Island
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Texas
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Wisconsin
Wisconsin
Wisconsin
Wisconsin
Wisconsin
Wisconsin
91
101
1
3
5
7
9
39
71
85
113
121
157
167
201
291
339
439
473
13
36
41
85
87
95
107
153
159
179
199
510
550
570
600
610
650
670
683
685
700
710
735
740
760
800
810
830
59
79
89
101
131
133
Montgomery Co
Philadelphia Co
Bristol Co
Kent Co
Newport Co
Providence Co
Washington Co
Brazoria Co
Chambers Co
Collin Co
Dallas Co
Denton Co
Fort Bend Co
Galveston Co
Harris Co
Liberty Co
Montgomery Co
Tarrant Co
Waller Co
Arlington Co
Charles City Co
Chesterfield Co
Hanover Co
Henrico Co
James City Co
Loudoun Co
Prince William Co
Richmond Co
Stafford Co
York Co
Alexandria
Chesapeake
Colonial Heights
Fairfax
Falls Church
Hampton
Hopewell
Manassas
Manassas Park
Newport News
Norfolk
Poquoson
Portsmouth
Richmond
Suffolk
Virginia Beach
Williamsburg
Kenosha Co
Milwaukee Co
Ozaukee Co
Racine Co
Washington Co
Waukesha Co
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-266
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-14. NOX Nonroad Control Efficiencies by SCC
SCC POD PODNAME ATTAINMENT CONTROL
2270002xxx 48 Construction Equipment - Diesel Attainment Phase 1 compression ign. std
2270003xxx 48 Industrial Equipment - Diesel Attainment Phase 1 compression ign. std
2270004xxx 48 Lawn And Garden - Diesel Attainment Phase 1 compression ign. std
2270005xxx 48 Farm Equipment - Diesel Attainment Phase 1 compression ign. std
2270006xxx 48 Commercial Equipment - Diesel Attainment Phase 1 compression ign. std
2270007xxx 48 Logging Equipment - Diesel Attainment Phase 1 compression ign. std
2270008xxx 48 Airport Service Equipment - Diesel Attainment Phase 1 compression ign. std
RULPEN96 CONEFF96
1.0 37
0.9 37
0.5 37
1.0 37
1.0 37
1.0 37
1.0 37
-------
Table 4.7-15. National Nonroad Diesel Emissions
(tons)
Ermine Tvoe
Recreational
Vehicles
Construction
Industrial
Lawn and Garden
Agricultural
Light
Commercial
Logging
Airport Service
VOC
NOX
CO
PM-10
PM-2.5
VOC
NOX
CO
PM-10
PM-2.5
VOC
NOX
CO
PM-10
PM-2.5
VOC
NOX
CO
PM-10
PM-2.5
VOC
NOX
CO
PM-10
PM-2.5
VOC
NOX
CO
PM-10
PM-2.5
VOC
NOX
CO
PM-10
PM-2.5
VOC
NOX
CO
PM-10
PM-2.5
19!
NET
1
547
7
0
0
98,658
794,859
477,757
145,900
134,228
233,948
216,66
98,727
24,866
22,877
723
5,946
3,351
898
827
23,691
118,414
113,801
20,076
18,470
2,284
15,386
9,884
2,953
2,717
654
8,665
3,999
1,165
1,072
12,045
100,442
46,446
17,971
16,534
35
QMS
1,160
7,672
4,795
959
882
166,439
1,389,600
767,523
163,983
150,865
32,255
260,134
126,916
30,527
28,085
9,568
63,250
39,532
7,906
7,273
219,496
1,105,995
830,206
204,237
187,898
14,393
95,148
59,467
11,893
10,941
12,002
74,186
29,365
7,727
7,109
10,273
90,835
39,318
10,381
9,550
1996
NET QMS
1
547
7
0
0
100,161
804,137
484,772
148,235
136,376
23,797
214,30'
98,080
24,921
22,929
730
5,983
3,380
906
834
32,625
164,323
149,409
21,158
19,466
2,314
15,532
10,011
2,989
2,750
670
8,844
4,095
1,180
1,086
12,201
101,350
46,959
18,316
16,851
1,170
7,747
4,876
975
897
167,115
1,385,862
775,071
166,034
152,752
32,667
262,874
129,074
31,047
28,563
9,706
64,184
40,174
8,034
7,392
219,594
1,111,779
842,638
207,506
190,905
14,609
96,607
60,478
12,095
11,127
11,652
72,616
29,688
7,812
7,187
10,001
86,672
39,987
10,557
9,713
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-268
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-16. National Spark Ignition Marine Engine Emissions
(tons)
Pollutant
voc
NOX
1995
NET
492,248
27,731
QMS
431,504
41,756
1996
NET
495,491
27,945
QMS
459,072
41,968
Table 4.7-17. National Locomotive Emissions
(tons)
Pollutant 1995 NET 1995 QMS
PM-10 50,000 26,900
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-269 Non-road Sources
-------
4.8 FUGITIVE DUST
The "Fugitive Dust" grouping includes the estimated emissions for several Tier II source categories.
These Tier II source categories are components of two Tier I source categories: Natural Sources and
Miscellaneous Sources. The PM-10 and PM-2.5 emissions from the Natural Sources category discussed
here are from geogenically derived wind erosion. PM-10 and PM-2.5 emissions in the Miscellaneous
Sources category are divided into two Tier II subcategories: agriculture and forestry, and fugitive dust.
This section presents a description of the methodology used to estimate the emissions for the following
tier categories:
Tier I Category Tier II Category
(13) Natural Sources (02) Geogenic (agricultural wind erosion)
(14) Miscellaneous (01) Agriculture and Forestry
(07) Fugitive Dust
PM-2.5 emissions were calculated only for the years 1990 through 1996. Although several of the
source categories listed above have information concerning the PM-2.5 particle size multiplier that should
be applied to the AP-42 emission factor to calculate PM-2.5 emissions, much of that data is fairly old. As
a consequence, EPA, Pechan, and Midwest Research Institute (MRI) performed an evaluation of more
recent particle size distribution information.1 That review indicated that the PM-2.5/PM-10 ratio for
several of the source categories listed above should be reduced. Table 4.8-1 shows the particle size ratios
used to calculate PM-2.5 particle size multipliers from the PM-10 particles size multipliers used to
develop PM-10 emissions for each fugitive dust category in this section.
4.8.1 Natural Sources, Geogenic, Wind Erosion
The wind erosion emissions were estimated for the years 1985 through 1996 using the following
methodology. PM-10 and PM-2.5 wind erosion emissions estimates for agricultural lands were made
using a modification of the methodology used by Gillette and Passi2 to develop wind erosion emissions
for 1985 NAPAP. Several simplifying assumptions were made in order to perform the calculations using
a spreadsheet model.3
The NAPAP methodology and the method used to develop the wind erosion estimates presented
here both develop an expectation of the dust flux based on the probability distribution of wind energy.
The methodology uses the mean wind speed coupled with information concerning the threshold friction
velocity for the soil and information on precipitation to predict the wind erosion flux potential for soils.
The basic equation used to determine the expected dust flux is given by Equation 4.8-1.
/ = k x C x C(
u
4
0.8864
T(3X) (Eq. 4.8-1)
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-270 Fugitive Dust
-------
where: I = dust flux (gm/cm2/sec)
k = PM-10 particle size multiplier (= 0.9)
PM-2.5 particle size multiplier (= 0.135)
C = constant (= 4 x 10"14 gm/cm2/sec)
Cd = drag coefficient
u = mean wind speed (cm/sec)
F(3,x) = incomplete gamma function
To evaluate F(3,x), x must be determined from Equation 4.8-2.
/ / \\ 2
* = L x M§£ (Eq. 4.8-2)
The threshold velocity (ut) can be determined from the threshold friction velocity (u*t - which is a function
of soil type and precipitation) from Equation 4.8-3.
Values of the threshold friction velocity for different soil types both before and after rain to account for
crusting of the soil surface have been reported by Gillette and Passi.2
4.8.1.1 Determination of Correction Parameters
In order to calculate the flux of emissions from wind erosion using the above equation, information
concerning the average monthly wind speed, total monthly precipitation and anemometer height for the
wind speed was necessary. Values for monthly wind speed, total monthly precipitation and anemometer
height were obtained from the Local Climatological Data4 for several meteorological stations within each
state. For most states, several meteorological stations data were obtained and an overall average was
determined for the state. The anemometer height was utilized to determine the drag coefficient (Cd) from
Equation 4.8-4.
f 023V
Cd = \-^-\ (Eq. 4.8-4)
s
where: zs = anemometer height
Information concerning the average soil type for each state was determined from the USDA surface
soil map.5 A single soil type was assigned to each state in order to determine a single value for the
threshold friction velocity (u*t). The threshold friction velocity (u*,) utilized represented either a before or
after rain value, depending upon whether or not precipitation exceeded 5.08 cm during a month. If
precipitation exceeded this amount, the after rain u*t value was utilized for all succeeding months until the
time of a significant tillage operation or plant emergence. The value of ut was then calculated using the
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-271 Fugitive Dust
-------
value of u*t determined and Cd. Once ut was determined, then x could be calculated and the incomplete
gamma function could be evaluated using an asymptotic expansion. Following evaluation of the
incomplete gamma function, the flux for each month was determined.
Wind erosion was assumed to be zero from the time of plant emergence until harvest. Separate flux
estimates were made for fall planted crops and spring planted crops. This meant that flux estimates were
only calculated from July to October for fall planted crops and from September until May for spring
planted crops. This approach is consistent with the methodology utilized by Gillette and Passi.2 For the
years 1985 through 1989, the before rain u*t value was always utilized for January for spring planted
crops rather than evaluating whether or not any month between September and December of the previous
year had more than 5.08 cm of precipitation.
4.8.1.2 1990-1996 Modification
The method for estimating 1990 through 1996 emissions from geogenic wind erosion is similar to
the above wind erosion methodology with the exception that previous years rain data for September
through December was used. This data was used to determine whether or not any month between
September and December of the previous year had more than 5.08 cm of precipitation. Gillette and Passi
utilized previous year precipitation information to assign the threshold friction velocity to an area.
4.8.1.3 Activity Data
Once the emission flux potential for each month for each crop type (fall or spring planted) for each
state was calculated, then the acres of spring or fall planted crops in each state were required (and the
number of seconds per month) to determine the emissions. The acres of crops planted in each state was
obtained for each of the 11 years from the USDA.6 Evaluation of which crops were spring planted or fall
planted for each state was made using information available from the USDA.7 The emissions calculated
were then estimated for each state.
4.8.1.4 County Distribution (1985-1989)
State-level PM-10 estimates were distributed to the county-level using estimates of county rural land
area from the U.S. Census Bureau.8 Equation 4.8-5 was used.
^ , r . . \ County Rural Lancn „, , „ . . _ „ 0 _
County Emissions = x State Emissions (Eq 4 8-5)
State Rural Land ^ 4 ;
4.8.1.5 County Distribution (1990-1996)
State-level PM-10 estimates were distributed to the county-level using estimates of acres of land
tilled from the Conservation Information Technology Center.9 Equation 4.8-6 was used.
„ , r . . ( County Cropland Tilled] „, , „ . . _ „ 0 ^.
County Emissions = x State Emissions (Eq 4 8-6)
( State Croplant Tilled } ^ 4 ;
'National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-272 Fugitive Dust
-------
4.8.2 Miscellaneous Sources
The methodology used to estimate the emissions from agricultural crops, agricultural livestock, and
fugitive dust are described in this section. The PM-10 and PM-2.5 emissions arise from construction
activities, mining and quarrying, paved road resuspension, and unpaved roads. The general methodology
used for these categories estimated the emissions by using an activity indicator and an emission factor
with one or more correction factors. The activity indicator for a given category varied from year to year
as may the correction factors.
4.8.2.1 Agricultural Crops (1985-1989)
The PM-10 emissions for the years 1985 through 1989 were estimated using the AP-42 emission
factor equation for agricultural tilling.10 The activity data for this calculation were the acres of land
planted. The emission factor, developed to estimate of the mass of TSP produced per acre-tilled was
adjusted to estimate PM-10 using the following constant parameters: the silt content of the surface soil, a
particle size multiplier, and the number of tillings per year.
The following AP-42 particulate emission factor equation (Equation 4.8-7) was used to determine
state PM-10 emissions from agricultural tilling for 1985 through 1989:
E = c x k x s0'6 x p x a (Eq. 4.8-7)
where: E = PM-10 emissions
c = constant 4.8 Ibs/acre-pass
k = dimensionless particle size multiplier (PM-10=0.21)
s = silt content of surface soil, defined as the mass fraction of particles smaller than
75 |^m diameter found in soil to a depth of 10 cm (%)
p = number of passes or tillings in a year (assumed to be 3 passes)
a = acres of land planted
4.8.2.1.1 Determination of Correction Parameters —
4.8.2.1.1.1 Silt content (s). By comparing the USDA5 surface soil map with the USDA11 county map,
soil types were assigned to all counties of the continental United States. Silt percentages were
determined by using a soil texture classification triangle.12 For those counties with organic material as its
soil type, Pechan used the previous silt percentages presented by Cowherd.13 The weighted mean state
silt values were determined by weighing the county value by the number of hectares within the county and
summing across the entire state. Table 4.8-2 shows the silt percentages used for 1985 through 1989.
These silt values were assumed constant for the 5-year period examined.
4.8.2.1.1.2 Number of Tillings per year (p). Cowherd et al.13 reported that crops are tilled three
times each year, on average, and this value was used for p.
4.8.2.1.2 Activity Data —
The acres of crops planted (a) in each state was obtained for each of the 5 years from the USDA.6
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-273 Fugitive Dust
-------
4.8.2.1.3 County Distribution —
State-level PM-10 estimates were distributed to the county-level using county estimates of cropland
harvested from the 1987 Census of Agriculture.14 Equation 4.8-8 was used.
„ , r . . ( County Cropland Harvested] „, , „ . . _
County Emissions = x State Emissions (Eq 4 8-8)
^ State Croplant Harvested )
4.8.2.2 Agricultural Crops (1990-1996)
The methodology to determine agricultural crop emissions for the years 1990 through 1996 was
similar to the methodology for the years 1985 through 1989, with several exceptions. The PM-10 and
PM-2.5 emissions for the years 1990 through 1996 were also estimated using the AP-42 emission factor
equation for agricultural tilling.10 The activity data for this calculation were the acres of land tilled. The
emission factor, developed to estimate the mass of TSP produced per acre-tilled was adjusted to estimate
PM-10 and PM-2.5 using the following constant parameters: the silt content of the surface soil, a particle
size multiplier, and the number of tillings per year.
The following AP-42 particulate emission factor equation (Equation 4.8-9) was used to determine
regional PM-10 emissions from agricultural tilling for 1990 through 1996:
E = c x k x s()'6 x p x a (Eq. 4.8-9)
where: E = PM emissions
c = constant 4.8 Ibs/acre-pass
k = dimensionless particle size multiplier
(PM-10=0.21; PM-2.5=0.042)
s = silt content of surface soil, defined as the mass fraction of particles smaller than
75 |^m diameter found in soil to a depth of 10 cm (%)
p = number of passes or tillings in a year
a = acres of land tilled
4.8.2.2.1 Determination of Correction Parameters —
4.8.2.2.1.1 Silt content (s). By comparing the USDA5 surface soil map with the USDA11 county map,
soil types were assigned to all counties of the continental U.S. Silt percentages were determined by using
a soil texture classification triangle.12 For those counties with organic material as its soil type, Pechan
used the previous silt percentages presented by Cowherd.13 These silt factors were then corrected using
information from Spatial Distribution of PM-10 emissions from Agricultural Tilling in the San Joaquin
Valley.15 Information in that report indicates that silt contents determined from the classification triangle
are typically based on wet sieving techniques. The AP-42 silt content is based on dry sieving techniques.
Wet sieving tends to desegregate finer materials thus leading to a higher than expected silt content based
on the soil triangle estimates. The overestimation is dependent upon the soil type. As a consequence, the
values for silt loam and loam were reduced by a factor of 1.5. The values for clay loam and clay were
reduced by a factor of 2.6. The values for sand, loamy sand, sandy loam and organic material remained
the same. Table 4.8-3 shows the percent silt used for each soil type for 1990 through 1996. These silt
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-274 Fugitive Dust
-------
values were assumed constant for the 6-year period examined. This differs from the 1989 through 1985
methodology in that the silt factors are applied on the county level, and are corrected values.
4.8.2.2.1.2 Number of Tillings per year (p). The number of tillings for 1990 through 1996 were
determined for each crop type, and for conservational and conventional use using information from
Agricultural Activities Influencing Fine Particulate Matter Emissions.16 The tillage emission factor ratio
column in the tables in that report were totaled by crop type when the agricultural implement code was
not blank. Harvesting was not included in this total. When the tilling instrument was felt to deeply
disturb the soil, the value of the tillage emission factor ratio was equal to one. However, other field
instruments were not felt to disturb the soil to the extent of the instruments used to develop the original
AP-42 emission factor and thus had an emission factor ratio of less than one. Discussions with the
organization that developed the original emission factor and the report referenced above indicated that
these values should be used to calculate the number of tillings rather than a single value for each
implement usage.17 Where there were data from more than one region for a single crop, an average
value was used. Information for both conservation and convention tillage methods were developed. The
tallies were rounded to the nearest whole number, since it is not physically possible to have a partial
tillage event.
These totals were tallied for corn, cotton, rice, sorghum, soybeans, spring wheat, and winter wheat.
Table 4.8-4 shows the number of tilling used for each crop type, and for conservational and conventional
use included in the database provided by the Conservation Information Technology Center (CTIC).9 The
number of tillings for categories not included in Agricultural Activities Influencing Fine Particulate Matter
Emissions were determined by contact with the CTIC.18
Rice and spring wheat are included in the category "spring-seeded small grain" in the database
provided by the CTIC.9 Winter wheat was assumed to prevail in all states except Arkansas, Louisiana,
Mississippi, and Texas. Rice was assumed to prevail in these four states, and the number of tillings for
rice were applied to the acres harvested in these states. Both rice and winter wheat are grown in
California. A ratio of rice to winter wheat acres harvested for 1990 through 1996 was obtained from the
U.S. Land Use Summary.6 This ratio was used to calculate a modified number of tillings for spring-
seeded small grain in California for each year.
Acres reported in the CTIC database for no till, mulch till, and ridge till were considered
conservation tillage. Those with 0 to 15 percent residue, and 15 to 30 percent residue were considered
conventional tillage.
4.8.2.2.2 Activity Data —
The acres of crops tilled (a) in each county for each crop type and tilling method was obtained for
each of the 6 years from the CTIC.9
4.8.2.2.3 County Distribution —
All emissions for agricultural crops for 1990-1996 were calculated on a county basis.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-275 Fugitive Dust
-------
4.8.2.3 Agricultural Livestock
The 1990 emissions from agricultural livestock were determined from activity data, expressed in
terms of the number of heads of cattle14 and a national PM-10 emission factor.19 Equation 4.8-10 was
used.
„ , r . . ( County Head of Cattle] ,n .^ „ 0 _.
County Emissions = ^ J- x 17 (Eq 4 8-10)
( 1,000 j v 4 ;
The emissions for the years 1985 through 1989 were produced using the methodology described in
section 4.8.2.8.3. The emissions for the years 1991 through 1996 were produced using the method
described in section 4.8.2.8.4.1. The PM-2.5 emissions for agricultural livestock for the years 1990
through 1996 were determined by multiplying the PM-10 emission for that year by the size adjustment
factor of 0.15, shown in table 4.8-1.
Due to double counting in the NPI, emissions for the following SCCs were deleted: 2805001000,
2805010000, 2805015000, and 2805005000.
Agricultural sources (i.e., livestock operations and fertilizer application) make up approximately
90 percent of NH3 emissions in current inventories. Because of the high relative contribution from these
sources, efforts were made to use the most recent information available to estimate their emissions.
Sections 4.8.2.3.1 and 4.8.2.3.2 describe the methodology used to estimate NH3 emissions from livestock
operations and fertilizer application, respectively.
4.8.2.3.1 Livestock Operations —
The livestock NH3 emissions in the inventory were estimated using activity data from the 1992 Census of
Agriculture.20 These data included county-level estimates of number of head for the following livestock:
cattle and calves, hogs and pigs, poultry, sheep, horses, goats, and minks. The emission factors used to
calculate emissions were taken from a study of NH3 emissions conducted in the Netherlands,21 and are
listed in table 4.8-5.
4.8.2.3.2 Fertilizer Application —
NH3 emissions from fertilizer application may comprise up to ten percent of total NH3 emissions
nationally. The activity data used to estimate emissions were obtained from the Commercial Fertilizers
Data Base compiled by T VA and now maintained by Association of American Plant Food Control
Officials.22 This database includes county-level usage of over 100 different types of fertilizers, including
those that emit NH3.
The emission factors used for fertilizer application were also obtained from the Netherlands NH3
study.21 This source lists emission factors for ten different types of fertilizers including the following:
• Anhydrous ammonia • Ammonium sulfate
• Aqua ammonia • Ammonium thiosulfate
• Nitrogen solutions • Other straight nitrogen
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-276 Fugitive Dust
-------
• Urea • Ammonium phosphates
• Ammonium nitrate • N-P-K
4.8.2.4 PM Emissions from Reentrained Road Dust from Unpaved Roads
Estimates of PM emissions from reentrained road dust on unpaved roads were developed for each
county. PARTS reentrained road dust emission factors depend on the average weight, speed, and number
of wheels of the vehicles traveling on the unpaved roadways, the silt content of the roadway surface
material, and the percentage of days in the year with minimal (less than 0.01 inches) or no precipitation.
Emissions were calculated by month at the state/road type level for the average vehicle fleet and then
allocated to the county/road type level by land area. The activity factor for calculating reentrained road
dust emissions on unpaved roads is the VMT accumulated on these roads. The specifics of the emission
estimates for reentrained road dust from unpaved roads are discussed in more detail below.
4.8.2.4.1 PM Emission Factor Calculation —
Equation 4.8-11, used in PARTS to calculate PM emission factors from Reentrained road dust on
unpaved roads, is based on an empirical formula from AP-42.23
UNPVD = PSUNPps * 5.9 * (SILT/12) * (SPD/30) * (WEIGHT/3)0'1 * (WHEELS/4)0-5 *
(365-IPDAYS)/365 * 453.392 (
-------
were calculated for each state that had three or more samples for that state. For states that did not have
three or more samples, the average for all samples from all states was substituted.
4.8.2.4.1.2 Precipitation Inputs. Rain data input to the emission factor equation above is in the form
of the total number of rain days in the year. However, the equation uses the number of days simply to
calculate a percentage of rain days. Therefore, to calculate unpaved road dust emission factors that
represent monthly conditions, data from the National Climatic Data Center4 showing the number of days
per month with more than 0.01 inches of rain were used. Precipitation event accumulation data were
collected for several meteorological stations within each state.
4.8.2.4.1.3 Vehicle Wheel, Weight, and Speed Inputs. The speeds shown in table 4.8-6 for light duty
vehicles and trucks were also assumed to be the average unpaved road speeds for the corresponding
unpaved road classification. However, because the fugitive dust emission factors are representative of
the entire vehicle fleet, these speeds for each road type were weighted by vehicle-specific VMT to obtain
road type-specific speeds. These speeds are shown in table 4.8-6. Estimates of average vehicle weight
and average number of wheels per vehicle over the entire vehicle fleet were based on data provided in the
Truck Inventory and Use Survey,25 MVMA Motor Vehicle Facts and Figures '91,26 and the 1991 Market
Data Book.21 Using these data sources, a fleet average vehicle weight of 6,358 pounds was modeled with
a fleet average number of wheels per vehicle of five.
4.8.2.4.2 Unpaved Road VMT —
The calculation of unpaved road VMT was performed in two parts. Separate calculations were
performed for county and noncounty (state or federally) maintained roadways. The 1995 unpaved VMT
was also used for 1996, as unpaved growth is very uncertain, but expected to be minimum.
Equation 4.8-12 is used to calculate unpaved road VMT.
VMTUP = ADTV * FSRM * DPY (Eq. 4.8-12)
where: VMTUP = VMT on unpaved roads (miles/year)
ADTV = average daily traffic volume (vehicles/day/mile)
FSRM = functional system roadway mileage (miles)
DPY = number of days in a year
4.8.2.4.2.1 Estimating Local Unpaved VMT. Unpaved roadway mileage estimates were retrieved
from the FHWA's annual Highway Statistics2* report. State-level, county-maintained roadway mileage
estimates are organized by surface type, traffic volume, and population category. From these data, state-
level unpaved roadway mileage estimates were derived for the volume and population categories listed in
table 4.8-7. This was done by first assigning an average daily traffic volume (ADTV) to each volume
category, as shown in table 4.8-7.
The above equation was then used to calculate state-level unpaved road VMT estimates for the
volume and population categories listed in table 4.8-7. These detailed VMT data were then summed to
develop state-level, county-maintained unpaved roadway VMT.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-278 Fugitive Dust
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4.8.2.4.2.2 Estimation of Federal and State-Maintained Unpaved Roadway VMT. The calculation
of noncounty (state or federally) maintained unpaved road VMT differed from the calculation of county-
maintained unpaved road VMT. This was required since noncounty unpaved road mileage was
categorized by arterial classification, not roadway traffic volume.
To calculate noncounty, unpaved road VMT, state-level ADTV values for urban and rural roads
were multiplied by state-level, rural and urban roadway mileage estimates. Assuming the ADTV does not
vary by roadway maintenance responsibility, the county-maintained ADTV values were assumed to apply
to noncounty-maintained roadways as well. To develop noncounty unpaved road ADTV estimates,
county-maintained roadway VMT was divided by county-maintained roadway mileage estimates, as
shown in Equation 4.8-13.
ADTV = VMT I MILEAGE (Eq. 4.8-13)
where: ADTV = average daily traffic volume for state and federally maintained roadways
VMT = VMT on county-maintained roadways (miles/year)
MILEAGE = state-level roadway mileage of county-maintained roadways (miles)
Federal and state-maintained roadway VMT was calculated by multiplying the state-level roadway
mileage of federal and state-maintained unpaved roads28 by the state-level ADTV values calculated as
discussed above for locally-maintained roadways. Equation 4.8-14 illustrates.
VMT = ADTV * RM * 365 (Eq. 4.8-14)
where: VMT = VMT at the state level for federally and state-maintained unpaved roadways
(miles/year)
ADTV = average daily traffic volume derived from local roadway data
RM = state-level federally and state-maintained roadway mileage (mi)
4.8.2.4.2.3 Unpaved VMT For 1993 and Later Years. The calculation of unpaved VMT differs for
years before 1993 and for the year 1993 and later years. This split in methodology is due a difference in
the data reported by states in the annual Highway Statistics. In both instances the calculation was
performed in two stages.
Unpaved VMT for 1993 and later years was calculated by multiplying the total number of miles of
unpaved road by state and functional class by the annualized traffic volume, where the annualized traffic
volume is calculated as the average daily traffic volume multiplied by the total number of days per year.
This calculation is illustrated in Equation 4.8-15.
UnpavedVMTRoadtype=MileageRoadtype*ADTV*DPY (Eq. 4.8-15)
where: Unpaved VMT = road type specific unpaved Vehicle Miles Traveled (miles/year)
Mileage = total number of miles of unpaved roads by functional class (miles)
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-279 Fugitive Dust
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ADTV = Average daily traffic volume (vehicle/day)
DPY = number of days per year
The total number of unpaved road miles by state and functional class was retrieved from the federal
Highway Administrations Highway Statistics.28 In Highway Statistics, state level Local functional class
unpaved mileage is broken out by ADTV category. The ADTV categories differed for urban and rural
areas. Table MV-1 of Highway Statistics shows the ADTV categories for rural and urban local
functional classes and the assumed traffic volume for each category. Local functional class unpaved
VMT was calculated for each of these ADTV categories using the equation illustrated above.
Unpaved road mileage for functional classes other than Local (rural minor collector, rural major
collector, rural minor arterial, rural other principal arterial, urban collector, urban minor arterial, urban
other principal arterial) are not broken out by ADTV in Highway Statistics. An average ADTV was
calculated for these functional classes by dividing state level unpaved Local VMT by the total number of
miles of Local unpaved road. Separate calculations were preformed for urban and rural areas. The
resulting state level urban and rural ADTV was then multiplied by the total number of unpaved miles in
each of the non-local functional classes.
One modification was made to the Local functional class mileage reported in Highway Statistics.
The distribution of mileage between the ADTV categories for Mississippi resulted in unrealistic
emissions. Total unpaved road mileage in Mississippi was redistribute within the ADTV categories based
on the average distributions found in Alabama, Georgia, and Louisiana.
4.8.2.4.3 Calculation of State-Level Emissions —
The state and federally maintained unpaved road VMT were added to the county- maintained VMT
for each state and road type to determine each state's total unpaved road VMT by road type. The state-
level unpaved road VMT by road type were then temporally allocated by month using the same NAPAP
temporal allocation factors used to allocate total VMT. These monthly state-level, road type-specific
VMT were then multiplied by the corresponding monthly, state-level, road type-specific emission factors
developed as discussed above. These state-level emission values were then allocated to the county level
using the procedure discussed below.
4.8.2.4.4 Allocation of State-Level Emissions to Counties —
The state/road type-level unpaved road PM emission estimates were then allocated to each county in
the state using estimates of county rural and urban land area from the U.S. Census Bureau29 for the years
1985 through 1989. Equation 4.8-16 was used for this allocation.
PMXY = (CNTYLANDURBjJSTATLANDURB)
+ (CNTYLANDRURjjSTATLANDRUR) *
where: PMxy = unpaved road PM emissions (tons) for county x and road type y
CNTYLANDURB x = urban land area in county x
STATLANDURB = urban land area in entire state
PMST URB Y = unpaved road PM emissions in entire state for urban road type y
CNTYLANDRURX = rural land area in county x
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-280 Fugitive Dust
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STATLANDRUR = rural land area in entire state
PMST RUR Y = unpaved road PM emissions in entire state for rural road type y
For the years 1990 through 1996, 1990 county-level rural and urban population was used to distribution
the state-level emissions instead of land area.
4.8.2.4.5 Nonattainment Area 1995 and 1996 Unpaved Road Controls —
PM control measures were applied to the unpaved road emission estimates for the years 1995 and
1996 and for the projection years. The level of control assumed varied by PM nonattainment area
classification and by rural and urban areas. On urban unpaved roads in moderate PM nonattainment
areas, the assumed control was paving the unpaved roads. This control was applied with a 96 percent
control efficiency and a 50 percent penetration rate. On rural roads in serious PM nonattainment areas,
chemical stabilization was the assumed control. This control was applied with a 75 percent control
efficiency and a 50 percent penetration rate. On urban unpaved roads in serious PM nonattainment areas,
paving and chemical stabilization were the controls assumed to be applied. This combination of controls
was applied with an overall control efficiency of 90 percent and a penetration rate of 75 percent.
4.8.2.5 PM Emissions from Reentrained Road Dust from Paved Roads
Estimates of PM emissions from reentrained road dust on paved roads were developed at the county
level in a manner similar to that for unpaved roads. PART5 reentrained road dust emission factors for
paved roads depend on the road surface silt loading and the average weight of all of the vehicles traveling
on the paved roadways. The equation used in PART5 to calculate PM emission factors from reentrained
road dust on paved roads is a generic paved road dust calculation formula from AP-42, shown in
Equation 4.8-17.30
PAVED = PSDPVD * (PVSILT/2)0'65 * (WEIGHT/3)1'5 (Eq. 4.8-17)
where: PAVED = paved road dust emission factor for all vehicle classes combined (grams per
mile)
PSDPVD = base emission factor for particles of less than 10 or 2.5 microns in diameter
from paved road dust (7.3 g/mi for PM-10 and ? for PM-2.5)
PVSILT = road surface silt loading (g/m2)
WEIGHT = average weight of all vehicle types combined (tons)
Paved road silt loadings were assigned to each of the twelve functional roadway classifications (six urban
and six rural) based on the average annual traffic volume of each functional system by state. One of three
values were assigned to each of these road classes, 1 (gm/m2) was assigned Local functional class roads,
and either 0.20 (gm/m2) or 0.04 (gm/m2) were assigned to each of the other functional class roads. A silt
loading of 0.20 (gm/m2) was assigned to a road types that had an ADTV less than 5000 and 0.04 (gm/m2)
was assigned to road types that had an ADTV greater than or equal to 5000. ADTV was calculated by
dividing annual VMT by state and functional class by state specific functional class roadway mileage.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-281 Fugitive Dust
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As with the PARTS emission factor equation for unpaved roads, the above PM emission factor
equation for paved roads is representative of a fleet average emission factor rather than a vehicle-specific
emission factor and it includes particulate matter from tailpipe exhaust, brake wear, tire wear, and
ambient background particulate concentrations. Therefore, the PARTS fleet average PM emission factors
for the tailpipe, tire wear, and brake wear components were subtracted from the paved road fugitive dust
emission factors before calculating emissions from reentrained road dust on paved roads.
The emission factors obtained from PARTS were modified to account for the number of days with a
sufficient amount of precipitation to prevent road dust resuspension. The PARTS emission factors were
multiplied by the fraction of days in a month with less than 0.01 inches of precipitation. This was done by
subtracting data from the National Climatic Data Center showing the number of days per month with
more than 0.01 inches of precipitation from the number of days in each month and dividing by the total
number of days in the month. These emission factors were developed by month at the state and road type
level for the average vehicle fleet.
For the years 1990 to 1996 the rain correction factor applied to the paved road fugitive dust
emission factors was reduced by 50 percent.
VMT from paved roads was calculated at the state/road type level by subtracting the state/road type-
level unpaved road VMT from total state/road type-level VMT. Because there are differences in
methodology between the calculation of total and unpaved VMT there are instances where unpaved
VMT is higher than total VMT. For these instances, unpaved VMT was reduced to total VMT and
paved road VMT was assigned a value of zero. The paved road VMT were then temporally allocated by
month using the NAPAP temporal allocation factors for VMT. These monthly/state/road type-level
VMT were then multiplied by the corresponding paved road emission factors developed at the same level.
These paved road emissions were allocated to the county level according to the fraction of total
VMT in each county for the specific road type. Equation 4.8-18 illustrates this allocation.
PVDEMISXY = PVDEMISSTY * VMTx>y/VMTST>Y (Eq. 4.8-18)
where: PVDEMISX Y = paved road PM emissions (tons) for county x and road type y
PVDEMISST Y = paved road PM emissions (tons) for the entire state for road type y
VMTX Y = total VMT (million miles) in county x and road type y
VMTST Y = total VMT (million miles) in entire state for road type y
PM control measures were applied to the paved road emission estimates for the years 1995 and
1996. The control assumed was vacuum sweeping on paved roads twice per month to achieve an control
level of 79 percent. This control was applied to urban and rural roads in serious PM nonattainment areas
and to urban roads in moderate PM nonattainment areas. The penetration factor used varied by road type
and NAA classification (serious or moderate).
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-282 Fugitive Dust
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4.8.2.6 Calculation ofPM-2.5 Emissions from Paved and Unpaved Roads
EPA, Pechan, and Midwest Research Institute (MRI) performed an evaluation of more recent
particle size distribution information.1 That review indicated that the PM-2.5/PM-10 ratio for reentrained
road dust from paved and unpaved roads should be reduced from the older AP-42 particle size
multipliers. The table 4.8-1 shows the particle size ratios used to calculate PM-2.5 emissions from the
PM-10 emissions for these sources.
Thus, all PM-2.5 emission from paved and unpaved roads were calculated by multiplying the final
PM10 emissions at the county/road type/month level by 0.25 for paved roads and by 0.15 for unpaved
roads.
4.8.2.7 Other Fugitive Dust Sources
The other fugitive dust sources are from construction and mining and quarrying activities.
Construction sources are explained in section 4.8.2.7.1 and mining and quarrying methodology is detailed
in section 4.8.2.7.2.
4.8.2.7.1 Construction Activities —
The PM-10 emissions for the years 1985 through 1995, and the PM-2.5 emission for the years 1990
through 1995 were calculated from an emission factor, an estimate of the acres of land under
construction, and the average duration of construction activity.31 The acres of land under construction
were estimated from the dollars spent on construction.32 The PM-10 emission factor for the years 1985
through 1989 was calculated from the TSP emission factor for construction obtained from AP-42 and
data on the PM-10/TSP ratio for various construction activities.19 The PM-10 emission factor for the
years 1990 through 1995 was obtained from Improvement of Specific Emission Factors.33 The 1996
emissions were extrapolated from the 1995 emissions using the ratio between the number of residential
construction permits issued in 1996 and the number issued in 1995.32 A control efficiency was applied to
emissions for 1995 and 1996 for counties classified as PM nonattainment areas.34
4.8.2.7.1.1 1985- 1989 Emission Factor Equation. The following AP-42 particulate emission factor
equation (Equation 4.8-19) for heavy construction was used to determine regional PM-10 emissions from
construction activities for 1985 through 1989.
E = Tx$xfxmxP (Eq. 4.8-19)
where: E = PM-10 emissions
T = TSP emission factor (1.2 ton/acre of construction/month of activity)
$ = dollars spent on construction ($ million)
f = factor for converting dollars spent on construction to acres of construction (varies by
type of construction, acres/$ million)
m = months of activity (varies by type of construction)
P = dimensionless PM-10/TSP ratio (0.22).
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-283 Fugitive Dust
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4.8.2.7.1.2 1990 through 1995 Emission Factor Equation . Equation 4.8-20 is a variation of the
AP-42 particulate emission factor equation for heavy construction and was used to determine regional
PM-10 and PM-2.5 emissions from construction activities for 1990 through 1995. The PM-2.5 emission
factor used for the years 1990 through 1995 was the PM-10 emission factor multiplied by the particle size
adjustment factor of 0.2, shown in table 4.8-1. A control efficiency was applied to PM nonattainment
areas for 1995 and 1996.
E = P
f
\ -
(Eq. 4.8-20)
where: E =
P =
f =
m =
CE =
PM emissions
PM emission factor (ton/acre of construction/month of activity)
(PM-10 = 0.11; PM-2.5 = 0.022)
dollars spent on construction ($ million)
factor for converting dollars spent on construction to acres of construction (varies by
type of construction, acres/$ million)
months of activity (varies by type of construction)
control efficiency (percent)
4.8.2.7.1.2.1 Dollars spent on construction ($). Estimates of the dollars spent on the various types of
construction by EPA region for 1987 were obtained from the Census Bureau.35 The fraction of total U.S.
dollars spent in 1987 for each region for each construction type was calculated. Since values from the
Census Bureau are only available every five years, the Census dollars spent for the United States for
construction were normalized using estimates of the dollars spent on construction for the United States as
estimated by the F.W. Dodge32 corporation for the other years. This normalized Census value was
distributed by region and construction type using the above calculated fractions. An example of how this
procedure was applied for SIC 1521 (general contractor, residential building: single family) is shown in
Equation 4.8-21.
sic
. 4.8-21)
where:
$
1988
1987
Region I
SIC 1521
Nation
Census
Dodge
dollar amount of construction spent
year 1988
year 1987
U.S. EPA Region I
Standard Industrial Code for general contractor, residential building; single
family
United States
Census Bureau
F.W. Dodge
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-284
1985-1996 Methodology
Fugitive Dust
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4.8.2.7.1.2.2 Determination of construction acres (f). Information developed by Cowherd et al.31
determined that for different types of construction, the number of acres was proportional to dollars spent
on that type construction. This information (proportioned to constant dollars using the method
developed by Heisler36) was utilized along with total construction receipts to determine the total number
of acres of each construction type.
4.8.2.7.1.2.3 Months of construction (m). Estimates of the duration (in months) for each type
construction were derived from Cowherd et al.31
4.8.2.7.1.2.4 PM-10/TSP Ratio (P) (1985-1989). The PM-10/TSP ratio for construction activities was
derived from Midwest Research Institute [MRI].19 In MRI's report, the data in Table 9, "Net Particulate
Concentrations and Ratios" is cited from Kinsey et al.37 That table included the ratios of PM-10/TSP for
19 test sites for three different construction activities. MRI suggests averaging the ratios for the
construction activity of interest. Since Pechan was looking at total construction emissions from all
sources, Pechan averaged the PM-10/TSP ratios for all test sites and construction activities.
4.8.2.7.1.2.5 PM-10 andPM-2.5 Ratio (P) f 1990-1995). The PM-10 emission factor used for the
years 1990 through 1995 for construction activities was obtained from Improvement of Specific Emission
Factors.33 This study reported an emission factor of 0.11 ton PM-10/acre-month. This value is the
geometric mean of emission factors for 7 different sites considered in the study. Emission inventories for
the sites were prepared for the construction activities observed at each site. The PM-2.5 emission factor
used for the years 1990-1995 was the PM-10 emission factor (0.11 ton PM-10/acre-month) multiplied by
the particle size adjustment factor of 0.2, shown in table 4.8-1.
4.8.2.7.1.2.6 Control Efficiency (1990-1996}. A control efficiency was applied to emissions for 1995
and 1996 for counties classified as PM nonattainment areas.34 Therefore, the control efficiency for the
years 1990 through 1994 is zero for all counties. The PM-10 control efficiency used for 1995 and 1996
PM nonattainment areas is 62.5. The PM-2.5 control efficiency for these years and areas is 37.5.
4.8.2.7.1.2.7 County Distribution. Regional-level PM-10 estimates were distributed to the county-level
using county estimates of payroll for construction (SICs 15, 16, 17) from County Business Patterns.38
Equation 4.8-22 was used.
^ , r • • County Construction Payroll n . , „ . .
County Emissions = x Regional Emissions (Eq. 4.8-22)
Regional Construction Payroll
4.8.2.7.2 Mining and Quarrying —
The PM-10 emissions for the years 1985 through 1995 were the sum of the emissions from metallic
ore, nonmetallic ore, and coal mining operations. The 1996 PM-10 emissions were produced through a
linear projection of the emissions for the years 1990 through 1995.The PM-2.5 emissions for the years
1990 through 1996 were determined by multiplying the PM-10 emissions for that year by the particle size
adjustment factor of 0.2, represented in table 4.8-1.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-285 Fugitive Dust
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PM-10 emissions estimates from mining and quarrying operations include only the following sources
of emissions: 1) overburden removal, 2) drilling and blasting, 3) loading and unloading and 4) overburden
replacement. Transfer and conveyance operations, crushing and screening operations and storage were
not included. Travel on haul roads was also omitted. These operations were not included in order to be
consistent with previous TSP emissions estimates from these sources (i.e., Evans and Cooper39), because
they represent activities necessary for ore processing, but not necessary for actual extraction of ore from
the earth, and because these activities are the most likely to have some type of control implemented.
Pechan's emissions of mining and quarrying operations is a summation of three types of mining
(metallic, non-metallic and coal) which are expressed in Equation 4.8-23.
E = Em+ En+ Ec (Eq. 4.8-23)
where: E = PM-10 emissions from mining and quarrying operations
Em = PM-10 emissions from metallic mining operations
En = PM-10 emissions from non-metallic mining operations
Ec = PM-10 emissions from coal mining operations
4.8.2.7.2.1 Determination of Correction Parameters. It was assumed that, for the four operations
listed above, the TSP emission factors utilized in developing copper ore processing Emission Trends
estimates applied to all metallic minerals. PM-10 emission factors were determined for each of the four
operations listed above by making the following assumptions. Table 11.2.3-2 of AP-4210 was used to
determine that 35 percent of overburden removal TSP emissions were PM-10. For drilling and blasting
and truck dumping, 81 percent of the TSP emissions were assumed to be PM-10.40 For loading
operations, 43 percent of TSP emissions were assumed to be PM-10.40
Non-metallic mineral emissions were calculated by assuming that the PM-10 emission factors for
western surface coal mining41 applied to all non-metallic minerals.
Coal mining includes two additional sources of PM-10 emissions compared to the sources
considered for metallic and non-metallic minerals. The two additional sources are overburden
replacement and truck loading and unloading of that overburden. Pechan assumed that tons of
overburden was equal to ten times the tons of coal mined.39
4.8.2.7.2.2 Activity Data. The regional metallic and non-metallic crude ore handled at surface mines
for 1985 through 1995 were obtained from the U.S. Geological Survey.42 Some state-level estimates are
withheld by the U.S. Geological Survey to avoid disclosing proprietary data. Known distributions from
past years were used to estimate these withheld data.
The regional production figures for surface coal mining operations were obtained from the Coal
Industry Annual43 for 1985 through 1995.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-286 Fugitive Dust
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4.8.2. 7.2.2.1 Metallic Mining Operations. The following PM-10 emissions estimate equation
(Equation 4.8-24) calculates the emissions from overburden removal, drilling and blasting, and loading
and unloading during metallic mining operations.
x EFo + B x EFb + EF, + EFd (Eq. 4.8-24)
where: A^ = metallic crude ore handled at surface mines (1000 short tons)
EF0 = PM-10 open pit overburden removal emission factor for copper ore processing
(Ibs/ton)
B = fraction of total ore production that is obtained by blasting at metallic mines
EFb = PM-10 drilling/blasting emission factor for copper ore processing (Ibs/ton)
E?! = PM-10 loading emission factor for copper ore processing (Ibs/ton)
EFd = PM-10 truck dumping emission factor for copper ore processing (Ibs/ton)
4.8.2. 7.2.2.2 Non-metallic Mining Operations. The following PM-10 emissions estimate equation
(Equation 4.8-25) calculates the emissions from overburden removal, drilling and blasting, and loading
and unloading during non-metallic mining operations.
En = An x (EFv + DxEFr + EFa+ '/2x (EF e + EF^ (Eq. 4.8-25)
where: A^ = non-metallic crude ore handled at surface mines (1000 short tons)
EFV = PM-10 open pit overburden removal emission factor at western surface coal
mining operations (Ibs/ton)
D = fraction of total ore production that is obtained by blasting at non-metallic
mines
EFr = PM-10 drilling/blasting emission factor at western surface coal mining
operations (Ibs/ton)
EFa = PM-10 loading emission factor at western surface coal mining operations
(Ibs/ton)
EFe = PM-10 truck unloading: end dump-coal emission factor at western surface
coal mining operations (Ibs/ton)
EFt = PM-10 truck unloading: bottom dump-coal emission factor at western
surface coal mining operations (Ibs/ton)
4.8.2. 7.2.2.3 Coal Mining. The following PM-10 emissions estimate equation (Equation 4.8-26)
calculates the emissions from overburden removal, drilling and blasting, loading and unloading, and
overburden replacement during coal mining operations.
Ec = Ac x (10 x (EFto + EFor + EFd) + EFv + EFr + EFa + '/2x (EF R + EF$ (Eq. 4.8-26)
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-287 Fugitive Dust
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where: Ac = coal production at surface mines (1000 short tons)
Efto = PM-10 emission factor for truck loading overburden at western surface coal
mining operations (Ibs/ton of overburden)
Efor = PM-10 emission factor for overburden replacement at western surface coal
mining operations (Ibs/ton of overburden)
Efdt = PM-10 emission factors for truck unloading: bottom dump-overburden at
western surface coal mining operations (Ibs/ton of overburden)
EFV = PM-10 open pit overburden removal emission factor at western surface coal
mining operations (Ibs/ton)
EFr = PM-10 drilling/blasting emission factor at western surface coal mining
operations (Ibs/ton)
EFa = PM-10 loading emission factor at western surface coal mining operations
(Ibs/ton)
EFe = PM-10 truck unloading: end dump-coal emission factor at western surface
coal mining operations (Ibs/ton)
EFt = PM-10 truck unloading: bottom dump-coal emission factor at western
surface coal mining operations (Ibs/ton)
4.8.2.7.2.3 1996 Emissions Methodology. For the year 1996 PM-10 emissions from mining and
quarrying operations were projected based on linear regression of the previous 5 years. Pechan was
unable to obtain regional metallic and non-metallic crude ore handled at surface mines for 1996. The
U.S. Geological Survey publishes summary statistics on mining and quarrying with a one year delay.
4.8.2.7.2.4 County Distribution. Regional-level emissions were distributed equally among counties
within each region (Equation 4.8-27).
County Emissions = - x Regional Emissions (Eq 4 8-27)
Number of Counties in Region
4. 8. 2. 8 Grown Emissions
Point source fugitive dust sources in the 1990 NET inventory were wind erosion, unpaved roads,
and paved roads. (A complete list of source categories is presented in table 4.8-9.) Emissions from these
sources were grown from the 1990 NET inventory based on BEA earnings. The cattle feedlot emissions
estimated above were also grown from year to year.
4.8.2.8.1 Emissions Calculations —
Base year controlled emissions are projected to the inventory year using Equation 4.8-28.
CE. = CEB¥ + (CEBY x £G.) (Eq. 4.8-28)
where: CE; = Controlled Emissions for inventory year I
CEBY = Controlled Emissions for base year
EG; = Earnings Growth for inventory year I
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-288 Fugitive Dust
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Earnings growth (EG) is calculated as shown in Equation 4.8-29.
DAT
EGt = 1- ——i- (Eq. 4.8-29)
L)A1BY
where: DAT; = Earnings data for inventory year I
DATBY = Earnings data in the base year
4.8.2.8.2 1990 Emissions —
The 1990 National Emission Trends is based primarily on state data, with the 1990 interim data
filling in the gaps. The database houses U.S. annual and average summer day emission estimates for the
50 states and the District of Columbia. Seven pollutants (CO, NOX, VOC, SO2, PM-10, PM-2.5, and
NH3) were estimated in 1990. The state data were extracted from three sources, the OTAG inventory,
the GCVTC inventory, and AIRS/FS.
Since EPA did not receive documentation on how these inventories were developed, this section
only describes the effort to collect the data and any modifications or additions made to the data.
4.8.2.8.2.1 OTAG. The OTAG inventory for 1990 was completed in December 1996. The database
houses emission estimates for those states in the Super Regional Oxidant A (SUPROXA) domain. The
estimates were developed to represent average summer day emissions for the ozone pollutants (VOC,
NOX, and CO). This section gives a background of the OTAG emission inventory and the data collection
process.
4.8.2.8.2.1.1 Inventory Components. The OTAG inventory contains data for all states that are partially
or fully in the SUPROXA modeling domain. The SUPROXA domain was developed in the late 1980s as
part of the EPA regional oxidant modeling (ROM) applications. EPA had initially used three smaller
regional domains (Northeast, Midwest, and Southeast) for ozone modeling, but wanted to model the full
effects of transport in the eastern United States without having to deal with estimating boundary
conditions along relatively high emission areas. Therefore, these three domains were combined and
expanded to form the Super Domain. The western extent of the domain was designed to allow for
coverage of the largest urban areas in the eastern United States without extending too far west to
encounter terrain difficulties associated with the Rocky Mountains. The Northern boundary was
designed to include the major urban areas of eastern Canada. The southern boundary was designed to
include as much of the United States as possible, but was limited to latitude 26 °N, due to computational
limitations of the photochemical models. (Emission estimates for Canada were not extracted from OTAG
for inclusion in the NET inventory.)
The current SUPROXA domain is defined by the following coordinates:
North: 47.00°N East: 67.00°W
South: 26.00°N West: 99.00°W
Its eastern boundary is the Atlantic Ocean and its western border runs from north to south through North
Dakota, South Dakota, Nebraska, Kansas, Oklahoma, and Texas. In total, the OTAG Inventory
completely covers 37 states and the District of Columbia.
National Air Pollutant Emission Trends 1985-1996 Methodology
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The OTAG inventory is primarily an ozone precursor inventory. It includes emission estimates of
VOC, NOX, and CO for all applicable source categories throughout the domain. It also includes a small
amount of SO2 and PM-10 emission data that was sent by states along with their ozone precursor data.
No quality assurance (QA) was performed on the SO2 and PM-10 emission estimates for the OTAG
inventory effort.
Since the underlying purpose of the OTAG inventory is to support photochemical modeling for
ozone, it is primarily an average summer day inventory. Emission estimates that were submitted as
annual emission estimates were converted to average summer day estimates using operating schedule data
and default temporal profiles and vice versa.
The OTAG inventory is made up of three major components: (1) the point source component,
which includes segment/pollutant level emission estimates and other relevant data (e.g., stack parameters,
geographic coordinates, and base year control information) for all stationary point sources in the domain;
(2) the area source component, which includes county level emission estimates for all stationary area
sources and non-road engines; and (3) the on-road vehicle component, which includes county/roadway
functional class/vehicle type estimates of VMT and MOBILESa input files for the entire domain.
4.8.2.8.2.1.2 Interim Emissions Inventory (OTAG Default). The primary data sources for the OTAG
inventory were the individual states. Where states were unable to provide data, the 1990 Interim
Inventory 44 was used for default inventory data.
4.8.2.8.2.1.3 State Data Collection Procedures. Since the completion of the Interim Inventory in 1992,
many states had completed 1990 inventories for ozone nonattainment areas as required for preparing
SIPs. In addition to these SIP inventories, many states had developed more comprehensive 1990
emission estimates covering their entire state. Since these state inventories were both more recent and
more comprehensive than the Interim Inventory, a new inventory was developed based on state inventory
data (where available) in an effort to develop the most accurate emission inventory to use in the OTAG
modeling.
On May 5, 1995, a letter from John Seitz (Director of EPA's Office of Air Quality Planning and
Standards [OAQPS]) and Mary Gade (Vice President of ECOS) to State Air Directors, states were
requested to supply available emission inventory data for incorporation into the OTAG inventory.45
Specifically, states were requested to supply all available point and area source emissions data for VOC,
NOX, CO, SO2, and PM-10, with the primary focus on emissions of ozone precursors. Some emission
inventory data were received from 36 of the 38 states in the OTAG domain. To minimize the burden to
the states, there was no specified format for submitting state data. The majority of the state data was
submitted in one of three formats:
1) an Emissions Preprocessor System Version 2.0 (EPS2.0) Workfile
2) an ad hoc report from AIRS/FS
3) data files extracted from a state emission inventory database
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4.8.2.8.2.1.4 State Data Incorporation Procedures/Guidelines. The general procedure for incorporating
state data into the OTAG Inventory was to take the data "as is" from the state submissions. There were
two main exceptions to this policy. First, any inventory data for years other than 1990 was backcast to
1990 using BEA Industrial Earnings data by state and two-digit SIC code. This conversion was required
for five states that submitted point source data for the years 1992 through 1994. All other data submitted
were for 1990.
Second, any emission inventory data that included annual emission estimates but not average
summer day values were temporally allocated to produce average summer day values. This temporal
allocation was performed for point and area data supplied by several states. For point sources, the
operating schedule data, if supplied, were used to temporally allocate annual emissions to average
summer weekday using the following equation:
EMISSIONSASD = EMISSIONSANNUAL * SUMTHRU * 1/(13 * DPW) (Eq. 4.8-30)
where:
EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
SUMTHRU = summer throughput percentage
DPW = days per week in operation
If operating schedule data were not supplied for the point source, annual emissions were temporally
allocated to an average summer weekday using EPA's default Temporal Allocation file. This computer
file contains default seasonal and daily temporal profiles by SCC. The following equation was used:
EMISSIONSASD = EMISSIONSANNUAL I (SUMFACSCC * WDFACSCC) (Eq. 4.8-31)
where:
EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
SUMFACSCC = default summer season temporal factor for SCC
WDFACSCC = default summer weekday temporal factor for SCC
There were a small number of SCCs that were not in the Temporal Allocation file. For these SCCs,
average summer weekday emissions were assumed to be the same as those for an average day during the
year and were calculated using the following equation:
EMISSIONSASD = EMISSIONSANNUAL I 365 (Eq. 4.8-32)
where:
National Air Pollutant Emission Trends 1985-1996 Methodology
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EMISSIONSASD = average summer day emissions
EMISSIONSANNUAL = annual emissions
4.8.2.8.2.1.5 Point. For stationary point sources, 36 of the 38 states in the OTAG domain supplied
emission estimates covering the entire state. Data from the Interim Inventory were used for the two
states (Iowa and Mississippi) that did not supply data. Most states supplied 1990 point source data,
although some states supplied data for later years because the later year data reflected significant
improvements over their 1990 data. Inventory data for years other than 1990 were backcast to 1990
using BEA historical estimates of industrial earnings at the 2-digit SIC level. Table 4.8-10 provides a
brief description of the point source data supplied by each state.
4.8.2.8.2.1.6 Area. For area sources, 17 of the 38 states in the OTAG domain supplied 1990
emission estimates covering the entire state, and an additional nine states supplied 1990 emission
estimates covering part of their state (partial coverage was mostly in ozone nonattainment areas). Interim
Inventory data were the sole data source for 12 states. Where the area source data supplied included
annual emission estimates, the default temporal factors were used to develop average summer daily
emission estimates. Table 4.8-11 provides a brief description of the area source data supplied by each
state.
4.8.2.8.2.1.7 Rule Effectiveness. For the OTAG inventory, states were asked to submit their best
estimate of 1990 emissions. There was no requirement that state-submitted point source data include rule
effectiveness for plants with controls in place in that year. States were instructed to use their judgment
about whether to include rule effectiveness in the emission estimates. As a result, some states submitted
estimates that were calculated using rule effectiveness, while other states submitted estimates that were
calculated without using rule effectiveness.
The use of rule effectiveness in estimating emissions can result in emission estimates that are much
higher than estimates for the same source calculated without using rule effectiveness, especially for
sources with high control efficiencies (95 percent or above). Because of this problem, there was concern
that the OTAG emission estimates for states that used rule effectiveness would be biased to larger
estimates relative to states that did not include rule effectiveness in their computations.
To test if this bias existed, county level maps of point source emissions were developed for the
OTAG domain. If this bias did exist, one would expect to see sharp differences at state borders between
states using rule effectiveness and states not using rule effectiveness. Sharp state boundaries were not
evident in any of the maps created. Based on this analysis, it was determined that impact of rule
effectiveness inconsistencies was not causing large biases in the inventory.
4.8.2.8.2.2 Grand Canyon Visibility Transport Commission Inventory. The GCVTC inventory
includes detailed emissions data for eleven states: Arizona, California, Colorado, Idaho, Montana,
Nevada, New Mexico, Oregon, Utah, Washington, and Wyoming.46 This inventory was developed by
compiling and merging existing inventory databases. The primary data sources used were state
inventories for California and Oregon, AIRS/FS for VOC, NOX, and SO2 point source data for the other
nine states, the 1990 Interim Inventory for area source data for the other nine states, and the 1985
National Air Pollutant Emission Trends 1985-1996 Methodology
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NAPAP inventory for NH3 and TSP data. In addition to these existing data, the GCVTC inventory
includes newly developed emission estimates for forest wildfires and prescribed burning.
After a detailed analysis of the GCVTC inventory, it was determined that the following portions of
the GCVTC inventory would be incorporated into the PM inventory:
• complete point and area source data for California
• complete point and area source data for Oregon
• forest wildfire data for the entire eleven state region
• prescribed burning data for the entire eleven state region
State data from California and Oregon were incorporated because they are complete inventories
developed by the states and are presumably based on more recent, detailed and accurate data than the
Interim Inventory (some of which is still based on the 1985 NAPAP inventory). The wildfire data in the
GCVTC inventory represent a detailed survey of forest fires in the study area and are clearly more
accurate than the wildfire data in the Interim Inventory. The prescribed burning data in the GCVTC
inventory are the same as the data in the Interim Inventory at the state level, but contain more detailed
county-level data.
Non-utility point source emission estimates in the GCVTC inventory from states other than
California and Oregon came from AIRS/FS. Corrections were made to this inventory to the VOC and
PM emissions. The organic emissions reported in GCVTC inventory for California are total organics
(TOG). These emissions were converted to VOC using the profiles from EPA's SPECIATE47 database.
4.8.2.8.2.3 AIRS/FS. SO2 and PM-10 (or PM-10 estimated from TSP) sources of greater than
250 tons per year as reported to AIRS/FS that were not included in either the OTAG or GCVTC
inventories were appended to the NET inventory. The data were extracted from AIRS/FS using the data
criteria set listed in table 4.8-12. The data elements extracted are also listed in table 4.8-12. The data
were extracted in late November 1996. It is important to note that estimated emissions were extracted.
4.8.2.8.2.4 Data Gaps. As stated above, the starting point for the 1990 NET inventory is the
OTAG, GCVTC, AIRS, and 1990 Interim inventories. Data added to these inventories include estimates
of SO2, PM-10, PM-2.5, and NH3, as well as annual or ozone season daily (depending on the inventory)
emission estimates for all pollutants. This section describes the steps taken to fill in the gaps from the
other inventories.
4.8.2.8.2.4.1 SO2 and PM Emissions. For SO2 and PM-10, state data from OTAG were used where
possible. (The GCVTC inventory contained SO2 and PM annual emissions.) In most cases, OTAG data
for these pollutants were not available. For point sources, data for plants over 250 tons per year for SO2
and PM-10 were added from AIRS/FS. The AIRS/FS data were also matched to the OTAG plants and
the emissions were attached to existing plants from the OTAG data where a match was found. Where no
match was found to the plants in the OTAG data, new plants were added to the inventory. For OTAG
plants where there were no matching data in AIRS/FS and for all area sources of SO2 and PM-10,
emissions were calculated based on the emission estimates for other pollutants.
National Air Pollutant Emission Trends 1985-1996 Methodology
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The approach to developing SO2 and PM-10 emissions from unmatched point and area sources
involved using uncontrolled emission factor ratios to calculate uncontrolled emissions. This method used
SO2 or PM-10 ratios to NOX. NOX was the pollutant utilized to calculate the ratio because (1) the types
of sources likely to be important SO2 and PM-10 emitters are likely to be similar to important NOX
sources and (2) the generally high quality of the NOX emissions data. Ratios of SO2/NOX and PM-10/NOX
based on uncontrolled emission factors were developed. These ratios were multiplied by uncontrolled
NOX emissions to determine either uncontrolled SO2 or PM-10 emissions. Once the uncontrolled
emissions were calculated, information on VOC, NOX, and CO control devices was used to determine if
they also controlled SO2 and/or PM-10. If this review determined that the control devices listed did not
control SO2 and/or PM-10, plant matches between the OTAG and Interim Inventory were performed to
ascertain the SO2 and PM-10 controls applicable for those sources. The plant matching component of
this work involved only simple matching based on information related to the state and county FIPS code,
along with the plant and point IDs.
There was one exception to the procedures used to develop the PM-10 point source estimates. For
South Carolina, PM-10 emission estimates came from the Interim Inventory. This was because South
Carolina had no PM data in AIRS/FS for 1990 and using the emission factor ratios resulted in
unrealistically high PM-10 emissions.
There were no PM-2.5 data in either OTAG or AIRS/FS. Therefore, the point and area PM-2.5
emission estimates were developed based on the PM-10 estimates using source-specific uncontrolled
particle size distributions and particle size specific control efficiencies for sources with PM-10 controls.
To estimate PM-2.5, uncontrolled PM-10 was first estimated by removing the impact of any PM-10
controls on sources in the inventory. Next, the uncontrolled PM-2.5 was calculated by multiplying the
uncontrolled PM-10 emission estimates by the ratio of the PM-2.5 particle size multiplier to the PM-10
particle size multiplier. (These particle size multipliers represent the percentage to total particulates
below the specified size.) Finally, controls were reapplied to sources with PM-10 controls by multiplying
the uncontrolled PM-2.5 by source/control device particle size specific control efficiencies.
4.8.2.8.3 Growth Indicators, 1985-1989 —
The changes in the point and area source emissions were equated with the changes in historic
earnings by state and industry. Emissions from each point source in the 1985 NAPAP inventory were
projected to the years 1985 through 1990 based on the growth in earnings by industry (two-digit SIC
code). Historical annual state and industry earnings data from BEA's Table SA-548 were used to
represent growth in earnings from 1985 through 1990.
The 1985 through 1990 earnings data in Table SA-5 are expressed in nominal dollars. To estimate
growth, these values were converted to constant dollars to remove the effects of inflation. Earnings data
for each year were converted to 1982 constant dollars using the implicit price deflator for PCE.49 The
PCE deflators used to convert each year's earnings data to 1982 dollars are:
National Air Pollutant Emission Trends 1985-1996 Methodology
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Year 1982 PCE Deflator
1985 111.6
1987 114.8
1988 124.2
1989 129.6
1990 136.4
Several BEA categories did not contain a complete time series of data for the years 1985 through
1990. Because the SA-5 data must contain 1985 earnings and earnings for each inventory year (1985
through 1990) to be useful for estimating growth, a log linear regression equation was used where
possible to fill in missing data elements. This regression procedure was performed on all categories that
were missing at least one data point and which contained at least three data points in the time series.
Each record in the inventory was matched to the BEA earnings data based on the state and the two-
digit SIC. Table 4.8-13 shows the BEA earnings category used to project growth for each of the two-
digit SICs found in the 1985 NAPAP Emission Inventory. No growth in emissions was assumed for all
point sources for which the matching BEA earnings data were not complete. Table 4.8-13 also shows the
national average growth and earnings by industry from Table SA-5.
4.8.2.8.4 Growth Indicators, 1991 through 1996 —
The 1991 through 1996 area source emissions were grown in a similar manner as the 1985 through
1989 estimates, except for using a different base year inventory. The point source inventory was also
grown for those states that did not want their AIRS/FS data used. (See Table 14 for a list of states that
chose AIRS/FS.) For those states requesting that EPA extract their data from AIRS/FS, the years 1990
through 1995 were downloaded from the EPA IBM Mainframe. The 1996 emissions were not extracted
since states are not required to have the 1996 data uploaded into AIRS/FS until July 1997.
4.8.2.8.4.1 Grown Estimates. The 1991 through 1996 point and area source emissions were
grown using the 1990 NET inventory as the basis. The algorithm for determining the estimates is
detailed in section 4.8.2.8. The 1990 through 1996 SEDS and BEA data are presented in tables 4.8-15
and 4.8-16. The 1996 BEA and SEDS data were determined based on linear interpretation of the 1988
through 1995 data. Point sources were projected using the first two digits of the SIC code by state.
Area source emissions were projected using either BEA or SEDS. Table 4.8-17 lists the SCC and the
source for growth.
The 1990 through 1996 earnings data in BEA Table SA-5 (or estimated from this table) are
expressed in nominal dollars. In order to be used to estimate growth, these values were converted to
constant dollars to remove the effects of inflation. Earnings data for each year were converted to 1992
constant dollars using the implicit price deflator for PCE. The PCE deflators used to convert each year's
earnings data to 1992 dollars are:
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Year 1992 PCE Deflator
1990 93.6
1991 97.3
1992 100.0
1993 102.6
1994 104.9
1995 107.6
1996 109.7
4.8.2.8.4.2 AIRS/FS. Several states responded to EPA's survey and requested that their 1991
through 1995 estimates reflect their emissions as reported in AIRS/FS. The list of these states, along
with the years available in AIRS/FS is given in table 4.8-14.
As noted in table 4.8-14, several states did not report emissions for all pollutants for all years for the
1990 to 1995 time period. To fill these data gaps, EPA applied linear interpolation or extrapolated the
closest two years worth of emissions at the plant level. If only one year of emissions data were available,
the emission estimates were held constant for all the years. The segment-SCC level emissions were
derived using the average split for all available years. The non-emission data gaps were filled by using the
most recent data available for the plant.
Many states do not provide PM-10 emissions to AIRS. These states' TSP emissions were converted
to PM-10 emissions using uncontrolled particle size distributions and AP-42 derived control efficiencies.
The PM-10 emissions are then converted to PM-2.5 in the same manner as described in section
4.8.2.8.2.4.1. The State of South Carolina provided its own conversion factor for estimating PM-10
from TSP.50
4.8.9 References
1. Memorandum from Chatten Cowherd of Midwest Research Institute, to Bill Kuykendal of the U.S.
EPA, Emission Factors and Inventories Group, and W.R. Barnard of E.H. Pechan and Associates,
Inc., September 1996.
2. Gillette, D.A., and R. Passi, "Modeling Dust Emission Caused by Wind Erosion," Journal of
Geophysical Research, Vol. 93, #D11, pp. 14233-14242, November, 1988.
3. Gillette, D.A. personal communication with W.R. Barnard of E. H. Pechan & Associates, Durham,
NC. 1991.
4. Local Climatological Data, National Climatic Data Center, Monthly, 1985-1996.
5. Soil Conservation Service Soil Geography - NATSGO Map Series Dominant Surface Soil Texture,
Data Source: USDA-SCS 1982 NRI & Soil-5 Databases & 1984 MLRA Map: U.S. Department of
Agriculture, Sept 1988: L.D. Spivey, Jr. & R.L. Glenn. 1988.
6. U.S. Land Use Summary, from the Feed Grains and Oil Seeds Section of ASCS-U.S. Department of
Agriculture, 1985-1996, annual.
National Air Pollutant Emission Trends 1985-1996 Methodology
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7. Usual Planting and Harvesting Dates for U.S. Field Crops, U.S. Department of Agriculture,
Statistical Reporting Service, Agriculture Handbook Number 628, 1984.
8. "1990 Census of Population and Housing," county data file, Bureau of the Census, U.S.
Department of Commerce, Washington, DC, 1994.
9. National Crop Residue Management Survey, Conservation Technology Information Center,
1990-1996.
10. "Compilation of Air Pollutant Emission Factors," 4th Edition, EPA Publication AP-42, including
Supplements A and B, U.S. Environmental Protection Agency, Research Triangle Park, NC, 1988.
11. Major Land Resource Areas of the United States Adjusted to County Boundaries for Compilations
of Statistical Data, U.S. Department of Soil Conservation Service. USGS National Atlas Base.
Agricultural Handbook 296. 1978.
12. Brady, Nyle C., The Nature & Properties of Soils, 8th Edition, New York, MacMillan, 1974. p 48.
13. Cowherd, C.C. Jr., K. Axtell, C.M. Guenther, & G.A. Jutze, Development of Emission Factors for
Fugitive Dust Sources. U.S. Environmental Protection Agency, Research Triangle Park, NC. June
1974. EPA-450/3-74-037.
14. "1987 Census of Agriculture, Volume 1: Geographic Area Series," county data file, Bureau of the
Census, U.S. Department of Commerce, Washington, DC, 1987.
15. Shimp, D.R. Campbell, S.G., and Francis, S.R. "Spatial Distribution of PM-10 emissions from
Agricultural Tillingin the San Joaquin Valley," California Air Resources Board, 1996.
16. Woodard, Kenneth R. "Agricultural Activities Influencing Fine Particulate Matter Emissions,"
Midwest Research Institute, March 1996.
17. Cowherd, C.C., Midwest Research Institute, personal communication with W.R. Barnard of E.H.
Pechan and Associates, Inc., Durham, NC, 1997.
18. Towery, D., Conservation Information Technology Center (CTIC), Purdue University, personal
communication with W.R. Barnard of E.H. Pechan and Associates, Inc., Durham, NC, 1997.
19. Midwest Research Institute, "Gap Filling PM-10 Emission Factors for Selected Open Area Dust
Sources," U.S. EPA Rept. No. EPA-450/4-88-003, February, 1988.
20. 1992 Census of Agriculture - Geographic Area Series 1A, IB, and 1C, (CD-ROM), U.S.
Department of Commerce, Bureau of Census, Washington, DC, 1992.
21. Asman, William, A.H., Ammonia Emissions in Europe: Updated Emission and Emission Variations,
National Institute of Public Health and Environmental Protection, Biltoven, The Netherlands, May
1992.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-297 Fugitive Dust
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22. Commercial Fertilizers Data -1989 and 1990, National Fertilizer Research Center, Tennessee
Valley Authority, Muscle Shoals, AL, 1990.
23. "Compilation of Air Pollutant Emission Factors," AP-42 with Supplement F, U.S. Environmental
Protection Agency, Office of Air Quality Planning and Standards, Research Triangle Park, NC, July
1993.
24. Stensland, G., Illinois State Water Survey, personal communication with W. Barnard of E.H. Pechan
& Associates, Inc., Durham, NC, 1989.
25. 1987 Census of Transportation: Truck Inventory and Use Survey - United States, TC87-T-52, U.S.
Department of Commerce, Bureau of Census, August 1990.
26. MVMA Motor Vehicle Facts and Gifures'91, Motor Vehicle Manufacturers Association, Detroit,
MI, 1991.
27. 1991 Market Data Book, Automotive News, Grain Communications, Inc., May 19, 1991.
28. Highway Statistics, ISBN 0-16-035995-3, U.S. Department of Transportation, Federal Highway
Administration, annually from Ocotober 1990 to 1996.
29. "Rural and Urban Land Area by County Data," Bureau of Census, CPHL79.DAT, Query Request by
E.H. Pechan & Associates, Inc., 1992.
30. "Draft User's Guide to PART5: A Program for Calculating Particle Emissions from Motor
Vehicles," EPA-AA-AQAB-94-2, U.S. Environmental Protection Agency, Office of Mobile
Sources, Ann Arbor, MI, July 1994.
31. Cowherd, C. C. Jr., C. Guenther and D. Wallace, Emission Inventory of Agricultural Tilling,
Unpaved Roads and Airstrips and Construction Sites, MRI, U.S. EPA Rept. No. EPA-450/3-74-
085, NTIS PB-238 919, November 1974.
32. Construction Review. Bureau of the Census, U.S. Department of Commerce, Washington, DC,
annual
33. Improvement of Specific Emission Factors. Midwest Research Institute, BACM Project No. 1,
March 1996.
34. 2010 Clean Air Act Baseline Emission Projections for the Integrated Ozone, Particulate Matter, and
Regional Haze Cost Analysis. E.H. Pechan & Associates, Inc., May 1997.
35. U.S. DOC, Bureau of Census, Industrial Series Census of Construction, Table 10, Value of
Construction Work for Establishments with Payroll by Location of Construction Work. 1987.
36. Heisler, S.L. "Interim Emissions Inventory for Regional Air Quality Studies," Electric Power
Research Institute Report EPRI EA-6070, November 1988.
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-298 Fugitive Dust
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37. Kinsey, J.S., et al.. Study of Construction Related Dust Control, Contract No. 32200-07976-01,
Minnesota Pollution Control Agency, Roseville, MN, April 19, 1983.
38. "1990 County Business Patterns," Bureau of the Census, U.S. Department of Commerce,
Washington, DC, 1992.
39. Evans, J.S. and D.W. Cooper, "An Inventory of Particulate Emissions from Open Sources," Journal
Air Pollution Control Association, Vol. 30, #12, pp. 1298-1303, December 1980.
40. U.S. EPA, "Generalized Particle Size Distributions for Use in Preparing Size-Specific Parti culate
Emissions Inventories," U.S. EPA Kept. No. EPA-450/4-86-013, July 1986.
41. AIRS Facility Subsystem Source Classification Codes and Emission Factor Listing for Criteria Air
Pollutants. EPA-450/4-90-003. Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. March 1990.
42. Correspondence with Jean Moore of the US Geological Survey, U.S. Department of Interior,.
March 1997.
43. "Coal Industry Annual." DOE/EIA-0584, U.S. Department of Energy, November, 1985-1996.
44. Regional Interim Emission Inventories (1987-1991), Volume I: Development Methodologies, EPA-
454/R-23-021a, U.S. Environmental Protection Agency, Office of Air Quality Planning and
Standards, Research Triangle Park, NC. May 1993.
45. Seitz, John, U.S. Environmental Protection Agency, Research Triangle Park, NC, Memorandum to
State Air Directors. May 5, 1995.
46. An Emission Inventory for Assessing Regional Haze on the Colorado Plateau, Grand Canyon
Visibility Transport Commission, Denver, CO. January 1995.
47. Volatile Organic Compound (VOC)/Particulate Matter (PM) Speciation Data System (SPECIATE)
User's Manual, Version 1.5, Final Report, Radian Corporation, EPA Contract No. 68-DO-0125,
Work Assignment No. 60, Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC. February 1993.
48. Table SA-5 — Total Personal Income by Major Sources 1969-1990. Data files. Bureau of
Economic Analysis, U.S. Department of Commerce, Washington, DC. 1991.
49. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC. 1988, 1987, 1988, 1989, 1990, 1991.
50. Internet E-mail from J. Nuovo to J. Better of the Department of Health and Environmental Control
(DHEC), Columbia, South Carolina, entitled Total Suspended Particulate (TSP)/PM-10 Ratio.
Copy to P. Carlson, E.H. Pechan & Associates, Inc., Durham, NC. April 10, 1997.
National Air Pollutant Emission Trends 1985-1996 Methodology
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Table 4.8-1. Particle Size Ratios
Source Category Ratio of PM-2.5 to PM-10
Wind Erosion - Agricultural Land 0.15
Agricultural Crops 0.20
Agricultural Livestock 0.15
Wind Erosion - Non-Agricultural Land 0.15
Paved Roads 0.25
Unpaved Roads 0.15
Construction Activities 0.20
Mining and Quarrying 0.20
Table 4.8-2. Silt Content by Soil Type, 1985 to 1989
Soil Type
Silt Loam
Sandy Loam
Sand
Loamy Sand
Clay
Clay Loam
Organic Material
Loam
Silt Content (%)
78
33
12
12
75
75
10-82
60
Table 4.8-3. Silt Content by Soil Type, 1990 to 1996
Soil Type
Silt Loam 52
Sandy Loam 33
Sand 12
Loamy Sand 12
Clay 29
Clay Loam 29
Organic Material 10-82
Loam 40
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-300 Fugitive Dust
-------
Table 4.8-4. Number of Tillings by Crop Type
Number of Tillings
Crop Conservational Use Conventional Use
Corn 2 6
Spring Wheat 1 4
Rice 5 5
Fall-Seeded Small Grain 3 5
Soybeans 1 6
Cotton 5 8
Sorghum 1 6
Forage 3 3
Permanent Pasture 1 1
Other Crops 3 3
Fallow 1 1
Annual Conservation Use (No method, not used after 1995; number of tillings = 1)
Table 4.8-5. Livestock Operations Ammonia Emission Factors
Emission Factor
Category AMS SCC (Ib NH /Head)
Cattle and Calves
Pigs and Hogs
Poultry
Sheep
Horses
Goats
Mink
2805020000
2805025000
2805030000
2805040000
2710020030
2805045001
2205045002
50.5
20.3
0.394
7.43
26.9
14.1
1.28
Table 4.8-6 Speeds Modeled for Unpaved Roads
Rural Roads Speed (mph) Urban Roads Speed (mph)
Minor Arterial 39 Other Principal Arterial 20
Major Collector 34 Minor Arterial 20
Minor Collector 30 Collector 20
Local 30 Local 20
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-301 Fugitive Dust
-------
Table 4.8-7 Assumed Values for Average Daily Traffic Volume by Volume Group
Vehicles Per Day Per Mile
Volume Category for Rural Roads Less than 50 50-199 200-499 500 and over
Assumed AD TV Value for Rural
Roads
125"
350"
550"
Volume Category for Urban Roads Less than 200 200-499 500-1999 2000 and over
Assumed ADTV Value for Urban
Roads
20*
350"
1250"
2200"
NOTE(S): *10% of volume group's maximum range endpoint.
"Average of volume group's range endpoints.
***110% of volume group's minimum.
Table 4.8-8. PM-2.5 to PM-10 Ratios for Paved and Unpaved Roads
Source Category
Ratio of PM-2.5 to PM-10
Paved Roads
Unpaved Roads
0.25
0.15
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-302
1985-1996 Methodology
Fugitive Dust
-------
Table 4.8-9. List of Grown Sources
TIFR1 TIFR7
2307010000 Industrial Processes Wood Products: SIC 24 Logging Operations Total 14 01
2710020030 Natural Sources Biogenic Horses and Ponies 14 01
2801000001 Miscellaneous Area Sources Agriculture Production-Crops Agriculture-Crops Land Breaking 14 01
2801000002 Miscellaneous Area Sources Agriculture Production-Crops Agriculture-Crops Planting 14 01
2801000003 Miscellaneous Area Sources Agriculture Production-Crops Agriculture-Crops Tilling 14 01
2801000004 Miscellaneous Area Sources Agriculture Production - Crops Agriculture - Crops Defoliation 14 01
2801000005 Miscellaneous Area Sources Agriculture Production - Crops Agriculture - Crops Harvesting 14 01
2801000006 Miscellaneous Area Sources Agriculture Production - Crops Agriculture - Crops Drying 14 01
2801000007 Miscellaneous Area Sources Agriculture Production-Crops Agriculture-Crops Loading 14 01
2801000008 Miscellaneous Area Sources Agriculture Production - Crops Agriculture - Crops Transport 14 01
2801700001 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2801700002 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2801700003 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2801700004 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2801700005 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2801700006 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2801700007 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2801700008 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2801700009 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2801700010 Miscellaneous Area Sources Agriculture Production-Crops Fertilizer Application 14 01
2805000000 Miscellaneous Area Sources Agriculture Production - Livestock Agriculture - Livestock Total 14 01
2805001000 Miscellaneous Area Sources Agriculture Production - Livestock Beef Cattle Feedlots Total 14 01
2805001001 Miscellaneous Area Sources Agriculture Production - Livestock Beef Cattle Feedlots Feed Preparation 14 01
2805005000 Miscellaneous Area Sources Agriculture Production - Livestock Poultry Operations Total 14 01
2805005001 Miscellaneous Area Sources Agriculture Production - Livestock Poultry Operations Feed Preparation 14 01
2805010000 Miscellaneous Area Sources Agriculture Production - Livestock Dairy Operations Total 14 01
2805010001 Miscellaneous Area Sources Agriculture Production - Livestock Dairy Operations Feed Preparation 14 01
2805015000 Miscellaneous Area Sources Agriculture Production - Livestock Hog Operations Total 14 01
2805015001 Miscellaneous Area Sources Agriculture Production - Livestock Hog Operations Feed Preparation 14 01
2805020000 Miscellaneous Area Sources Agriculture Production-Animal Husbandry Cattle and Calves Composite 14 01
2805025000 Miscellaneous Area Sources Agriculture Production-Animal Husbandry Hogs and Pigs Composite 14 01
2805030000 Miscellaneous Area Sources Agriculture Production-Animal Husbandry Poultry - Chickens Composite 14 01
2805040000 Miscellaneous Area Sources Agriculture Production-Animal Husbandry Sheep and Lambs Composite 14 01
2805045001 Miscellaneous Area Sources Agriculture Production-Animal Husbandry Goats 14 01
2275085000 Mobile Sources Aircraft Unpaved Airstrips Total 14 07
2650000005 Waste Disposal, Treatment, & Recovery Scrap & Waste Materials Scrap & Waste Materials Storage Piles 14 07
30300519 Primary Metal Production Primary Metal Production Primary Copper Smelting Unpaved Road Traffic: Fugitive Emissions 14 07
30300831 Primary Metal Production Iron Production Fugitive Emissions: Roads Unpaved Roads: LDV 14 07
30300832 Primary Metal Production Iron Production Fugitive Emissions: Roads Unpaved Roads: MDV 14 07
30300833 Primary Metal Production Iron Production Fugitive Emissions: Roads Unpaved Roads: HDV 14 07
30300834 Primary Metal Production Iron Production Fugitive Emissions: Roads Paved Roads: All Vehicle Types 14 07
30302321 Primary Metal Production Primary Metal Production Taconite Iron Ore Processing Haul Road: Rock 14 07
30302322 Primary Metal Production Primary Metal Production Taconite Iron Ore Processing Haul Road: Taconite 14 07
30501024 Mineral Products Mineral Products Surface Mining Operations Hauling 14 07
30501031 Mineral Products Mineral Products Surface Mining Operations Scrapers: Travel Mode 14 07
30501039 Mineral Products Mineral Products Surface Mining Operations Hauling: Haul Trucks 14 07
30501045 Mineral Products Mineral Products Surface Mining Operations Bulldozing: Overburden 14 07
30501046 Mineral Products Mineral Products Surface Mining Operations Bulldozing: Coal 14 07
30501047 Mineral Products Mineral Products Surface Mining Operations Grading 14 07
30501049 Mineral Products Mineral Products Surface Mining Operations Wind Erosion: Exposed Areas 14 07
30501050 Mineral Products Mineral Products Surface Mining Operations Vehicle Traffic: Light/Medium Vehicles 14 07
30501090 Mineral Products Mineral Products Surface Mining Operations Haul Roads: General 14 07
30502011 Mineral Products Mineral Products Stone Quarrying/Processing Hauling 14 07
30502504 Mineral Products Mineral Products Sand/Gravel Hauling 14 07
31100101 Building Construction Building Construction Construction: Building Contractors Site Preparation: Topsoil Removal 14 07
31100102 Building Construction Building Construction Construction: Building Contractors Site Preparation: Earth Moving (Cut S Fill) 14 07
31100103 Building Construction Building Construction Construction: Building Contractors Site Preparation: Aggregate Hauling (on dirt) 14 07
31100205 Building Construction Building Construction Construction: Demolition of Structures On-Site Truck Traffic 14 07
31100206 Building Construction Building Construction Construction: Demolition of Structures On-Site Truck Traffic 14 07
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-303
1985-1996 Methodology
Fugitive Dust
-------
Table 4.8-10. Point Source Data Submitted
State Data Source/Format
Alabama Al RS-AFS - Ad hoc retrievals
Arkansas Al RS-AFS - Ad hoc retrievals
Connecticut State - EPS Workfile
Delaware State - EPS Workfile
District of Columbia Al RS-AFS - Ad hoc retrievals
Florida Al RS-AFS - Ad hoc retrievals
Georgia - Atlanta State - State format
Urban Airshed (47
counties) domain
Georgia - Rest of Al RS-AFS -Ad hoc retrievals
State
Illinois State - EPS Workfiles
Indiana AIRS-AFS - Ad hoc retrievals
Kansas AIRS-AFS - Ad hoc retrievals
Kentucky - Jefferson Jefferson County - EPS Workfile
County
Kentucky - Rest of State - EPS Workfile
State
Louisiana State - State Format
Maine State - EPS Workfile
Maryland State - EPS Workfile
Massachusetts State - EPS Workfile
Michigan State - State Format
Minnesota AIRS-AFS - Ad hoc retrievals
Missouri AIRS-AFS - Ad hoc retrievals
Nebraska AIRS-AFS - Ad hoc retrievals
New Hampshire State - EPS Workfile
New Jersey State - EPS Workfile
New York State - EPS Workfile
North Carolina State - EPS Workfiles
North Dakota AIRS-AFS - Ad hoc retrievals
Ohio State - State Format
Oklahoma State - State Format
Pennsylvania - Allegheny County - County Format
Allegheny County
Pennsylvania - Philadelphia County - County Format
Philadelphia County
Pennsylvania- Rest of State - EPS Workfile
State
Rhode Island State - EPS Workfile
South Carolina AIRS-AFS - Ad hoc retrievals
Temporal
Resolution
Annual
Annual
Daily
Daily
Annual
Annual
Daily
Annual
Daily
Annual
Annual
Daily
Daily
Annual
Daily
Daily
Daily
Annual
Annual
Annual
Annual
Daily
Daily
Daily
Daily
Annual
Annual
Annual
Daily
Daily
Daily
Daily
Annual
Year of Data
1994
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1990
1993
1990
1990
1990
1990
1990
1990
1990
1994
1990
1990
1990
1990
1991
Adjustments to Data
Backcast to 1990 using BEA. Average Summer Day
estimated using methodology described above.
Average Summer Day estimated using default
temporal factors.
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
None
Average Summer Day estimated using default
temporal factors.
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
None
None
Average Summer Day estimated using methodology
described above.
None
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
Backcast to 1990 using BEA. Average Summer Day
estimated using methodology described above.
Average Summer Day estimated using methodology
described above.
None
None
None
None
Average Summer Day estimated using methodology
described above.
Average Summer Day estimated using methodology
described above.
Backcast to 1990 using BEA. Average Summer Day
estimated using methodology described above.
None
None
None
None
Average Summer Day estimated using default
temporal factors.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-304
1985-1996 Methodology
Fugitive Dust
-------
Table 4.8-10 (continued)
State
Data Source/Format
Temporal
Resolution Year of Data Adjustments to Data
South Dakota AIRS-AFS - Ad hoc retrievals
Tennessee AIRS-AFS - Ad hoc retrievals
Texas State - State Format
Vermont State - EPS Workfile
Virginia AIRS-AFS - Ad hoc retrievals
West Virginia AIRS-AFS - Ad hoc retrievals
Wisconsin State - State Format
Annual 1990 Average Summer Day estimated using methodology
described above.
Annual 1990 Average Summer Day estimated using default
temporal factors.
Daily 1992 Backcast to 1990 using BEA.
Daily 1990 None
Annual 1990 Average Summer Day estimated using methodology
described above.
Annual 1990 Average Summer Day estimated using methodology
described above.
Daily 1990 None
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-305
1985-1996 Methodology
Fugitive Dust
-------
Table 4.8-11. Area Source Data Submitted
State
Connecticut
Delaware
District of Columbia
Florida
Georgia
Data Source/Format
State - EPS Workfile
State - EPS Workfile
State - Hard copy
AIRS-AMS - Ad hoc retrievals
State - State format
Temporal
Resolution
Daily
Daily
Daily
Daily
Daily
Geoaraohic Coveraae
Entire State
Entire State
Entire State
Jacksonville, Miami/
Ft. Lauderdale, Tampa
Atlanta Urban Airshed
Adjustments to Data
None
None
None
Added Non-road emission estimates
from Int. Inventory to Jacksonville
(Duval County)
None
Illinois State - State format Daily
Indiana State - State format Daily
Kentucky State - State Format Daily
Louisiana State - State Format Daily
Maine State - EPS Workfile Daily
Maryland State - EPS Workfile Daily
Michigan State - State Format Daily
Missouri AIRS-AMS-Ad hoc retrievals Daily
New Hampshire State - EPS Workfile Daily
New Jersey State - EPS Workfile Daily
New York State - EPS Workfile Daily
North Carolina State - EPS Workfiles Annual
Ohio State - Hard copy Daily
Pennsylvania State - EPS Workfile Daily
Rhode Island State - EPS Workfile Daily
Tennessee State - State format Daily
Texas State - State Format Annual
Vermont State - EPS Workfile Daily
Virginia State - EPS Workfile Daily
West Virginia AIRS-AMS - Ad hoc retrievals Daily
Wisconsin State - State Format Daily
(47 Counties)
Entire State
Entire State
Kentucky Ozone Nonattainment
Areas
Baton Rouge Nonattainment
Area (20 Parishes)
Entire State
Entire State
49 Southern Michigan Counties
St. Louis area (25 counties)
Entire State
Entire State
Entire State
Entire State
Canton, Cleveland Columbus,
Dayton, Toledo, and Youngstown
Entire State
Entire State
42 Counties in Middle
Tennessee
Entire State
Entire State
Entire State
Charleston, Huntington/Ashland,
and Parkersburg (5 counties
total)
Entire State
None
Non-road emissions submitted were
county totals. Non-road emissions
distributed to specific SCCs based
on Int. Inventory
None
None
None
None
None
Only area source combustion data
was provided. All other area source
data came from Int. Inventory
None
None
None
Average Summer Day estimated
using default temporal factors.
Assigned SCCs and converted from
kgs to tons. NOX and CO from Int.
Inventory added to Canton, Dayton,
and Toledo counties.
Non-road emissions submitted were
county totals. Non-road emissions
distributed to specific SCCs based
on Int. Inventory
None
No non-road data submitted. Non-
road emissions added from Int.
Inventory
Average Summer Day estimated
using default temporal factors.
None
None
None
None
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-306
1985-1996 Methodology
Fugitive Dust
-------
Table 4.8-12. Ad Hoc Report
Criteria
Regn
DLL4
DLL4
DLL4
DLL4
DLL4
DLL4
DES4
DUE4
VI NV
GTO
CEVOC
CECO
CESO2
CE NO2
CE PM-10
CE PT
GEO
VIETY
VIE 90
Plant Output
YINV
SITE
CNTY
CYCD
7IPC
DNED
DNME
_AT1
_ON1
SIC1
OPST
SIRS
YEAR OF INVENTORY
STATE FIPS CODE
COUNTY FIPS CODE
CITY CODE
ZIP CODE
MEDS POINT ID
DLANT NAME
_ATITUDE PLANT
_ONGITUDE PLANT
STANDARD INDUSTRIAL
CODE
OPERATING STATUS
STATE REGISTRATION
MUMBER
Point Output
STTE
CNTY
PNED
DNUM
CAPC
CAPU
DAT1
DAT2
DAT3
DAT4
MOHD
MODW
MOHY
STATE FIPS CODE
COUNTY FIPS CODE
NEDS POINT ID
DOINT NUMBER
DESIGN CAPACITY
DESIGN CAPACITY
UNITS
WINTER
THROUGHPUT
SPRING
THROUGHPUT
SUMMER
THROUGHPUT
-ALL THROUGHPUT
MUMBER HOURS/DAY
MUMBER DAYS/WEEK
MUMBER
HOURS/YEAR
Stack Output
STTE
CNTY
PNED
STNB
_AT2
_ON2
STHT
STDM
STET
STEV
STFR
DLHT
STATE FIPS CODE
COUNTY FIPS CODE
NEDS POINT ID
STACK NUMBER
_ATITUDE STACK
LONGITUDE STACK
STACK HEIGHT
STACK DIAMETER
STACK EXIT
TEMPERATURE
STACK EXIT VELOCITY
STACK FLOW RATE
DLUME HEIGHT
Segment Output
General
STTE
CNTY
DNED
STNB
DNUM
SEGN
SCC8
HEAT
ZPRT
SULF
^SHC
DODP
STATE FIPS CODE
COUNTY FIPS CODE
NEDS POINT ID
STACK NUMBER
DOINT NUMBER
SEGMENT NUMBER
sec
HEAT CONTENT
^NNUALFUEL
THROUGHPUT
SULFUR CONTENT
ASH CONTENT
DEAK OZONE
SEASON DAILY
DROCESS RATE
Segment Output
Pollutant
STTE
CNTY
DNED
STNB
DNUM
SEGN
SCC8
DLL4
D034
DU04
DES4
DUE4
CLEE
CLT1
CTL2
REP4
DME4
Emfa
STATE FIPS CODE
COUNTY FIPS CODE
MEDS POINT ID
STACK NUMBER
DOINT NUMBER
SEGMENT NUMBER
sec
DOLLUTANT CODE
OSD EMISSIONS
OSD EMISSION
UNITS
DEFAULT
ESTIMATED
EMISSIONS
DEFAULT
ESTIMATED
EMISSIONS UNITS
CONTROL
EFFICIENCY
DRIMARY CONTROL
DEVICE CODE
SECONDARY
CONTROL DEVICE
CODE
RULE
EFFECTIVENESS
VIETHODCODE
Emission factor
-------
Table 4.8-13. Bureau of Economic Analysis's SA-5 National Changes in Earnings by
Industry
Percent Growth from:
Industry SIC 1985 to 1987 1987 to 1988 1988 to 1989 1989 to 1990
Farm
Agricultural services, forestry,
01,02
07, 08, 09
14.67
23.58
-2.73
5.43
14.58
1.01
-3.11
2.48
fisheries, and other
Coalmining 11,12 -17.46 -6.37 -4.16 4.73
Metal mining 10 -3.03 18.01 8.94 4.56
Nonmetallic minerals, except fuels 14 2.33 3.74 -2.79 -0.45
Construction 15,16,17 7.27 4.81 -1.36 -3.80
National Air Pollutant Emission Trends 1985-1996 Methodology
Procedures Document for 1900-1996 4-308 Fugitive Dust
-------
Table 4.8-14. Emission Estimates Available from AIRS/FS by State, Year, and Pollutant
State
1990
1991
1992
1993
N S P T V
1994
C N S P T V
1995
C N S P T V
Alabama
Alaska
Arizona
f
alifornia
olorado
onnecticut
Hawaii
llinois
Louisiana
Michigan
Minnesota
Montana
Nebraska
Nevada
New
Hampshire
slew Mexico
North Dakota
Oregon
ennsylvani
a
South
arolina
South
Dakota
Texas
Utah
Vermont
Virginia
Washington
Wisconsin
Wyoming
Notes:
C = CO
= NO,
S = SO,
P = PM-10 T = TSP
V = VOC
Pennsylvania only includes Allegheny County (State 42, County 003); New Mexico only includes Albuquerque (State 35, County
001); Washington only includes Puget Sound (State 53, County 033, 053, or 061); Nebraska includes all except Omaha City
(State 31, County 055); the CO emissions in NET were maintained for South Dakota (State 46).
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-309
1985-1996 Methodology
Fugitive Dust
-------
Table 4.8-15. SEDS National Fuel Consumption, 1990-1996 (trillion Btu)
Fuel Tvoe End-User Code
Population
TPOPP
Table 4.8-1 6. BEASA-5
Industry
Farm
Farm
Farm
Agricultural services,
Agricultural services,
Agricultural services,
Agricultural services,
Agricultural services,
Agricultural services,
Agricultural services,
Nonmetallic minerals
Construction
Construction
Construction
Construction
forestry, fisheries, and other
forestry, fisheries, and other
forestry, fisheries, and other
forestry, fisheries, and other
forestry, fisheries, and other
forestry, fisheries, and other
forestry, fisheries, and other
, except fuels
1990
248,709
National
Primary metal industries
Transportation by air
1991 1992 1993 1994 1995
1996
252,131 255,025 257,785 259,693 261,602 263,510
Earnings by Industry, 1990-1996 (million $)
LNUM SIC 1990 1991 1992 1993 1994 1995
81 1,2 48 41 46 45 42 31
82 1,2 3,586 3,552 3,686 3,740 3,849 3,980
90 1,2 3,001 2,957 3,079 3,126 3,228 3,353
100 7-9 24 24 24 24 26 27
110 7-9 20 20 21 22 23 24
120 7-9 433333
121 7-9 111011
122 7-9 222222
123 7-9 111111
200 7-9 36 37 36 34 35 35
240 14 444444
300 15-17 218 197 195 199 216 219
310 15-17 54 47 46 47 51 51
320 15-17 29 28 28 27 29 29
330 15-17 135 123 121 125 136 138
423 33 33 30 31 30 32 33
542 45 30 30 31 31 31 31
1996
29
4,058
3,423
27
25
3
1
1
1
35
4
219
50
29
139
32
31
Table 4.8-17 Area Source Listing by SCC and Growth Basis
SCC FILE
2275000000 BEA
2275001000 BEA
2275020000 BEA
2275020021 BEA
2275050000 BEA
2275060000 BEA
2275070000 BEA
2275085000 BEA
2275900000 BEA
2275900101 BEA
2275900102 BEA
2301000000 BEA
2301010000 BEA
2301020000 BEA
2301030000 BEA
2301040000 BEA
2710020030 BEA
2801000003 BEA
CODE
542
920
542
542
542
542
542
542
542
542
542
471
471
471
471
471
081
081
SCC FILE CODE
2801000005 BEA 100
2801700001 BEA 081
2801700002 BEA 081
2801700003 BEA 081
2801700004 BEA 081
2801700005 BEA 081
2801700006 BEA 081
2801700007 BEA 081
2801700008 BEA 081
2801700009 BEA 081
2801700010 BEA 081
2805000000 BEA 081
2805001000 BEA 081
2805020000 BEA 081
2805025000 BEA 081
2805030000 BEA 081
2805040000 BEA 081
2805045001 BEA 081
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-310
1985-1996 Methodology
Fugitive Dust
-------
SECTION 5.0
LEAD EMISSIONS METHODOLOGY
5.1 INTRODUCTION
The methodology used to estimate the lead emissions presented in the Trends reports for the years
1970 to 1996 was based on the 1940-1984 Methodology. This section describes, in detail, the
procedures used to create these estimates.
5.1.1 Background
The lead emissions methodology was based on a "top-down" approach where national information
was used to create a national inventory of lead emissions. The emissions were estimated based on the
source of the emissions and, in the case of combustion sources, the fuel type. The national activity of a
process producing lead emissions was measured by the consumption of fuel, the throughput of raw
materials, or an alternative production indicator. An emission factor was then applied to activity data to
determine the amount of lead emitted from a specific process. For some categories, the lead content of
the fuel was incorporated into the estimating procedure as part of the emission factor. The final element
used to estimate emissions was the control efficiency, which quantifies the amount of lead not emitted
due to the presence of control devices.
The lead emissions were presented in the 1997 Trends report by Tier categories, but in the lead
emissions methodology, emissions were estimated by a different set of source categories. The source
categories or subcategories contributing to lead emissions were regrouped into the Tier categories. The
estimation procedures are presented in this section by Tier II category. The correspondence between the
Tier II categories and the lead emissions methodology source categories is presented in Table 5.1-1.
Within the description of the procedures for each Tier II category, the correlation between the categories
is reiterated.
5.1.2 General Procedure
Lead emissions were calculated according to Equation 5.1-1.
Lead Emissionstj = A. y. x EF{J x [1 -CE. j] (Eq. 5.1-1)
where: A = activity
EF = emission factor
CE = control efficiency
I = year
j = source category
National Air Pollutant Emission Trends Lead Emissions Methodology
Procedures Document for 1900-1996 5 -1 Intro duction
-------
As an aid in the calculation of emissions by the lead methodology, two Excel spreadsheets were
created for each year and are collectively referred to as the Trends spreadsheets. The spreadsheets were
entitled TRENDSxx.XLS and MGTMPxx.XLS, where xx represents the year. The required data were
entered into the TRENDSxx.XLS spreadsheet, after which the MGTMPxx.XLS spreadsheet was opened
and the necessary calculations were made to estimate the national emissions. This procedure was
designed to simplify the process of estimating emissions for a new year. By using the TRENDSxx.XLS
spreadsheets from the previous year as templates, the spreadsheets for the new year were created by
editing only the data requiring updating.
The calculations utilized within the TRENDSxx.XLS spreadsheets required specific units for the
activity indicators and the emission factors. The required units are specified within the procedures for
each Tier II category. In general, the units for activity indicators were short tons for solids, gallons for
liquids, and cubic feet for gases. Emission factors were expressed in units of metric pounds of pollutant
per unit consumption or throughput. Control efficiencies were expressed as a dimensionless decimal
fraction. By using these units, the emissions calculated within the spreadsheets were expressed in metric
tons. Raw data used as the basis for activity indicators or emission factors were often expressed in units
which required conversion to the appropriate units. The following conversion factors were used in many
cases.
1 ton (metric) = 1.1023 tons (short)
1 ton (long) = 1.1016 tons (short)
1 ton (short) = 0.9072 tons (metric)
1 bbl = 42 gal
The emission factors used to estimate lead emissions were based on the most recent information
available. For many categories, the most recent emission factor was used to estimate the emissions for all
years.
When the emissions were estimated for 1996, not all of the activity information was available. In
order to make a preliminary emissions estimate, activity data from preceding years were used to estimate
the activity data for 1996. This was done using several different methods. The first method used a
quadratic equation and the past 20 years of activity data. Data for 1976-1995 were used, and the previous
ten year's data (1986-1995) was repeated. The second method used a linear regression and the past 7
years of activity data. Data from 1989-1995 were used, 1993-1995 data were repeated, and the 1995 data
were repeated a third time. The third method, used in cases where the first method resulted in a negative
activity value, calculated the average of the activity data over the past 5 years. Table 5.1-2 presents by
general source category the method used to estimate activity data for generating 1996 emissions. For
general source categories not listed, activity data for the current year were available at the time the
emissions were estimated.
5.1.3 Organization of Procedures
The methodology used to estimate lead emissions is described by Tier II category except for the On-
road vehicles category which is described at the Tier I level. For each category, the procedure is divided
National Air Pollutant Emission Trends Lead Emissions Methodology
Procedures Document for 1900-1996 5-2 Introduction
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into four sections, reflecting the data required to generate the estimates: (1) technical approach, (2)
activity indicator, (3) emission factor, and (4) control efficiency. The procedures for obtaining activity
indicators, emission factors or control efficiencies are arranged in a variety of ways, depending on the
specific requirements of the category. The procedures could be arranged by process, fuel type, or other
subcategory.
References are provided at the end of the description of the procedure for each Tier II category.
Many of the references are published annually as part of a series. In some cases, several references are
provided for the same information, reflecting a change or discontinuation of one source and its
replacement by another. The specific source used would depend on the specific year for which
information is needed. All tables and supporting data immediately follow the description of the procedure
for each Tier II category.
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Table 5.1-1. Correspondence Between Tier II Categories and Lead Emissions Methodology Categories
Tier I Category
Fuel Combustion -
Electric Utility
Fuel Combustion -
Industrial
Fuel Combustion -
Other
Tier II Category
Coal
Oil
Coal
Oil
Commercial and
Institutional Coal
Commercial and
Institutional Oil
Miscellaneous Fuel
Combustion (except
residential)
Residential Other
Tier I/Tier II Code
01-01
01-02
02-01
02-02
03-01
03-02
03-04
03-06
Lead Emissions
Methodology
Category
Bituminous Coal and
Lignite
Anthracite Coal
Residual Oil
Distillate Oil
Bituminous Coal and
Lignite
Anthracite Coal
Residual Oil
Distillate Oil
Bituminous Coal and
Lignite
Anthracite Coal
Residual Oil
Distillate Oil
Residual Oil
Bituminous Coal and
Lignite
Anthracite Coal
Residual Oil
Distillate Oil
Lead Emissions Methodology Subcategory
Electric Utility
Electric Utility
Electric Utility
Electric Utility
Industrial
Industrial
Industrial
Industrial
Commercial and Institutional
Commercial and Institutional
Commercial and Institutional
Commercial and Institutional
Waste Oil
Residential
Residential
Residential
Residential
-------
Table 5.1-1 (continued)
Tier I Category
Chemical and Allied
Product Manufacture
Metals Processing
Other Industrial
Processes
Waste Disposal and
Recycling
On-road vehicles
Non-road engines
and vehicles
Tier II Category
Inorganic Chemical
Manufacturing
Nonferrous
Ferrous
Not Elsewhere
Classified
Mineral Products
Miscellaneous
Industrial Processes
Incineration
All Categories (Light-
Duty Gas Vehicles
and Motorcycles,
Light-Duty Gas
Trucks, and
Heavy-Duty Gas
Vehicles)
Nonroad Gasoline
Aircraft
Tier I/Tier II Code
04-02
05-01
05-02
05-03
07-05
07-10
10-01
11
12-01
12-03
Lead Emissions
Methodology
Category
Industrial Processes
Industrial Processes
Industrial Processes
Industrial Processes
Industrial Processes
Industrial Processes
Solid Waste
Disposal
On-road vehicles
Other Non-road
engines and
vehicles
Vessels
Aircraft
Lead Emissions Methodology Subcategory
Secondary Metals (lead oxide/pigment)
Nonferrous Metals (copper, zinc, and lead production)
Secondary Metals (lead, copper, and battery production)
Miscellaneous Process Sources [miscellaneous products
(can soldering and cable covering)]
Iron and Steel Industry
Nonferrous Metals (ferroalloy production)
Secondary Metals Industry (grey iron foundries)
Mineral Products (ore crushing)
Miscellaneous Process Sources [miscellaneous products
(type metal production)]
Mineral Products (cement manufacturing and glass
production, lead-glass)
Miscellaneous Process Sources (lead alkyl production -
electrolytic process, sodium lead alloy, and miscellaneous
products (ammunition)]
Incineration
Gasoline (leaded and unleaded)
Gasoline
Gasoline
Aviation Gasoline
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Table 5.1-2. Method Used for Estimating 1996 Activity Data
General Source Category
Activity Data Estimation Method
Non-road engines and vehicles
All Anthracite Coal Categories
Fuel Combustion, excluding Electric Utility
Bituminous Coal
Residual Oil
Distillate Oil
Solid Waste
Industrial Process Sources
Quadratic equation method
Linear regression method
Linear regression method
Quadratic equation method
Linear regression method
Quadratic equation method
Linear regression method
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-6
Lead Emissions Methodology
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5.2 FUEL COMBUSTION ELECTRIC UTILITY - COAL: 01-01
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (See Table 5.1-1 for Tier correspondence):
Category: Subcategory:
Bituminous Coal and Lignite Electric Utility
Anthracite Coal Electric Utility
5.2.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, activity indicators were expressed in million short
tons for bituminous coal, and in thousand short tons for anthracite coal. Emission factors were expressed
in metric pounds/thousand short tons.
The following procedures for determining activity indicators and emission factors were used for the
years 1970 through 1995.
5.2.2 Activity Indicator
The activity indicator for the combustion of coal at electric Utility was the anthracite coal receipts at
electric Utility obtained from Reference la or Ib.
The activity indicator for the combustion of bituminous coal and lignite was calculated as the
difference between the total national consumption of coal by electric Utility and the anthracite coal
consumption at electric Utility as determined above. The total national consumption of coal was obtained
from Reference 2a or Reference 3.
5.2.3 Emission Factor
The emission factors for the combustion of anthracite coal and of bituminous coal and lignite were
obtained from Reference 4a.
5.2.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from the sources included
in this Tier II category.
National Air Pollutant Emission Trends Lead Emissions Methodology
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5.2.5 References
1. Cost and Quality of Fuels for Electric Utility Plants. DOE/EIA-0191(xx). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
a. Appendix A
b. Table entitled, "Receipts and Average Delivered Cost of Coal By Rank, Census Division, and
state, 19xx."
2. Electric Power Annual. DOE/EOA-0348(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Volume I. Table entitled, "Consumption of Fossil Fuels and End-year Stocks of Coal and
Petroleum at U.S. Utility."
3. Quarterly Coal Report: January - March. DOE/EIA-0121 (xx/1Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Quarterly.
4. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
National Air Pollutant Emission Trends Lead Emissions Methodology
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5.3 FUEL COMBUSTION ELECTRIC UTILITY - OIL: 01-02
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Residual Oil Electric Utility
Distillate Oil Electric Utility
5.3.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, activity indicators were expressed in million
gallons and emission factors were expressed in metric pounds/million gallons.
The following procedures for determining activity indicators and emission factors were used for the
years 1970 through 1995.
5.3.2 Activity Indicators
The activity indicators for the combustion of residual and distillate oils were the consumption of
these fuel types by electric Utility. The distillate oil consumption was assumed to be equal to the
"adjusted" distillate fuel oil sales to electric Utility obtained from Reference la or Reference 2. The
residual fuel oil consumption was obtained from "adjusted" residual fuel sales in Reference la. When this
reference was unavailable, the residual oil consumption was calculated as the difference between the total
oil consumption and the distillate oil consumption. The total annual oil consumption was obtained from
Reference 3.
5.3.3 Emission Factors
The emission factors for the combustion of residual oil and of distillate oil by electric Utility were
obtained from Reference 4a.
5.3.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from the sources included
in this Tier II category.
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5.3.5 References
1. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Adjusted Sales of Distillate Fuel Oil By End Use in the U.S."
b. Table entitled, "Adjusted Sales of Residual Fuel Oil By End Use in the U.S."
2. Petroleum Marketing Annual. DOE/EIA-0389(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
3. Electric Power Annual. DOE/EOA-0348(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
4. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
National Air Pollutant Emission Trends Lead Emissions Methodology
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5.4 FUEL COMBUSTION INDUSTRIAL - COAL: 02-01
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Anthracite Coal Industrial
Bituminous Coal and Lignite Industrial
5.4.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, the activity indicators were expressed in million
short tons for bituminous coal, and in thousand short tons for anthracite coal. The emission factors were
expressed in metric pounds/thousand short tons.
The following procedures for determining activity indicators and emission factors were used for the
years 1970 through 1995.
5.4.2 Activity Indicator
The activity indicator for the industrial combustion of anthracite coal was the distribution of
anthracite coal from Pennsylvania (i.e. District 24) obtained from Reference la under the category
"Industrial Plants (except coke)."
The activity indicator for the combustion of bituminous coal and lignite was based on total national
coal consumption obtained from Reference 2a under the category "Industrial Plants (except coke)." The
sum of coal consumption by cement plants and lime plants was subtracted from the total coal
consumption. The coal consumption by cement plants was obtained from Reference 3 or Reference 4a.
The coal consumption by lime plants was estimated by multiplying the lime production value obtained
from Reference 5 by the conversion factor, 0.1 tons coal/ton lime produced. If Reference 4 was
unavailable, the previous year's data was used.
5.4.3 Emission Factors
The emission factors for the industrial combustion of anthracite coal and of bituminous coal and
lignite were obtained from Reference 6a.
5.4.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from the sources included
in this Tier II category.
National Air Pollutant Emission Trends Lead Emissions Methodology
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5.4.5 References
1. Coal Distribution January-December 19xx. DOE/EIA-0125(xx/4Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
a. Table entitled, "Domestic Distribution of U.S. Coal by Origin, Destination, and Consumer:
January-December 19xx."
2. Quarterly Coal Report: January - March. DOE/EIA-0121 (xx/1Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Quarterly.
a. Table entitled, "U.S. Coal Receipts By End-Use Sector"
3. Minerals Industry Surveys, Cement. Bureau of Mines, U.S. Geological Survey, Washington, DC.
Monthly.
4. Minerals Yearbook, Cement. US Geological Survey (formerly Bureau of Mines), Washington,
DC. Annual
a. Table entitled, "Clinker Produced and Fuel Consumed by the Portland Cement Industry the
U.S. by process."
5. Chemical and Engineering News, Facts and Figures Issue. American Chemical Society,
Washington, DC. Annual.
6. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
National Air Pollutant Emission Trends Lead Emissions Methodology
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5.5 FUEL COMBUSTION INDUSTRIAL - OIL: 02-02
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Residual Oil Industrial
Distillate Oil Industrial
5.5.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, activity indicators were expressed in million
gallons and emission factors were expressed in metric pounds/million gallons.
The following procedures for determining activity indicators and emission factors were used for the
years 1970 through 1995.
5.5.2 Activity Indicator
The activity indicator for industrial combustion of residual oil was based on the adjusted quantity of
residual oil sales for industrial and oil company use obtained from Reference 1 or 2a. The total of three
statistics was subtracted from this value to obtain the activity indicator. The first statistic was two-thirds
of the quantity of oil consumed by cement plants reported in Reference 3 or 4a. The second statistic was
the quantity of residual oil consumed by petroleum refineries reported in Reference 5a. The third statistic
was the quantity of residual oil consumed by steel mills; this value was calculated by multiplying the
quantity of raw steel production obtained from Reference 6a or 7, by 0.00738 * 106 gal/103 ton steel.
The conversion factor between the gallons of oil and the tons of steel was updated in 1982 based on
Reference 8.
The activity indicator for industrial combustion of distillate oil was based on the adjusted quantity of
distillate oil sales to industrial and oil companies obtained from Reference 1 or 2a. The total of two
statistics was subtracted from this value to obtain the activity indicator for distillate oil. The first statistic
was one-third of the quantity of oil consumed by cement plants, expressed in gallons, reported in
Reference 3 or 4a. The second statistic was the quantity of distillate oil consumed by petroleum
refineries, expressed in gallons, reported in Reference 5 a or 5b.
5.5.3 Emission Factor
The lead emission factor for the industrial combustion of residual oil and of distillate oil were
obtained from Reference 9a.
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5.5.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from the sources included
in this Tier II category.
5.5.5 References
1. Petroleum Marketing Monthly. DOE/EIA-0380(xx/01). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
2. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Adjusted Sales of Residual Fuel Oil by End-Use in the U.S."
3. Minerals Industry Surveys, Cement. Bureau of Mines, U.S. Department of the Interior,
Washington, DC. Monthly.
a. Table entitled, "Clinker Produced and Fuel Consumed by the Portland Cement Industry in the
U.S. By Process."
4. Minerals Yearbook, Cement. US Geological Survey (formerly Bureau of Mines), Washington, DC.
Annual
a. Table entitled, "Clinker Produced and Fuel Consumed by the Portland Cement Industry in the
U.S. By Process."
5. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Fuel Consumed at Refineries by PAD District."
b. Table entitled, "Refinery Fuel Use and Losses by PAD District."
6. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC.
a. Table containing information on metals and manufactures.
7. Mineral Industry Surveys. Iron and Steel. US Geological Survey (formerly Bureau of Mines).
a. Table entitled, "Salient Iron and Steel Statistics."
8. Census of Manufactures (Fuels and Electric Energy Consumed). Bureau of the Census, U.S.
Department of Commerce, Washington, DC. 1982.
9. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
National Air Pollutant Emission Trends Lead Emissions Methodology
Procedures Document for 1900-1996 5-14 Category: 02-02
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5.6 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL COAL: 03-01
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Anthracite Coal Commercial / Institutional
Bituminous Coal and Lignite Commercial / Institutional
5.6.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, the activity indicators were expressed in million
short tons for bituminous coal, and in thousand short tons for anthracite coal. The emission factors were
expressed in metric pounds/thousand short tons.
The following procedures for determining activity indicators and emission factors were used for the
years 1970 through 1995.
5.6.2 Activity Indicator
The activity indicators for the combustion of anthracite and bituminous coal and lignite were the
consumption of each coal type by commercial and institutional users. Determination of these activity
indicators required activity data for both anthracite and bituminous residential coal combustion.
The commercial/institutional consumption of anthracite coal was obtained by subtracting the
residential anthracite consumption from residential and commercial/institutional anthracite consumption.
Residential and commercial/institutional consumption of anthracite coal was obtained from Reference la
for District 24 only. This calculation is shown in Equation 5.6-1.
Anthracite Coalc/I = Anthracite CoalRandc/I - Anthracite CoalR (Eq. 5.6-1)
where: R = residential consumption
C /1 = commercial/institutional consumption
Residential consumption of anthracite coal was determined by extrapolating the consumption of the
previous year based on the change in the number of dwelling units in the Northeastern United States
having coal as the main fuel for space heating. Data concerning the number of dwelling units were
obtained from Reference 2. The calculation of the residential anthracite coal consumption is summarized
in Equation 5.6-2.
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Dwelling Units.
Anthracite CoaL . = Anthracite Coal,, . , x (En 5 6-2)
' Dwelling Units. l v H' ' '
where: R = residential consumption
I = year under study
Commercial/institutional consumption of bituminous coal was obtained by subtracting the residential
bituminous consumption from the residential and commercial/institutional bituminous consumption.
Residential and commercial/institutional consumption of bituminous coal was calculated by subtracting
residential and commercial/institutional consumption of anthracite coal from residential and
commercial/institutional consumption of all types of coal. These two consumption values were obtained
from Reference la and excluded coal from District 24 which represents anthracite coal consumption.
This calculation is summarized in Equation 5.6-3.
Bituminous Coalcjl = (All CoalRandCII - Anthracite CoalRandCjI) - Bituminous CoalR fEq. 5.6-3)
where: R = residential consumption
C /1 = commercial/institutional consumption
The residential consumption of bituminous coal was determined by estimating the quantity of all coal
consumed by all dwelling units using coal as the main fuel and subtracting from this value the residential
consumption of anthracite coal calculated above. The quantity of all coal consumed was calculated using
the number of dwelling units using coal as the main fuel for space heating obtained from Reference 2 and
a factor estimating the average annual consumption of coal per dwelling unit. This calculation is
summarized in Equation 5.6-4.
Bituminous CoalR = (Dwelling Units x 6.73 tons burned/dwelling/year) - Anthracite CoalR CEa. 5.6-4)
where: R = residential consumption
5.6.3 Emission Factors
The emission factors for the commercial/institutional combustion of anthracite coal and of
bituminous coal and lignite were obtained from Reference 3 a.
5.6.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from the sources included
in this Tier II category.
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5.6.5 References
1. Coal Distribution January-December 19xx. DOE/EIA-0125(xx/4Q). Energy Information
Administration, U.S. Department of Energy, Washington, DC. Annual.
a. Table entitled, "Domestic Distribution of U.S. Coal to the Residential and Commercial Sector
by Origin."
2. American Housing Survey, Current Housing Reports, Series H-l50-83. Bureau of the Census, U.S.
Department of Commerce, Washington DC. Biennial.
3. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
National Air Pollutant Emission Trends Lead Emissions Methodology
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5.7 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL OIL: 03-02
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Residual Oil Commercial / Institutional
Distillate Oil Commercial / Institutional
5.7.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, activity indicators were expressed in million
gallons and emission factors were expressed in metric pounds/million gallons.
The following procedures for determining activity indicators and emission factors were used for the
years 1970 through 1995.
5.7.2 Activity Indicator
The activity indicator for the commercial/institutional combustion of residual oil was the "adjusted"
total quantity of residual oil sales for commercial and military use obtained from Reference 1 or
Reference 2a.
The activity indicator for the combustion of distillate oil was the "adjusted" total quantity of distillate
oil sales for commercial and military use (not including military diesel fuel) obtained from Reference 1, or
commercial and military use obtained from Reference 2b minus military diesel fuel use obtained from
Reference 2c.
5.7.3 Emission Factor
The emission factors for the commercial/institutional combustion of residual oil and of distillate oil
were obtained from Reference 3 a.
5.7.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from the sources included
in this Tier II category.
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5.7.5 References
1. Petroleum Marketing Monthly. DOE/EIA-0380(xx/01). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
2. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Adjusted Sales of Residual Fuel Oil by End Use in the US."
b. Table entitled, "Adjusted Sales of Distillate Fuel Oil by End Use in the US."
c. Table entitled, "Adjusted Sales for Military, Non-road engines and vehicles, and All Other Uses:
Distillate Fuel Oil, Residual Fuel Oil and Kerosene."
3. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
National Air Pollutant Emission Trends Lead Emissions Methodology
Procedures Document for 1900-1996 5-19 Category: 03-02
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5.8 FUEL COMBUSTION OTHER - MISCELLANEOUS FUEL COMBUSTION (EXCEPT
RESIDENTIAL): 03-04
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Residual Oil Waste Oil
5.8.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, the activity indicator was expressed in million
gallons and the emission factor was expressed in metric pounds/million gallons.
The following procedures for determining activity indicators and emission factors were used for the
years 1970 through 1996.
5.8.2 Activity Indicator
The activity indicator for the combustion of residual waste oil was assumed to be a constant annual
consumption of 500 x 106 gallons of waste oil.
5.8.3 Emission Factor
The emission factor for the combustion of residual waste oil was calculated as 75 lb/1,000 gal
multiplied by the average percentage of lead. It was assumed that the percentage of lead had a constant
value of 0.5333 up to the year 1975; after which, it was assumed that the lead percentage steadily
decreased. After 1984, the value has remained constant at 0.0213. The average lead percentage values
are presented in Table 5.8-1.
5.8.4 Control Efficiency
No control efficiency was applied to activity data to estimate lead emissions from the combustion of
waste oil.
5.8.5 References
None.
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Table 5.8-1. Annual Percentage Lead Content
Percent
Year Lead
1975 0.5333
1976 0.4702
1977 0.407
1978 0.3439
1979 0.2807
1980 0.2176
1981 0.1545
1982 0.0913
1983 0.0282
1984 0.0213
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5.9 FUEL COMBUSTION OTHER - RESIDENTIAL OTHER: 03-06
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Anthracite Coal Residential
Bituminous Coal and Lignite Residential
Residual Oil Residential
Distillate Oil Residential
5.9.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, the activity indicators were expressed in million
tons for bituminous coal and in thousand tons for anthracite coal. The emission factors for these
categories were expressed in metric pounds/thousand tons. Activity indicators for residual and distillate
oils were expressed in million gallons and emission factors were expressed in metric pounds/million
gallons.
The following procedures for determining activity indicators and emission factors were used for the
years 1970 through 1995.
5.9.2 Activity Indicator
The activity indicator for the residential combustion of anthracite coal was the residential
consumption of anthracite coal. This value was determined by extrapolating the residential consumption
of anthracite coal during the previous year based on the change in the number of dwelling units in the
Northeastern United States having coal as the main fuel for space heating. Data concerning the number
of dwelling units were obtained from Reference 1. The calculation of the residential anthracite coal
consumption is summarized in Equation 5.9-1.
Dwelling Units.
Anthracite CoaL . = Anthracite CoaL . , x (En 59-1)
R'1 *'1'1 Dwelling Units.^ l q' '
where: R = residential consumption
I = year under study
The activity indicator for the combustion of bituminous coal and lignite was the residential
consumption of bituminous coal and lignite. This value was determined by estimating the quantity of all
coal consumed by all dwelling units using coal as the main fuel and subtracting from this value the
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residential consumption of anthracite coal calculated above. The quantity of all coal consumed was
calculated using the number of dwelling units using coal as the main fuel for space heating obtained from
Reference 1 and a factor estimating the average annual consumption of coal per dwelling unit. This
calculation is summarized in Equation 5.9-2.
Bituminous CoalR = (Dwelling Units x 6.73 tons burned/dwelling/year) - Anthracite CoalR f^n 5.9-2)
where: R = residential consumption
The activity indicator for the residential combustion of residual oil was assumed to be zero. The
activity indicator for the combustion of distillate oil was the sum of the "adjusted" sales (or deliveries) for
residential use of distillate oil and for farm use of other distillates as reported in Reference 2 or Reference
3a and 3b.
5.9.3 Emission Factors
The emission factor for the residential combustion of anthracite coal was obtained from Reference
4.
The emission factor for the combustion of bituminous coal and lignite and for distillate oil was
obtained from Reference 5 a.
No emission factor was required for the combustion of residual oil because the activity was assumed
to be zero.
5.9.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from the sources included
in this Tier II category.
5.9.5 References
1. American Housing Survey, Current Housing Reports, Series H-l50-83. Bureau of the Census, U.S.
Department of Commerce, Washington DC. Biennial.
2. Petroleum Marketing Monthly. DOE/EIA-0380(xx/01). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
3. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Adjusted Sales of Distillate Fuel Oil by End Use in the U.S."
b. Table entitled, "Adjusted Sales for Gram Use: Distillate Fuel Oil and Kerosene; Sales for
Electric Utility and Oil Company Uses; Distillate Fuel Oil and Residual Fuel Oil."
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4. Development of HA TREMS Data Base and Emission Inventory Evaluation. EPA-45 0/3-77-011.
U.S. Environmental Protection Agency, Research Triangle Park, NC. April 1977.
5. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
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5.10 CHEMICAL AND ALLIED PRODUCT MANUFACTURE - INORGANIC CHEMICAL
MANUFACTURE: 04-02
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Industrial Processes - Lead Emissions Secondary Metals (lead oxide/pigment)
5.10.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, activity indicators were expressed in thousand
tons and emission factors were expressed in metric pounds/tons.
The following procedures for determining activity indicators and emission factors were used for the
years 1970 through 1995.
5.10.2 Activity Indicator
Activity indicators for the of barton pot (litharge and leady oxide), red lead, and white lead were the
respective quantities of each produced (using the lead content) as reported in Reference 1. If the litharge
and red lead are reported together, the last known distribution was used to distribute the activity. If the
value for white lead was withheld, the previous year's data was used.
5.10.3 Emission Factor
The lead emission factors for barton pot, red lead, and white lead were obtained from Reference 2a.
5.10.4 Control Efficiency
No control efficiencies were applied to activity data to estimate lead emissions from the sources
included in this Tier II category.
5.10.5 References
1. Minerals Yearbook, Lead. US Geological Survey (formerly Bureau of Mines), Washington, DC.
Annual.
a. Table entitled, "Production & Shipments of Lead Pigments and Oxides in the U.S."
2. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Table 7.16-1
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5.11
METALS PROCESSING - NONFERROUS: 05-01
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Industrial Processes - Lead Emissions
Subcategory:
Nonferrous Metals (copper, zinc, and lead
production)
Secondary Metals (lead, copper, and battery
production)
Miscellaneous Process Sources [miscellaneous
products (can soldering and cable covering)]
5.11.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator, emissions factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in thousand tons and emission factors were expressed in metric pounds/tons.
All control efficiencies were expressed as dimensionless fractions.
The following procedures for determining activity indicators, emission factors, and applicable
control efficiencies were used for the years 1970 through 1995.
5.11.2 Activity Indicator
5.11.2.1 Nonferrous Metals
The activity indicator for copper roasting was based on the primary copper smelter production from
domestic and foreign ores from Reference la. Copper smelter production was expressed in units of
blister copper produced. It was assumed that of the 4 tons of copper concentrate/ton of blister, only half
was roasted. Therefore, the amount of blister copper produced multiplied by 2 resulted in the activity
indicator for the roasting process.
Activity indicators for copper smelting and converting were assumed to be equivalent. Activity data
were calculated in the same manner as for the roasting process, except it was assumed that all of the
blister copper produced was smelted and converted. Therefore, units of blister copper produced
multiplied by 4 resulted in the activity indicators for the smelting and converting process.
Activity data for zinc sintering was based on the redistilled slab zinc production obtained from
Reference 2a. The activity indicator for the horizontal retort process was assumed to be zero. The
activity indicator for the vertical retort process was assigned the same value as used for zinc sintering.
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The activity indicators for lead sintering, blast furnaces, and reverberatory furnaces were assumed to
be equal to the primary refined lead production from domestic and foreign ores as listed in Reference 3.
5.11.2.2 Secondary Metals
Activity data for three copper-producing processes were obtained from Reference Ib. The
production level of high-leaded tin bronze was used as the basis for high Lead (58%) activity. The
production level of yellow brass was used as the basis for red-yellow brass (15%) activity. Other alloys
(7%) activity was based on the production level of leaded red brass and semi-red brass.
Activity indicators for three lead-producing furnace types and fugitive lead processes were obtained
from Reference 3 or 4a. The pot furnace activity was estimated as 90 percent of the total consumption of
lead scrap by all consumers obtained from Reference 4a. The activity indicator for reverberatory furnaces
was estimated by multiplying the total consumption of lead scrap by the ratio between the quantity of lead
recovered as soft lead (obtained from Reference 3b) and the total lead recovered from scrap. The activity
indicator for blast furnaces was estimated by multiplying the total consumption of lead scrap by the ratio
between lead recovered as antimonial lead and the total lead recovered from scrap. Fugitive lead activity
was assumed to be equal to the total quantity of lead recovered.
Battery production consists of five processes: (1) grid casting, (2) paste mixing, (3) lead oxide mill,
(4) three process operations, and (5) lead reclamation furnace. The number of batteries produced was
used as the activity indicator for each process. The total weight of lead used to produce storage batteries
was obtained from Reference 3c. This value was converted from metric tons to English units and was
used to calculate the number of batteries produced, expressed in thousands of batteries, as shown in
Equation 5.11-1.
Weightph x 1.10231 x 2,000 Iblton
Number of Batteries = (Eq. 5.11 -1)
1,000 x 26 Iblbattery
The activity indicator for lead reclamation furnaces was 1 percent of the number of batteries
produced as calculated above.
5.11.2.3 Miscellaneous Process Sources
The activity indicator for can soldering was the can soldering consumption as listed in Reference 3c.
If this activity indicator was not available, the previous year's value was used. The activity indicator for
cable covering was based on the value for cable covering consumption, also obtained from Reference 3c,
which was multiplied by 10 to account for recycling.
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5.11.3 Emission Factor
5.11.3.1 Nonferrom Metals
The emission factors for primary copper and lead smelting processes were obtained from References
5a and 5b, respectively. The emission factors for processes associated with primary zinc smelting were
obtained from Reference 6a. Values for these emission factors were established as the midpoint of the
emission factor ranges reported in the references cited.
5.11.3.2 Secondary Metals
The emission factors for secondary lead processing were obtained from Reference 6a. The emission
factors for secondary copper processing were obtained from Reference 5c. Battery production emission
factors were reported in Reference 5d.
5.11.3.3 Miscellaneous Process Sources
The emission factors for can soldering and can covering were obtained from Reference 5e.
5.11.4 Control Efficiency
5.11.4.1 Nonferrous Metals
The control efficiencies for all copper, zinc, and lead production processes for the years 1970
through 1984 were equivalent to the TSP control efficiencies for the same processes. The TSP control
efficiencies were derived from Reference 7 or Reference 8 using Equation 5.11-2. Values for the control
efficiency were assumed constant after the year 1984.
_ (JJE-AE)_]
\ (Eq. 5.11-2)
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
5.11.4.2 Secondary Metals
The control efficiencies for the secondary lead production processes were obtained from Reference
9.
5.11.4.3 Miscellaneous Process Sources
The control efficiencies for can soldering and cable covering were obtained from Reference 9.
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5.11.5 References
1. Minerals Yearbook, Copper. US Geological Survey (formerly Bureau of Mines), Washington, DC.
Annual.
a. Table entitled, "Copper: World Smelter Production, by Country."
b. Table entitled, "Production of Secondary Copper & Copper Alloy Products in the U.S. by Item
Produced From Scrap."
2. Minerals Yearbook, Zinc. US Geological Survey (formerly Bureau of Mines), Washington, DC.
Annual.
a. Table entitled, "Salient Zinc Statistics" (production of slab zinc from scrap).
3. Minerals Yearbook, Lead. US Geological Survey (formerly Bureau of Mines), Washington, DC.
Annual.
a. Table entitled, "Salient Lead Statistics."
b. Table entitled, "Pb Recovered from Scrap Processed in the U.S., by Kind of Scrap and Form of
Recovery."
c. Table entitled, "U.S. Consumption of Lead, by Product."
4. Minerals Yearbook, Recycling of Nonferrous Materials. US Geological Survey (formerly Bureau of
Mines), Washington, DC. Annual.
a. Table entitled, "Stocks and Consumption of New and Old Lead Scrap in the U.S. by Type of
Scrap."
5. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Table 7.3-10
b. Table 7.6-1
c. Table 7.9-1
d. Table 7.15-1
e. Table 7.17-1
6. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
7. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
8. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
9. Control Techniques for Lead Air Emissions, Volumes 1 and 2. U.S. Environmental Protection
Agency, Research Triangle Park, NC. December 1977.
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5.12 METALS PROCESSING - FERROUS: 05-02
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Industrial Processes - Lead Emissions Iron and Steel Industry (coke, blast furnace, sintering,
open hearth, BOF (Basic Oxygen Furnace), and electric
arc furnace)
Nonferrous Metals (ferroalloy production)
Secondary Metals Industry (grey iron foundries)
5.12.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator, emissions factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, activity
indicators for all source categories, except those in the iron and steel industry, were expressed in
thousand tons. For the iron and steel industry source categories, activity indicators were expressed in
million tons. All emission factors were expressed in metric pounds/tons. All control efficiencies were
expressed as dimensionless fractions.
The following procedures for determining activity indicators, emission factors, and applicable
control efficiencies were used for the years 1970 through 1995.
5.12.2 Activity Indicator
5.12.2.1 Iron and Steel
The activity indicator for coke production was the oven production figure obtained from Reference
la. The activity for coke production was assumed to be zero for all years including and following 1994.
The activity indicator for blast furnaces was the total pig iron production as reported in Reference Ib,
Reference 2a, or Reference 3. This value included exports. The activity indicator for the windbox
sintering process was the total production of pig iron, divided by 3 (two other processes [discharge,
sinter-fugitive] to not contribute to Pb emissions).
The activity indicators for open hearth, basic oxygen, and electric arc furnaces were based on the
total scrap and pig iron consumption. Reference 4 contained the total scrap and pig iron consumed by
each furnace type by manufacturers of pig iron and raw steel and castings. The fraction of the combined
quantity of scrap and pig iron consumed by each of the three furnace types was calculated. Total raw
steel production reported in Reference Ib or Reference 2a was multiplied by each fraction to obtain the
raw steel production for each furnace type.
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5.12.2.2 Nonferrom Metals
The activity indicator for ferrosilicon production was the net gross weight production obtained from
Reference 5a or 6a. Silicon manganese activity was assumed to be 42.1 percent of the net production of
ferrosilicon. Production of ferromanganese by electric furnaces was assumed to be 57.9 percent of the
net production of ferrosilicon. Production of silicon metal was obtained from Reference 6a. For
ferromanganese from blast furnaces and for Ferro-Mang (std), the activity indicators were assumed to be
zero.
Ferrochrome-silicon activity was obtained from Reference 5a or 7, and activity data for High Carbon
Ferro production was obtained from Reference 5a or 8. If these data were not available, values for the
previous year were used.
5.12.2.3 Secondary Metals
The activity indicator for cupola furnaces in grey iron foundries was based on the combined quantity
of scrap and pig iron consumed by cupola furnaces. This value was obtained from Reference 4a under
the category of iron foundries and miscellaneous users. The final activity was determined by adjusting
this production value to account for this category's respective emission factor, which was expressed in
terms of the charged quantity, and not the fresh feed quantity. This adjustment required dividing the
production value by 0.78.
The activity indicator for electric induction was based on the combined quantity of iron and steel
scrap and pig iron consumed in electric furnaces. This value was obtained from Reference 4a under the
category of iron foundries and miscellaneous users. The amount consumed was adjusted to account for
recycling by dividing the consumption value by 0.78.
5.12.3 Emission Factor
5.12.3.1 Iron and Steel
The emission factors for all processes were obtained from Reference 9a. The emission factor used
for by-product coke was the same as that established for metallurgical coke manufacturing.
5.12.3.2 Nonferrous Metals
The emission factors for all processes were set equal to the midpoint of the emission factor ranges
reported in Reference lOa.
5.12.3.3 Secondary Metals - Grey Iron Foundries
The emission factors for all processes were reported in Reference lOb.
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5.12.4 Control Efficiency
The control efficiencies for all processes included in this Tier II category for the years 1970 through
1984 were equivalent to the TSP control efficiencies for the same processes. The TSP control
efficiencies were derived from Reference 11 or Reference 12 using Equation 5.12-1. Values after the year
1984 were assumed constant.
where: CE = control efficiency
UE = emissions before control
AE = emissions after control
5.12.5 References
1. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC.
a. Table containing information on "Petroleum, Coal, and Products." SCC = 3-03-003
b. Table containing information on "Metals and Manufactures."
2. Minerals Yearbook, Iron and Steel. U.S. Geological Survey (formerly Bureau of Mines),
Washington, DC. Annual.
a. Table entitled, "Salient Iron and Steel Statistics."
b. Table entitled, "U.S. Consumption of Iron and Steel Scrap, Pig Iron, and Direct-Reduced Iron
(DRI) in 19xx, by Type of Furnace and Other Use."
3. Minerals Industry Surveys, Iron Ores. U.S. Geological Survey (formerly Bureau of Mines),
Washington, DC. Monthly.
4. Minerals Industry Surveys, Iron and Steel Scrap. U.S. Geological Survey (formerly Bureau of
Mines), Washington, DC. Monthly.
a. Table on consumption of iron and steel scrap and pig iron in the United States by type of
furnace or other use.
5. Minerals Yearbook, Ferroalloys. U.S. Geological Survey (formerly Bureau of Mines), Washington,
DC. Annual.
a. Table entitled, "Table 2. Ferroalloys Produced and Shipped from Furnaces in the U.S."
6. Minerals Yearbook, Silicon. U.S. Geological Survey (formerly Bureau of Mines), Washington, DC.
Annual.
a. "Table 1. Production, Shipments, and Stocks of Silvery Pig Iron, Ferrosilicon, and Silicon
Metal in the U.S. in 19xx"
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7. Minerals Yearbook, Chromium. U.S. Geological Survey (formerly Bureau of Mines), Washington,
DC. Annual.
8. Minerals Yearbook, Iron and Steel. US Geological Survey (formerly Bureau of Mines),
Washington, DC. Annual.
9. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
10. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Table 7.4-5
b. Table 7.10-3
11. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
12. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
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5.13
METALS PROCESSING - NOT ELSEWHERE CLASSIFIED: 05-03
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Industrial Processes - Lead Emissions
Subcategory:
Mineral Products (ore crushing)
Miscellaneous Process Sources [miscellaneous
products (type metal production)]
5.13.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator, emissions factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in thousand tons and emission factors were expressed in metric pounds/tons.
All control efficiencies were expressed as dimensionless fractions.
The following procedures for determining activity indicators, emission factors, and applicable
control efficiencies were used for the years 1970 through 1995.
5.13.2 Activity Indicator
The activity indicator for lead ore production was the gross weight of lead ore produced on a dry
weight basis as reported in Reference la or Ib. If this value is not reported on a dry weight basis, the dry
weight is estimated from the Pb ore production, in terms of recoverable Pb content, divided by 0.0799.
The activity indicator for Zn, Cu, Cu-Zn ores was estimated as the sum of the "ore produced" listed in
Reference 2a, and "all other sources" listed in Reference la. The activity data for Pb-Zn, Cu-Pb, Cu-Pb-
Zn ores was assumed to be zero. If Reference la is not available, Zn, Cu, Cu-Zn ores are estimated using
the following equation:
1.4291(jc) - 49736.557
(Eq. 5.13-1)
where: x = value for copper ore produced, in short tons.
The activity indicator for type metal production was based on the consumption of lead for type metal
production obtained from Reference 1. In accordance with procedures provided in Reference 3, this
value was multiplied by 330 to account for recycling. If the value is withheld, use the most recent
available year.
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5.13.3 Emission Factor
The emission factors for ore crushing and grinding processes were obtained from Reference 4a. The
emission factors for type metal production were obtained from Reference 4b.
5.13.4 Control Efficiency
The control efficiencies for ore crushing and grinding processes and type metal production were
obtained from Reference 3. No control efficiencies were applied to the activity data to estimate emissions
from type metal production.
5.13.5 References
1. Minerals Yearbook, Lead. U.S. Geological Survey (formerly Bureau of Mines), Washington, DC.
Annual.
a. Table entitled, "Production of Lead and Zinc in Terms of Recoverable Metals, in U.S. in 19xx,
by State."
b. Table Entitled, "Salient Lead Statistics."
2. Minerals Yearbook, Copper. U.S. Geological Survey (formerly Bureau of Mines), Washington, DC.
Annual.
a. Table entitled, "Salient Copper Statistics."
3. Control Techniques for Lead Air Emissions, Volumes 1 and 2. U.S. Environmental Protection
Agency, Research Triangle Park, NC. December 1977.
4. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Table 7.6-1
b. Table 7.17-1
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5.14
OTHER INDUSTRIAL PROCESSES - MINERAL PRODUCTS: 07-05
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Industrial Processes - Lead Emissions
Subcategory:
Mineral Products [Cement Manufacturing (wet
kiln/cooler, wet dryer/grinder, dry kiln/cooler and
dry dryer/grinder) and Glass Production (lead-
glass)]
5.14.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator, emissions factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in thousand tons and emission factors were expressed in metric pounds/tons.
All control efficiencies were expressed as dimensionless fractions.
The following procedures for determining activity indicators, emission factors, and applicable
control efficiencies were used for the years 1970 through 1995.
5.14.2 Activity Indicator
The activity indicators for wet kiln/cooler and wet dryer/grinder used in cement manufacturing were
assumed to be equal. The value used was the sum of two categories: "wet" clinker produced and "both"
clinker produced, reported in Reference la or Reference 2a. The activity indicators for dry kiln/cooler
and dry dryer/grinder were both estimated to be the sum of "dry" clinker produced and "both" clinker
produced, as reported in Reference la. The activity indicator for lead-glass production was assumed to
be zero.
5.14.3 Emission Factor
The emission factors for cement manufacturing processes were obtained from Reference 3a. The
emission factor for glass production was obtained from Reference 3b.
5.14.4 Control Efficiency
The control efficiencies for the wet and dry kiln/cooler used in cement manufacturing for the years
1970 through 1984 were equivalent to the TSP control efficiencies for kilns. The control efficiencies for
the wet and dry dryer/grinders for the years 1970 through 1984 were equivalent to the TSP control
efficiencies for grinders. These TSP control efficiencies were derived from Reference 4 or Reference 5
using Equation 5.14-1. All control efficiencies for the years following 1984 were assumed constant.
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where: CE = control efficiency
UE = emissions before control
AE = emissions after control
No control efficiencies were applied to activity data to estimate emissions from lead-glass
production.
5.14.5 References
1. Minerals Industry Surveys, Cement. US Geological Survey (formerly Bureau of Mines),
Washington, DC. Monthly.
a. Table entitled, "Clinker Produced and Fuel Consumed by the Portland Cement Industry."
2. Minerals Yearbook, Cement. US Geological Survey (formerly Bureau of Mines), Washington,
DC. Annual
a. Table entitled, "Clinker Produced and Fuel Consumed by the Portland Cement Industry in the
U.S. by process."
3. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Table 8.6-1
b. Table 8.13-1
4. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
5. Standard Computer Retrievals, NE257 report, from the National Emissions Data System (NEDS).
Unpublished computer reports. National Air Data Branch, Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle Park, NC. Annual.
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5.15 OTHER INDUSTRIAL PROCESSES - MISCELLANEOUS INDUSTRIAL
PRODUCTS: 07-10
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Industrial Processes - Lead Emissions
Subcategory:
Miscellaneous Process Sources [Lead Alkyl
Production (electrolytic process), Sodium Lead
Alloy (recovery furnace, TEL process vents, TML
process vents, and sludge pits), and Miscellaneous
Products (ammunition)]
5.15.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator, emissions factor, and
control efficiency, where applicable. In order to utilize these values in the Trends spreadsheets, activity
indicators were expressed in thousand tons and emission factors were expressed in metric pounds/tons.
All control efficiencies were expressed as dimensionless fractions.
The following procedures for determining activity indicators, emission factors, and applicable
control efficiencies were used for the years 1970 through 1995.
5.15.2 Activity Indicator
The activity indicator for lead alkyl production by the electrolytic process was based on the quantity
of lead consumed in anti-knock manufacturing obtained from Reference la. This quantity of lead was
converted to a quantity of additive by multiplying by 1.76. The activity indicator for this category was
assumed to be 10 percent of the quantity of additive consumed based on Reference 2. As of 1992, it was
assumed that there were no producers of lead alkyl products in the United States. All emissions after
1992 for this category are zero.
The activity indicator for sodium lead alloy production processes was based on the remaining 90
percent of the quantity of additive consumed as determined above for lead alkyl production. The activity
for recovery furnaces and sludge pits was assumed to be equal to the remaining quantity of additive. The
activity of TEL (TetraEthyl Lead) process vents and TML (TetraMethyl Lead) process vents was 63
percent and 37 percent, respectively, of the remaining quantity of additive. These apportionments were
based on Reference 2. As of 1992, it was assumed that there were no producers of sodium lead alloy
products in the US. All emissions after 1992 for this category are zero.
The activity indicator for ammunition production was the sum of lead consumption for the following
uses: (1) caulking lead (building construction), (2) total pipes, traps, and other extruded products, (3)
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Lead Emissions Methodology
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total sheet lead, and (4) other metal products. The consumption information was obtained from
Reference 1.
5.15.3 Emission Factor
The emission factors for lead alkyl and sodium lead alloy production processes were obtained from
Reference 3a. The emission factors for ammunition production were obtained from Reference 3b.
5.15.4 Control Efficiency
The control efficiencies for ammunition production were obtained from Reference 2. No control
efficiencies were applied to estimate emissions from the other sources included in this Tier II category.
5.15.5 References
1. Minerals Yearbook, Lead. U.S. Geological Survey (formerly Bureau of Mines), Washington, DC.
Annual.
a. Table entitled, "U.S. Consumption of Lead, by Product."
2. Control Techniques for Lead Air Emissions, Volumes 1 and 2. U.S. Environmental Protection
Agency, Research Triangle Park, NC. December 1977.
3. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Table 5.22-1
b. Table 7.17-1
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5.16 WASTE DISPOSAL AND RECYCLING : 10-01
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
Solid Waste Disposal Incineration (Municipal, Residential,
Commercial/Institutional, and Conical
Woodwaste)
5.16.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trend?, spreadsheets, activity indicators were expressed in million tons
and emission factors were expressed in metric pounds/thousand tons.
The following procedures for determining activity indicators, emission factors, and applicable
control efficiencies were used for the years 1970 through 1995.
5.16.2 Activity Indicator
The activity indicator for municipal incineration was the sum of the operating rates for the SCCs 5-
01-001-01 and 5-01-001-02 obtained from Reference 1 or 2. The activity for 1995 was calculated by
multiplying the 1990 activity by the ratio of 1995 combustion to 1990 combustion from Reference 3.
The activity indicator for residential incineration was the operating rate for residential on-site
incineration obtained from Reference 4. The activity for 1995 and 1996 was calculated by multiplying the
1994 activity obtained from reference 4 by the ratio of 1994 activity to 1995 or 1996 activity obtained
from Reference 5.
Commercial/industrial incineration was based on the sum of the operating rates provided in
Reference 1 or 2 for the following SCCs: 5-02-001-01, 5-02-001-02, 5-03-001-01, and 5-03-001-02.
The previous year's activity data reported in the Trends spreadsheet was scaled based on the ratio of the
total operating rate for the current year to the total for the previous year. This calculation is shown in
Equation 5.16-1.
(Eq. 5.16-1)
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where: A = activity indicator
I = year
OR = operating rates for SCCs 5-02-001-01, 5-02-001-02, 5-03-001-01, and 5-03-001-02
The activity for commercial/industrial incineration for the years 1995 and 1996 was calculated by
multiplying the 1994 activity obtained from Reference 1 by the ratio of 1994 emissions to 1995 or 1996
emissions obtained from Reference 5.
The activity indicator for conical woodwaste incineration was the sum of the operating rates for the
SCCs 5-02-001-05 and 5-03-001-05 obtained from Reference 1 or 2.
5.16.3 Emission Factor
The emission factors for municipal, residential, and commercial/institutional incineration were
obtained from Reference 6a or Reference 7a.
The emission factor for conical woodwaste incineration (SCC 5-02-001-05) was assumed to be zero.
5.16.4 Control Efficiency
The control efficiency associated with municipal incineration was obtained from Reference 1 or 2 for
SCC 5-01-001.
No control efficiencies were applied to the activity data to estimate emissions from the remaining
types of incineration (i.e., residential, commercial/institutional, and conical woodwaste).
5.16.5 References
1. Standard Computer Retrievals, AFP650 report, from the AIRS Facility Subsystem. Unpublished
computer reports. National Air Data Branch, Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, NC. Annual.
2. Computer Retrieval, NE257 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park,NC. February 9, 1980.
3. Characterization of Municipal Solid Waste in the United States. (1996 Update) Municipal and
Industrial Solid Waste Division, U.S. Environmental Protection Agency, Washington, DC. June
1997.
4. Computer Retrieval, NE260 report, by Source Classification Code (SCC) from the National
Emission Data System (NEDS). Unpublished computer report. National Air Data Branch, Office of
Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle
Park, NC. February 9, 1980.
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5. National Emission Trends Report. Draft Report. Prepared by E.H. Pechan and Associates, Inc.
under contract No. 68-D3-0035, work assignment III-102 for Emission Factor and Inventory Group,
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1997.
6. Compilation of Air Pollutant Emission Factors, Fourth Edition, Supplements A through D, AP-42.
U.S. Environmental Protection Agency, Research Triangle Park, NC. September 1991.
a. Table 2.1-1.
7. Compilation of Air Pollutant Emission Factors, Third Edition, Supplements 1 through 14, AP-42.
NTIS PB-275525. U.S. Environmental Protection Agency, Research Triangle Park, NC.
September 1977.
a. Appendix E
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5.17 ON-ROAD VEHICLES: 11
The emissions for all Tier II categories under this Tier I category were determined by the Lead
Emissions Methodology for the following source categories (see table 5.1-1 for Tier correspondence):
Category: Subcategory:
On-road vehicles Gasoline (leaded, unleaded)
5.17.1 Technical Approach
The lead emissions included in these Tier II categories were the sum of the emissions from the
source categories listed above. Emissions were estimated from an activity indicator and an emissions
factor. In order to utilize these values in the Trend?, spreadsheets, activity indicators were expressed in
million gallons and emission factors were expressed in metric pounds/gallons. The total lead emissions
for the Tier I category were allocated to the Tier II categories by the relative fraction of vehicle miles
traveled (VMT) for the appropriate vehicle types.
The following procedures for determining activity indicators, emission factors, and allocation to the
Tier II categories were used for the years 1970 through 1996.
5.17.2 Activity Indicator
The activity indicator for On-road vehicles was the gasoline consumption by all On-road vehicles as
reported in Reference la. If this consumption value was not available, the previous year's consumption
was adjusted based on the vehicle miles traveled (VMT) obtained from Reference 2a using Equation
5.17-1:
VMT.
GCt - GCtl x -^L- (Eq. 5.17-1)
where: GC = total gasoline consumption by all On-road vehicles
I = year of interest
VMT = vehicle miles traveled
The percentage of total unleaded gasoline was obtained from Reference 3a, and this value was
applied to the total consumption of gasoline, resulting in unleaded gasoline use. This procedure was
repeated to obtain leaded gasoline activity.
5.17.3 Emission Factor
The lead emission factors for On-road vehicles were reported in Reference 4 to be 1.5(Y) Ib/ton,
where Y is the number of grams of lead/gasoline. Y values are shown in Table 5.17-1. The values for Y
were obtained from Reference 5.
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5.17.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from On-road vehicles.
5.17.5 Allocation of Emissions to the Tier II Categories
The total lead emissions were the sum of the emissions from leaded gasoline and from unleaded
gasoline. Lead emissions from these two types of gasolines were calculated by multiplying the activity
indicator by the emission factor. In order to allocate the total lead emissions to the Tier II categories, the
relative fraction of the VMT for each of the three vehicle classifications was determined. The VMT data
for this purpose were obtained from a variety of sources. Relative VMT fractions used for the years
1940 through 1993 for each of the vehicle classifications are given in Table 5.17-2.
5.17.6 References
1. On-road vehicles Statistics. Federal On-road vehicles Administration, U.S. Department of
Transportation, Washington, DC. Annual.
a. Table MF-21, "Motor Fuel Use"
2. Welty, K. On-road vehicles Information Management, Federal On-road vehicles Administration, US
Department of Transportation, personal communications with E.H. Pechan and Associates, Inc.,
Durham, NC, 1997. (Information received on floppy diskette.)
3. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table entitled, "Finished Motor Gasoline Supply and Disposition."
4. Control Techniques for Lead Air Emissions, Volumes 1 and 2. U.S. Environmental Protection
Agency, Research Triangle Park, NC. December 1977.
5. Motor Gasolines. National Institute for Petroleum and Energy Research, IIT Research Institute,
Barltesville, OK. Summer 1987 and Summer 1990.
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Table 5.17-1. Number of Grams of Lead/Gasoline (Y)
Year
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
Leaded Gasoline
2.43
2.59
2.63
2.2
2.07
1.82
2.02
2.03
1.76
1.76
1.33
1.01
1.02
0.83
0.84
0.59
0.37
0.15
0.15
0.08
0.08
0.0002
0.0002
0.0002
0.0002
0.0002
0.0002
Unleaded
Gasoline
NA
NA
NA
0.014
0.014
0.014
0.014
0.014
0.01
0.016
0.028
0.009
0.005
0.003
0.006
0.002
0.002
0.001
0.001
0.002
0.0004
0.0002
0.0002
0.0002
0.0002
0.0002
0.0002
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Table 5.17-2. Relative VMT Fractions for Each Tier II Category
Light-Duty Gas Vehicles Light-Duty
Year and Motorcycles Gas Trucks
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
0.83
0.83
0.82
0.82
0.82
0.82
0.81
0.80
0.80
0.79
0.78
0.76
0.79
0.78
0.77
0.76
0.75
0.74
0.75
0.75
0.75
0.75
0.75
0.75
0.75
0.75
0.75
0.13
0.13
0.14
0.14
0.15
0.15
0.16
0.17
0.17
0.18
0.19
0.21
0.19
0.20
0.21
0.22
0.23
0.24
0.24
0.24
0.24
0.24
0.24
0.24
0.24
0.24
0.24
Heavy-Duty Gas
Trucks
0.04
0.03
0.03
0.03
0.03
0.03
0.03
0.03
0.03
0.03
0.03
0.03
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.01
0.01
0.01
0.01
0.01
0.01
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5.18
NON-ROAD ENGINES AND VEHICLES - NONROAD GASOLINE: 12-01
The emissions for this Tier II category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Other Non-road engines and vehicles
Vessels
Aircraft
Subcategory:
Gasoline (Farm Tractors, Other Farm Equipment,
construction, Snowmobiles, Small Utility Engines,
Heavy Duty General Utility Engines,
Motorcycles)
Gasoline
Aviation Gasoline
5.18.1 Technical Approach
The lead emissions included in this Tier category were the sum of the emissions from the source
categories listed above. Emissions were estimated from an activity indicator and an emissions factor. In
order to utilize these values in the Trends spreadsheets, activity indicators were expressed in million
gallons and emission factors were expressed in metric pounds/thousand gallons.
The following procedures for determining activity indicators, emission factors, and applicable
control efficiencies were used for the years 1970 through 1995.
5.18.2 Activity Indicator
The activity indicator for gasoline-powered farm tractors was based on the 1973 gasoline
consumption by farm tractors reported in Reference 1. The adjustment factor applied to the 1973 data
was the ratio of the quantity of gasoline consumed by all agricultural equipment in 1973 and in the year
under study as reported in Reference 2a. It is assumed that this procedure was used for the years both
before 1973 and after 1973. Equation 5.18-1 summarizes this procedure.
GC
Tractor, i
Agriculture, i
Tractor, 1973
GC
(Eq. 5.18-1)
Agriculture, 1973
where: GC = gasoline consumption
I = year under study
The activity indicator for other gasoline-powered farm equipment was also based on gasoline
consumption. It was assumed that the gasoline consumption by other farm equipment was equivalent to
8.52 percent of the quantity of gasoline consumed by farm tractors as determined by the preceding
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procedure. Activity for other farm equipment is considered zero for the year 1991 and all subsequent
years.
The activity indicator for gasoline-powered construction equipment was the total gasoline
consumption by construction equipment as reported in Reference 2.
Activity data for snowmobiles were based on the 1973 gasoline consumption by snowmobiles, as
reported in Reference 1. An adjustment factor was applied to the 1973 value to account for the ratio of
the number of snowmobile registrations in 1973 and in the year under study as reported in Reference 3.
It is assumed that this procedure was used for the years both before 1973 and after 1973. Equation 5.18-
2 summarizes this procedure.
N
(~i(~~< — C^f v Snowmobiles, i
^^Snowmobiles, i ~ ^^Snowmobiles, 1973 TT (Eq. 5.18-2)
Snowmobiles, 1973
where: GC = gasoline consumption
I = year under study
N = number of registered vehicles
Activity data for small utility gasoline engines was based on the 1980 value for gasoline consumption
by small engines (533 x 106 gallons). An adjustment factor was applied to the 1980 data to account for
the ratio of the number of single unit dwellings in 1980 and in the year under study. The number of
single unit dwellings in 1980 was obtained from Reference 4. For the year under study, the number of
single unit dwellings was estimated by adding or subtracting the number of new one-family structures
started each year between 1980 and the year under study to the number of single unit dwellings in 1980.
The number of new one-family structures started was obtained from Reference 5 for each year. It is
assumed that this procedure was used for the years both before 1973 and after 1973. Equation 5.18-3
summarizes this procedure.
Single Unit Dwellings.
Sing,e Unit
where: GC = gasoline consumption
I = year under study
The activity indicator for heavy duty general gasoline utility engines was the total gasoline consumed
by the industrial/commercial category obtained from Reference 2.
The activity indicator for motorcycles was calculated from the number of motorcycles, the average
annual Non-road engines and vehicles mileage traveled, and the median estimated average miles per
gallon. The motorcycle population and the Non-road engines and vehicles mileage were obtained from
Reference 6. The average miles per gallon (MPG) was assumed to be 44.0 miles/gallon. Activity for
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motorcycles was considered zero for the year 1995 and all subsequent years because no leaded gasoline
was consumed by motorcycles after this year. Equation 5.18-4 summarizes this calculation.
r~i(-~< _ A7 y Motorcyles, Off-highway .-,-, c 1 O /IN
^^Motorcycles ~ ^Motorcycles MPC J-lo-4;
where: GC = gasoline consumption
N = number of motorcycles
M = mileage
MPG = miles/gallon
The activity indicator for aircraft was the total national quantity of aviation gasoline supplied as
reported in Reference 7a, Reference 8a, or Reference 9a. Reference 7a was used for the years 1970
through 1978. Reference 8a was used for the years 1979 and 1980. Reference 9a was used for the years
1981 through 1995.
5.18.3 Emission Factor
The lead emission factor for the combustion of gasoline in Non-road engines and vehicles was
reported in Reference 10 to be 1.5(Y) Ib/ton, where Y is the number of grams of lead/gasoline. It was
assumed that all gasoline used for these engines was leaded. The value of Y was obtained from
Reference 11 for the years 1970 to 1988 and Reference 12 for the years 1989 to 1996.
The lead emission factor for aircraft was reported in Reference 13 to be the lead content of aviation
gasoline multiplied by the percent of lead emitted. Therefore, the emission factor is 2g/gal times 0.75.
5.18.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from Non-road engines
and vehicles.
5.18.5 References
1. Exhaust Emissions from Uncontrolled Vehicles and Related Equipment Using Internal Combustion
Engines. U.S. Environmental Protection Agency. Prepared by Southwest Research Institute, San
Antonio, TX, under Contract No. EHS-70-108. October 1973.
2. On-road vehicles Statistics. Federal On-road vehicles Administration, U.S. Department of
Transportation, Washington, DC. Annual.
a. Table MF-24
3. International Snowmobile Industry Association, 7535 Little River Turnpike, Suite 330, Annandale,
VA.
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4. American Housing Survey, Current Housing Reports, Series H-l50-83. Bureau of the Census, U.S.
Department of Commerce, Washington DC. Biennial.
5. Survey of Current Business. Bureau of Economic Analysis, U.S. Department of Commerce,
Washington, DC.
6. 19xx Motorcycle Statistical Annual. Motorcycle Industry Council, Inc., Costa Mesa, CA. Annual.
7. Annual Energy Review. DOE/EIA-0384(xx). Energy Information Administration, U.S. Department
of Energy, Washington, DC. Annual.
a. Table Entitled, "Petroleum Products Supplied to the Transportation Sector, Electric Utilities,
and Total, 1949-19xx."
8. Energy Data Report. DOE/EIA-0109(80/12). Energy Information Administration, U.S. Department
of Energy, Washington, DC. Annual.
a. Table entitled, "Comparative Supply of Disposition Statistics."
9. Petroleum Supply Annual. DOE/EIA-0340(xx/07). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table Entitled, "U.S. Supply, Disposition, and Ending Stocks of Crude Oil and Petroleum
Products, 19xx."
10. Control Techniques for Lead Air Emissions, Volumes 1 and 2. U.S. Environmental Protection
Agency, Research Triangle Park, NC. December 1977.
11. Gray, C.L. Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency.
"Transmittal of Revised Lead Mobile Source Emission Factors." Internal Memorandum to D.
Tyler.
12. Motor Gasolines. National Institute for Petroleum and Energy Research, IIT Research Institute,
Barltesville, OK. Summer 1987 and Summer 1990.
13. Locating and Estimating Air Emissions from Sources of Lead and Lead Compounds. Draft Report.
U.S. Environmental Protection Agency, Research Triangle Park, NC, July 1996.
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SECTION 6.0
NATIONAL CRITERIA POLLUTANT ESTIMATES
PROJECTIONS METHODOLOGY
6.1 INTRODUCTION
The general approach for developing the projections estimates involved using the 1995 emissions
estimates as the base year and applying growth factors and control efficiencies, as appropriate. The
following sections describe the specific procedures used for each section of the inventory: nonutility
point sources; utilities; area sources; highway mobile sources; and non-road mobile sources.
6.2 NONUTILITY POINT SOURCE PROJECTIONS
6.2.1 Growth Factors
U.S. Environmental Protection Agency (EPA) guidance for projecting emissions lists the following
economic variables (in order of preference) for projecting emissions:1
• product output
• value added
• earnings
• employment
In the absence of product output projections, EPA guidance recommends value added projections. Value
added is the difference between the value of industry outputs and inputs. U.S. Department of Commerce
Bureau of Economic Analysis (BEA) gross state product (GSP) projections represent a measure of value
added and are a fuller measure of growth than BEA's earnings projections because earnings represent
only one component of GSP. GSP measures reflect the value added to revenue from selling a product
minus the amounts paid for inputs from other firms. By incorporating inputs to production, GSP reflects
future changes in production processes, efficiency, and technological changes. BEA's GSP projections
are available by state at the 2-digit Standard Industrial Classification (SIC) code level.2
Growth factors were developed for each projection year and each 2-digit SIC from BEA GSP data
for the base year (1995) and the projection years, using the following equation:
GFy = (GSPj/(GSP95)
where: GFy = growth factor for year y
GSPy = gross state product for year y
GSP95 = gross state product for base year 1995
A file containing the growth factors used to develop Trends emission projections can be found on the
following EPA Web page: http://www.epa.gov/ttn/chief/ei_data.html.
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6.2.2 Control Assumptions/Factors
Controls applied to the projected emissions are those mandated under the Clean Air Act
Amendments of 1990 (CAAA). CAAA provisions affecting nonutility industrial point sources include:
• National volatile organic compound (VOC) rules
• Benzene national emission standards for hazardous air pollutants (NESHAPs)
• Title III 2-year and 4-year maximum achievable control technology (MACT) standards
• VOC and oxides of nitrogen (NOX) reasonably available control technology (RACT)
requirements in ozone nonattainment areas
• New Control Techniques Guidelines (CTGs)
• Ozone rate-of-progress requirements
Controls assumed for each pollutant to project emissions are described in the following sections.
6.2.2.1 VOC Controls
Control measures for VOC include RACT, new CTGs, and Title III MACT controls. The
stringency of the Title III MACT standard is based on draft or final standards where available. The
promulgation and compliance dates for the 2-year and 4-year MACT standards are listed in table 6.2-1.
For other sources, emission standards (expressed as percentage reductions in emissions) are based on
technology transfer from other categories and engineering judgement. Title III MACT controls are
generally as stringent, or more stringent, than RACT controls and are thus the dominant control option
for many source categories. VOC control efficiencies are summarized in table 6.2-2. A 100 percent rule
effectiveness (RE) is assumed for all control measures.
The Trends projections estimates do not include the following provisions which could further reduce
VOC emissions in ozone nonattainment areas:
• Ozone nonattainment areas and the northeast ozone transport region (OTR) are subject to
offset requirements for major new source growth and major modifications.
• Areas must attain the ozone standard by deadlines set according to their nonattainment
classification. The mix of VOC and NOX reductions chosen as the attainment strategy is
determined through Urban Airshed Modeling. These reduction requirements are area-specific
and are unknown for many areas at this time.
6.2.2.2 NOX Controls
Industrial point source NOX controls include NOX RACT. Major stationary source NOX emitters in
marginal and above nonattainment areas and in the northeast OTR are required to install RACT-level
controls under the ozone nonattainment related provisions of Title I. RACT control levels are specified
by each state. Representative RACT levels were chosen for each source type (see table 6.2-3) in order to
model the reductions associated with this requirement. These control levels were based on EPA
Alternative Control Techniques documents (ACTs) and an assumed RE of 100 percent. Note that NOX
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RACT was already implemented by 1996 for all nonattainment areas except Louisville, Kentucky. NOX
RACT controls in Louisville were modeled in 1996 and beyond.
6.2.2.3 CO, SO2, and PM Controls
No CO controls were applied to the projected emissions, although some CO nonattainment areas
may have adopted controls for specific point sources within the nonattainment areas. Sulfur dioxide
(SO2) nonattainment provisions of the CAA do not specify any mandatory controls for SO2 emitters,
although individual states or nonattainment areas may require further controls. No SO2 controls were
applied to the Trends projected emissions. Possible control initiatives for particulates under the CAAA
would result from the Title I provisions related to particulate matter less than 10 microns in diameter
(PM-10) nonattainment. Because review of the draft SIPs available indicate that the controls are mainly
targeting area source emitters, no PM controls were applied to the projected emissions.
6.2.3 Other Issues
An emission cap of 5.6 million tons of SO2 per year was set by the CAAA for industrial sources. If
this cap is exceeded, the Administrator may promulgate new regulations. To reflect improved fuel
efficiency for combustion sources, adjustments were made to the projected industrial, commercial/
institutional and residential combustion emissions. The adjustments to industrial emissions projections
are described below. Similar adjustments were made to the commercial/institutional and residential
emissions projections and are described in section 6.2.3.2.
6.2.3.1 Industrial Emissions Adjustments
Adjustments were made to the projected emissions for combustion sources in the industrial sector by
assuming increases in fuel efficiencies for future years. Efficiency adjustment factors (EAFs) were
developed from data on energy consumption per unit output from the U.S. Department of Energy (DOE)
publication Annual Energy Outlook 1997.4 Using 1995 as the base year, the EAFs were calculated for
each fuel (e.g., natural gas, steam coal, residual fuel, etc.) as the ratio between the base year consumption
per unit output and the projection year consumption per unit output, as shown below:
EAF = CL/C
95
where: EAFy = efficiency adjustment factor for projection year j;
Cy = consumption per unit output for projection year y
C95 = consumption per unit output for base year 1995
Table 6.2-4 shows the industrial sector EAFs calculated for each fuel for each projection year.
Source classification codes (SCCs) for the industrial sector were identified from the Tier categories
and each SCC was assigned to one of the fuel categories. These assignments were performed
electronically for most SCCs, however, some assignment had to be performed manually for certain SCCs.
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Appropriate EAFs were applied to growth-factor based emissions projections for all pollutants for
each SCC to develop the revised emissions projections. Note that no adjustments were made to the
electricity fuel sector.
6.2.3.2 Commercial/Institutional and Residential Emission Adjustments
Adjustments were made to the projected emissions for combustion sources in the commercial/
institutional and residential sectors by assuming increases in fuel efficiencies for future years. Efficiency
adjustment factors (EAFs) were developed from data on energy consumption by fuel type and square
footage obtained from the DOE publication Annual Energy Outlook 1997} It was assumed that fuel
efficiency increases if square footage increases and fuel consumption decreases. Consumption factors
(CFs) were developed for each fuel for each year by multiplying the square footage (total floor space for
commercial/institutional and average house square footage for residential) by the delivered energy
consumption by fuel.
Using 1995 as the base year, the EAFs were calculated for each fuel (e.g., natural gas, coal, etc.) as
the ratio between the base year CF and the projection year CF, as shown below:
EAFy = CFy/CF95
where: EAFy = efficiency adjustment factor for projection year j;
CFy = consumption factor for projection year y
CF95 = consumption factor for base year 1995
Table 6.2-5 shows the commercial/institutional and residential sector EAFs calculated for each fuel for
each projection year.
SCCs for the commercial/institutional and residential sectors were identified from the Tier categories
and each SCC was assigned to one of the fuel categories. These assignments were performed
electronically for most SCCs, however, some assignments had to be performed manually for certain
SCCs. Appropriate EAFs were applied to the growth factor based emissions projections for all pollutants
for each SCC to develop the revised emissions projections. Note that no adjustments were made to the
electricity fuel sector.
6.2.4 References
1. Procedures for Preparing Emissions Projections, EPA-450/4-91-019, U.S. Environmental
Protection Agency, Research Triangle Park, NC, July 1991.
2. Regional State Projections of Economic Activity and Population to 2045, U.S. Department of
Commerce, Bureau of Economic Analysis, Washington, DC, July 1995.
3. National Air Quality and Emissions Trends Report, 1995, EPA-454/R-96-005, U.S. Environmental
Protection Agency, Office of Air Quality Planning and Standards, Research Triangle Park, NC, July
1996.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-4 Projections
-------
4. Annual Energy Outlook 1997 with Projections to 2015, DOE/EIA-0383(97), U.S. Department of
Energy, Energy Information Administration, Washington, DC, December 1996.
Table 6.2-1. Compliance Dates for Promulgated 2-Year and 4-Year MACT Standards3
Source Category
Promulgation
Date
Compliance
Date
2-Year Standards:
Hazardous Organic National Emission Standards for
Hazardous Air Pollutants (NESHAP) (HON)
Commercial (point/area) and Industrial Dry-cleaning
4- Year Standards:
Aerospace Industries
Chromic Acid Anodizing (point/area)
Coke Ovens: Charging, Top Side, & Door Leaks
Commercial Sterilization Facilities (point/area)
Decorative and Hard Chromium Electroplating (point/area)
Gasoline Distribution-Stage I
Halogenated Solvent Cleaners (point/area)
Industrial Process Cooling Towers
Magnetic Tapes (Surface Coating)
Marine Vessel Loading
Off-site Waste Operations
Petroleum Refineries - other sources not distinctly listed
Polymers/Resins Group I
Polymers/Resins Group II
Polymers/Resins Group IV
Printing/Publishing (Surface Coating)
Secondary Lead Smelting (point)
Shipbuilding and Ship Repair (Surface Coatings)
Wood Furniture
February 1994
September 1993
July 1995
November 1994
October 1993
November 1994
November 1994
November 1994
November 1994
July 1994
November 1994
July 1995
May 1996
July 1995
July 1996
February 1995
May 1996
May 1996
May 1995
November 1995
November 1995
October 1994
December 1993
September 1998
January 1996
November 1993
December 1997
January 1996
December 1997
December 1997
March 1996
December 1996
September 1999
July 1999
August 1998
July 1999
March 1998
September 1999
May 1999
June 1997
December 1997
November 1997
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-5
1997-2010 Methodology
Projections
-------
Table 6.2-2. Point Source VOC Controls
VOC Control
Source Category Efficiency
National Rules
Marine vessel loading: petroleum liquids 80
TSDFs 96
Benzene NESHAP (national)
By-product coke mfg 85
By-product coke - flushing-liquor circulation tank 95
By-product coke - excess-ammonia liquor tank 98
By-product coke mfg. - tar storage 98
By-product coke mfg. - light oil sump 98
By-product coke mfg. - light oil dec/cond vents 98
By-product coke mfg. - tar bottom final cooler 81
By-product coke mfg. - naphthalene processing 100
By-product coke mfg. - equipment leaks 83
By-product coke manufacture - other 94
By-product coke manufacture - oven charging 94
Coke ovens - door and topside leaks 94
Coke oven by-product plants 94
2-Year MACT (national)
Synthetic Organic Chemical Manufacturing Industry (SOCMI) HON
-SOCMI processes 79
- VOL storage 95
- SOCMI fugitives (equipment leak detection and repair) 60
-SOCMI wastewater 0
- Ethylene oxide manufacture 98
- Phenol manufacture 98
- Acrylonitrile manufacture 98
- Polypropylene manufacture 98
- Polyethylene manufacture 98
- Ethylene manufacture 98
Dry Cleaning
- Perchloroethylene 95
- Other 70
4-Year MACT (national)*
TSDFs (offsite waste operations) 96
Shipbuilding and repair 24
Polymers and resins II 78
Polymers and resins IV 70
Styrene-butadiene rubber manufacture (polymers & resins group I) 70
Wood furniture surface coating 30
Aircraft surface coating (aerospace) 60
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-6 Projections
-------
Table 6.2-2 (continued)
VOC Control
Source Category Efficiency (%)
Petroleum Refineries: other sources
- Fixed roof petroleum product tanks 98
- Fixed roof gasoline tanks 96
- External floating roof petroleum product tanks 90
- External floating roof gasoline tanks 95
- Petroleum refinery wastewater treatment 72
- Petroleum refinery fugitives 72
- Petroleum refineries - Slowdown w/o control 78
-Vacuum distillation 72
Halogenated Solvent Cleaners
- Open top degreasing - halogenated 63
- In-line (conveyorized) degreasing - halogenated 39
Printing
- Flexographic 32
- Gravure 27
Gasoline Marketing
- Storage 5
- Splash loading 99
- Balanced loading 87
- Submerged loading 99
- Transit 5
- Leaks 39
7/10-Year MACT (national)
Paint and varnish manufacture 35
Rubber tire manufacture 70
Green tire spray 90
Automobile surface coating 79
Beverage can surface coating 57
Paper surface coating 78
Flatwood surface coating 90
Fabric printing 80
Metal surface coating 90
Plastic parts surface coating 45
Pulp and paper production 70
Agricultural chemical production 79
Pharmaceutical production 79
Polyesters 70
Fabric coating 70
Petroleum refineries - fluid catalytic cracking 70
Oil and natural gas production 90
Explosives 70
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-7 Projections
-------
Table 6.2-2 (continued)
VOC Control
Source Category Efficiency (%)
Plywood/particle board 70
Reinforced plastics 70
7/10-Year MACT (national) (continued)
Publicly-owned treatment works (POTWs) 70
Phthalate plasticizers 70
Polymers and resins III 78
Rayon production 70
Polyvinyl chloride 70
Spandex production 70
Nylon 6 production 70
Alkyd resins 70
Polyester resins 70
Chelating agents 70
New CTGs (moderate and above)
SOCMI reactor 85
SOCMI distillation 85
Printing - lithographic 44
Non-CTG and Group III CTG RACT (moderate and above)**
Carbon black manufacture 90
Whiskey fermentation - aging 85
Charcoal manufacturing 80
Cold cleaning 63
Bakeries 95
Urea resins - general 90
Organic acids manufacture 90
Leather products 90
CTG RACT (marginal and above)**
Terephthalic acid manufacture 98
Cellulose acetate manufacture 54
Vegetable oil manufacture 42
Dry cleaning - stoddard 70
Stage I - splash unloading 95
Stage I - submerged unloading 95
Open top degreasing 42
In-line (conveyorized) degreasing 42
Petroleum refineries - blowdown 98
NOTE(S): "Compliance dates for 2- and 4-year MACT standards are listed by source category in 6.2-2.
**RACT controls are effective in 1995 or 1996, depending on the geographic area.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-8 Projections
-------
Table 6.2-3. NOX Nonutility Point Source RACT Controls*
Source Category
ICI Boilers - Coal
ICI Boilers - Residual Oil
ICI Boilers - Distillate Oil
ICI Boilers - Natural Gas
ICI Boilers - Wood/Bark
ICI Boilers - Cyclone
ICI Boilers - Stoker
Internal Combustion Engines - Oil
Internal Combustion Engines - Gas
Gas Turbines - Oil
Gas Turbines - Natural Gas
Process Heaters - Distillate Oil
Process Heaters - Residual Oil
Process Heaters - Natural Gas
Adipic Acid Manufacturing
Nitric Acid Manufacturing
Glass Manufacturing - Container
Glass Manufacturing - Flat
Glass Manufacturing - Pressed/Blown
Cement Manufacturing - Dry
Cement Manufacturing - Wet
Iron & Steel Mills - Reheating
Iron & Steel Mills - Annealing
Iron & Steel Mills - Galvanizing
Municipal Waste Combustors
Medical Waste Incinerators
Open Burning
LNB = Low NOX burners
LNC2 = Low NOX burners plus overfire air
NCR = Natural gas reburning
SNCR = Selective noncatalytic reduction
IR = Ignition timing retardation
AF = Air/Fuel adjustment
ULNB = Ultra-low NOy burners
Control Strategy
LNB
LNB
LNB
LNB
None
NCR
SNCR
IR
AF + IR
Water Injection
LNB
ULNB
ULNB
ULNB
Thermal Reduction
Extended Absorption
LNB
LNB
LNB
Mid-Kiln Firing
Mid-Kiln Firing
LNB
LNB
LNB
SNCR
SNCR
None
NOX Percentage
Reduction
50
50
50
50
0
53
55
25
30
68
84
74
73
75
81
95
40
40
40
25
25
66
50
50
45
45
0
NOTE:
*RACT controls are effective in 1995 or 1996, depending on the geographic area.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-9
1997-2010 Methodology
Projections
-------
Table 6.2-4. EAFs for Industrial Sector
RATIO
CODE
sc
RO
DO
NG
RE
MCC
OP
LP
RATIO
CODE
RDO
RNG
RRE
ROF
RLP
CDO
CNG
CRE
COF
NAME
Steam Coal - Industrial
Residual Oil - Industrial
Distillate Oil - Industrial
Natural Gas - Industrial
Renewables (hydroelectric, wood, wood waste, solid waste) - Industrial
Metallurgical Coal and Coke - Industrial
Other Petroleum (pet. Coke, asphalt, road oil, lubricants, gasoline) -
Industrial
LPG - Industrial
Table 6.2-5. EAFs for Commercial
NAME
Distillate Oil - Residential
Natural Gas - Residential
Renewables (Wood) - Residential
Other Fuels (kerosene and coal) - Residential
LPG - Residential
Distillate Oil - Commercial
Natural Gas - Commercial
Renewables (Wood) - Commercial
Other Fuels (kerosene, coal, Ipg, residual fuel oil) - Commercial
1999
0.977
0.667
1.000
0.976
0.979
0.880
0.991
0.927
2000
0.977
0.778
1.000
0.970
0.979
0.840
0.973
0.909
2002
0.953
0.778
1.000
0.943
0.979
0.760
0.945
0.909
2005
0.907
0.778
0.968
0.902
0.979
0.680
0.900
0.873
2007
0.884
0.778
0.935
0.879
0.957
0.640
0.873
0.836
2008
0.884
0.667
0.935
0.868
0.957
0.640
0.864
0.836
2010
0.860
0.667
0.935
0.845
0.957
0.600
0.836
0.818
and Residential Sector
1999
0.937
1.005
0.949
0.876
0.996
0.866
1.017
1.000
0.850
2000
0.913
0.995
0.935
0.863
1.005
0.859
1.012
1.000
0.870
2002
0.857
0.973
0.895
0.841
0.979
0.821
1.003
1.000
0.855
2005
0.803
0.949
0.860
0.741
0.963
0.801
0.993
1.000
0.834
2007
0.773
0.933
0.823
0.722
0.939
0.766
0.988
1.000
0.846
2008
0.763
0.930
0.813
0.713
0.948
0.760
0.983
1.000
0.840
2010
0.727
0.916
0.795
0.697
0.927
0.748
0.981
1.000
0.826
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-10
1997-2010 Methodology
Projections
-------
6.3 UTILITY PROJECTIONS
6.3.1 Existing Unit Projections
Electric utility generation projections were based on the 1995 Trends utility database. This file was
summed to the boiler level and compared to generation data found on DOE, Energy Information
Administration (EIA) Forms 7591 and 7672 to find one-to-one boiler to generator matches. Where these
matches were found, generation data were taken from Form 767 and where a one-to-one correspondence
was not available, a heat input (MMBtu) boiler to plant, fuel type ratio was established for use in
allocating Form 759 plant level/fuel type generation to the boilers.
Heat input of the base file was totaled to the fuel/plant level and a boiler to plant level ratio was
calculated for each point. The base file was then mapped by plant to the Form 759 plant level generation
file and the boiler/plant ratio was multiplied by the Form 759 generation data to estimate boiler
generation allocation.
Additionally, boilers were mapped into the Form 767 file and when a one-to-one boiler to generator
correspondence was determined, the Form 767 generation value was used. Only in cases where plant
level generation was positive and where boiler level generation was zero or where a one-to-one boiler to
generator correspondence was not established was the Form 759 generation allocation used. The noted
exception occurred at Warrick (ORIS 6705). The baseline file for this plant showed it had several boilers
in the inventory base year. However, only Boiler 4 was determined to have operated during this period.
The additional boilers were therefore eliminated from the file.
Once base year generation was established for each of the inventory's boilers, an operating profile
type was associated based on the calculated capacity utilization factor. This factor was calculated at the
boiler level using the following equation:
Capacity Factor Utilization = Generation (GW-hr)/'[Boiler Capacity (MW) x 8.76]
where: 8.76 is the product of the 8,760 operating hours per year and the 10"3 factor converting MW to
GW.
Previously, historical capacity utilization factors were used to estimate utility profiles, however,
because generation data were available for the operating years 1990 and 1995, only the actual operating
data for that year (1995) were used. Within each profile, a maximum change in capacity factor was
established (as part of the Ozone Transport Assessment Group [OTAG] process and used in ERCAM-
NOX) to estimate future year fuel use, emissions, and generation for each unit. Table 6.3-1 presents the
profile types and their associated maximum change in capacity factors.
Total projected generation from these existing units was compared to NERC region-fuel generation
demands and new units were brought on-line or capacity utilization at existing units was decreased in
order to meet total generation.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-11 Projections
-------
6.3.2 Planned Units
Listings of electric utility units expected to begin operation over the next 10 years are published
annually by the DOE.3 Available unit-specific data for these planned units include the unit's location,
capacity, primary fuel type, and expected year of startup. These data were downloaded from the DOE's
web site and converted to dBase format.
In most cases, the planned unit data include the county that the unit is expected to be sited in. For
these units, latitude and longitude coordinates were assigned to planned units corresponding to the
centroid of the county listed for the unit. Planned units without a county designation were sited as
described below for siting generic units. The following additional unit parameters were assigned to
planned units.
Coal-Fired Oil-Fired Gas-Fired
Units Units Units
Heat Rate (Btu/kWh) 10,070 9,680 9,680
Capacity Utilization 0.90 0.20 0.90
Factor
6.3.3 Generic Units
Additional generation capacity, above that which is expected to be provided by existing and planned
utility units, will be needed in projection years to meet electricity demand. This generation demand is
assumed to be filled by units termed "generic units." Generic units were created in the utility data base to
meet the generation demands in the projection years that will not be met by existing and planned units.
Generic units are essentially place-holders used to account for emissions caused by the generation of
electricity expected to be needed in each state beyond the generation that will be provided by existing and
planned units.
Total generation demand is projected by DOE by region and fuel type. These generation forecasts
are also broken down by utility generation and nonutility generation. Table 6.3-2 presents these
generation forecasts by NERC region and fuel type. The procedure used to estimate the unmet
generation in the projection years is described below.
• Generation from the electric utility units existing in the 1995 Trends inventory and the known
planned units was estimated for the projection years by multiplying the 1995 generation at these
units by the ratio of the future capacity factor (calculated as discussed above) to the 1995
capacity factor. Units projected to retire in the future have a future year capacity factor of 0.
• The 1995 generation from the fossil-fuel fired utility units included in the Trends inventory were
totaled by state and fuel type and by federal DOE region and fuel type.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-12 Projections
-------
• The DOE regional/fuel type generation projections for 1990, 2000, and 2010 were interpolated
to give generation estimates by region and fuel type for 1996, 1999, 2005, 2007, and 2008.
• The projected generation from the existing and planned units at the regional/fuel level was
subtracted from the corresponding generation demand projection to give the generation
requirement that would need to be filled by generic units.
• Generation from generic units at the regional/fuel level was allocated at the state/fuel level
based on the fraction of each state's generation for a specific fuel type in the specific projection
year out of the total generation for that fuel in that region for the specific projection year.
• The total generic generation needed for a state was divided into individual generic combined
cycle (CC) and combustion turbine (CT) units with assumed capacities of 200 MW for oil,
450 MW for gas, and 500 MW for coal units. Other characteristics of generic units were
assumed to be the same as those listed above for planned units.
Combined cycle and combustion turbine plants have proven to be superior in terms of low emissions,
improved heat rates, low cost, load flexibility, and are showing increasing use in the electric generating
sector. As a result of these trends, it was assumed that generic units would shift to CCs (oil) and CTs
(natural gas), rather than coal-fired boilers.
The generic units were sited at existing fossil-fuel fired plant sites. When possible, generic units
were not sited in nonattainment areas. Because of the large number of generic units in some states and
the limited number of existing plant sites to choose from, a hierarchy was developed for siting the generic
units. First, in attainment areas only, generic units were sited to replace units scheduled to retire by the
projection year. Second, generic units were sited at plant sites that were constructed in 1970 or later.
New utility units generally tend to be added to sites with other relatively new units, rather than with older
units. Third, if necessary, generic units were sited at plant sites older than 1970. If additional generic
units remained to be sited after all available existing sites in attainment areas were filled, the above
hierarchy was repeated using sites in nonattainment areas.
6.3.4 Control Assumptions
Both NOX and SO2 controls were applied to the utility projections.
6.3.4.1 NOX Controls
Controlled NOX emissions at electric utility units were estimated by applying ERCAM-NOX control
strategies to meet emission rate limits. Emission rates for certain coal-fired boiler types are specified in
the CAAA's Title IV. Additional rates for units required to apply RACT controls under Title I are
specified in the NOX Supplement to the Title I General Preamble. These include emission rate limits for
oil- and gas-fired boilers. New units sited in nonattainment areas or the OTR are subject to NSR and,
therefore, more stringent emission limits. The control limits applied encompass controls specified by Title
I, Title IV, the Ozone Transport Commission's memorandum of understanding (MOU) Phase II limits,
and New Source Performance Standard (NSPS) NOX regulations.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-13 Projections
-------
Existing units located in ozone nonattainment areas or located within the OTR may be subject to
Title I requirements which include RACT for electric generating units.
Under Title IV, coal-fired boilers are subject to certain NOX emission rate limits based on their
bottom and firing types. No limits have been established for Group II boilers, however, actual emission
rate data from EPA's Acid Rain Division were used. Table 6.3-3 presents NOX emission rate limits for
Group I and II boilers as modeled. Some oil and gas plants were also subject to emission rate limit
requirements and the limits modeled in this study are included in this table. Title IV limits are applied to
boilers in ozone nonattainment areas, boilers in the OTR if unit level emissions exceed 100 tons NOX per
year, and to any Phase I unit.
In 1994, the OTR's MOU was signed by 10 northeastern states and the District of Columbia, which
required NOX controls beyond RACT on major sources (in some states). Beginning in 1999, major
sources located within the OTR's inner corridor are required to reduce NOX emissions to either 0.20 Ibs/
MMBtu or achieve a 65 percent reduction from 1990 baseline levels, as specified in the Phase II round of
control. Outer region units are required to reduce emissions to either the 0.20 Ibs/MMBtu or a 55
percent emission reduction under this plan. These reductions were modeled in projection year emission
estimates.
6.3.4.2 SO2 Controls
The electric utility SO2 reductions were developed using B2-SO2, a system built on the AIRCOST
system, which was used extensively to analyze proposed utility SO2 controls leading up to Title IV of the
CAAA. B2-SO2 develops least cost control measures at the unit/boiler level to meet a target emissions
reduction tonnage input by the user.
National reductions were developed from pre-control estimates of plant emissions and Title IV
Phase I and II emissions targets as shown below.
Year
1999
2000
2002
2005
2007
2008
2010
SO2 Emission Target
(kilotons/year)
11,060
10,216
10,329
10,442
10,295
10,148
10,002
SO2 National Reduction
Requirement
2,730
3,610
3,512
3,311
3,551
3,367
3,453
Candidate SO2 controls were developed for each of the coal burning units in the data file which
showed high enough SO2 emissions to make controls cost-effective. Three types of controls were
possible: (1) coal fuel switching; (2) wet flue gas desulfurization (FGD); and (3) 100 percent natural gas
conversion by coal plants.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-14 Projections
-------
Costs of the fuel switching control options were estimated using the most recent DOE data on cost
and quality of fuel at electricity utility plants (FERC Form 423 for 1993, 1994, and 1995).4 The FGD
options were estimated using engineering cost parameters in a format similar to the Electric Power
Research Technology (EPRI) Technology Assessment Guide approach, with cost parameters updated to
reflect the most recent information on costs. Capital costs for FGD were developed from the results of
IAPCS model for standardized units. Operating and maintenance (O&M) cost parameters were based on
experience with six retrofit scrubbers as outlined in a recent paper by DOE.5 Finally, state-level cost
adjustment factors were applied, varying from 85 to 118 percent, representing regional differences in
construction costs.
While the actual cost factors for wet scrubbing are rather complex, the algorithm results in the
following costs for a 90 percent removal scrubber on a 500 megawatt unit:
Capital recovery factor 0.11 (11 percent per year)
Capital 154.26 $/kW (1995 dollars)
O&M (total fixed + variable) 1.93 mils/kWh
The percentage reduction for the FGD options is a user-stipulated variable. However, it was found
that the maximum, 97 percent, was the least cost removal level, and was selected for all of the FGD units
the model built.
The cost fuel switching module applied different costs and modeling approaches for bituminous as
opposed to sub-bituminous coals. Fuel switching "down-rank," from bituminous to sub-bituminous, was
modeled separately.
All candidate unit control options are input to a data file and sorted by increasing incremental cost
per ton of SO2 removed. The model then selects options for each unit up to the level at which total
reductions just exceed the desired target reduction tonnage. The most expensive option selected for the
each boiler (if any) by this procedure is the control reported for the unit.
The B2-SO2 system is applied to all units, excluding those known to be retiring prior to the scenario
date. The files include known planned start-ups, and "generic" units required to meet generation
forecasts by fuel type. However, the planned and generic units will not normally be controlled, since they
must meet the Phase II standards, and any further reductions are typically found to be uneconomic.
6.3.5 Other Issues
6.3.5.1 Paniculate Matter Emissions
When fuel switching control options are applied to utility boilers to control SO2 emissions, PM
emissions change, depending on the fuel type and quality. Percent ash content of fuel was found to
directly influence the amount of PM emitted by a boiler. For this reason, ash content algorithms were
established to estimate the percent ash content in fuels chosen by the SO2 reduction model. In
conjunction with reported percent ash content in the Trends baseline file, new percent ash content values
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-15 Projections
-------
were directly ratioed to calculate new PM emission levels. This was done for both PM-10 and for every
boiler where fuel switching occurred.
6.3.6 References
1. Form 759, U.S. Department of Energy, Energy Information Administration, Washington, DC.
2. Form 767, U.S. Department of Energy, Energy Information Administration, Washington, DC.
3. Supplement to the Annual Energy Outlook 1997, U.S. Department of Energy, Energy Information
Administration, Washington, DC, electronic download, 1997.
4. Form 423, U.S. Department of Energy, Washington, DC, electronic download, 1997.
5. The Effects of Title IV of the Clean Air Act Amendments of 1990 on Electric Utilities: An Update,
DOE/EIA-0582(97), U.S. Department of Energy, Washington, DC, March 1997.
Table 6.3-1. Profile Types and Maximum Change in Capacity Factors
Historical Average
Capacity Factor
Profile Type
Maximum Change
in Capacity Factor
>90%
78 - 90%
66 - 77%
47 - 65%
20 - 46%
<20%
Base
Base with moderate turndown
Base with significant turndown
Intermediate
Peaking with long runtime
Peaking with short runtime
No change
Increase capacity factor to 90%
Increase capacity factor to 77%
Increase capacity factor to 65%
Increase capacity factor to 46%
No change
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-16
1997-2010 Methodology
Projections
-------
Table 6.3-2. Utility Projections by NERC Region and Fuel Type3
(Generation in Billions of kWh)
Region
ECAR
ERGOT
MAAC
MAIN
MAPP
NPCC/NY
NPCC/NE
SERC/FL
SERC
SPP
WSCC/NWP
WSCC/RA
WSCC/CNV
Fuel Type
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Coal
Oil
Natural
Gas
Gas
Gas
Gas
Gas
Gas
Gas
Gas
Gas
Gas
Gas
Gas
Gas
1995
450.
1.
3.
93.
2.
80.
104.
6.
11.
127.
1.
4.
108.
0.
1.
25.
7.
23.
16.
11.
13.
58.
21.
35.
340.
2.
9.
154.
0.
83.
74.
0.
5.
83.
0.
5.
32.
1.
41.
36
56
62
86
24
,34
45
,40
29
70
07
,12
65
70
35
84
86
,43
22
,20
76
84
58
39
,16
,16
58
55
,90
54
07
,11
73
33
,12
27
,51
37
38
1996
451
2
8
98
0,
95
98
7
15,
131
1
10,
99
0,
3,
23
4,
17
16,
9
15,
60,
22
28
342
5,
13,
159
0,
74
72
0,
2
89
0,
11
36
0,
26
.71
.44
.88
.23
.59
.70
.70
.33
.16
.75
.58
.09
.98
.89
.63
.25
.70
.18
.11
.00
.05
.32
.71
.19
.22
.30
.52
.73
.92
.38
.33
.08
.46
.18
.18
.81
.37
.85
.97
1999
477.00
1.46
8.26
99.06
0.48
105.58
103.58
4.79
32.27
142.19
0.78
17.04
112.64
0.90
4.45
24.70
6.65
18.98
15.49
13.37
14.95
61.61
17.47
34.90
363.05
4.33
32.68
172.28
0.45
70.24
82.44
0.58
26.26
88.94
0.18
19.90
35.80
1.22
53.24
2002
477.26
1.44
12.85
104.95
0.40
111.71
104.34
2.38
54.60
136.55
0.73
20.97
117.32
1.00
5.59
24.37
2.18
18.85
15.50
20.40
18.54
63.87
13.30
42.44
378.50
2.52
73.42
176.71
0.56
86.15
83.92
0.69
35.12
91.27
0.16
24.15
35.52
0.96
47.72
2005
494.36
1.86
20.09
105.04
0.43
125.07
101.99
2.65
79.26
121.81
0.67
54.21
121.84
0.88
14.05
24.39
1.75
27.98
15.70
20.88
23.65
67.23
14.66
52.03
396.01
3.97
83.84
177.87
0.53
103.21
85.93
0.45
43.03
93.18
0.13
32.99
47.80
0.96
41.79
2007
514.49
2.49
25.00
115.66
0.38
123.24
106.41
2.21
76.31
126.31
0.84
63.30
124.30
1.01
17.27
26.64
2.02
31.23
15.70
20.84
28.65
67.61
15.11
55.85
398.45
4.36
98.63
178.03
0.54
116.09
85.93
1.24
51.24
93.08
0.13
37.02
62.67
0.95
36.35
2010
515.09
2.47
46.47
117.07
0.32
133.63
106.35
2.19
83.43
124.81
0.74
73.93
124.81
1.13
24.60
26.95
2.39
39.34
15.70
17.88
39.99
70.10
14.20
63.33
397.28
4.39
133.58
180.88
0.51
127.09
86.37
1.35
55.12
95.29
0.13
40.87
81.07
0.89
26.49
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-17
1997-2010 Methodology
Projections
-------
Table 6.3-3. Title IV or RACT NOV Emission Rate Limits
Source Category
NOX Emission Rate Limit
(Ibs/MMBtu)*
Coal-Fired Boilers
Dry bottom, wall-fired
** Dry bottom, wall-fired (Phase I)
Dry bottom, tangentially-fired
** Dry bottom, tangentially-fired (Phase I)
Wet bottom
Cyclone
Vertically-fired
Fluidized bed combustor
Cell burner
Other
Oil/Gas-Fired Boilers
Wall-fired
Tangentially-fired
0.45
0.50
0.38
0.45
0.86
0.94
0.80
0.29
0.68
1.00
0.30
0.20
These rates are based on the draft Title IV NOX rulemaking.
Group I boilers; all others are Group II.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-18
1997-2010 Methodology
Projections
-------
6.4 AREA SOURCE PROJECTIONS
Area source projections include small stationary sources not included in the point source data base
(e.g., dry cleaners, graphic arts, industrial fuel combustion, gasoline marketing, etc.) and solvent use
(e.g., consumer solvents, architectural coatings). Highway mobile and non-road mobile are described in
sections 6.5 and 6.6, respectively.
6.4.1 Growth Factors
As with the nonutility point sources, area source growth factors were developed for each year and
each 2-digit SIC from BEA GSP data for the base year (1995) and projection years. A file containing the
growth factors used to develop Trends emission projections can be found on the following EPA Web
page: http://www.epa.gov/ttn/chief/ei_data.html.
6.4.2 Control Assumptions/Factors
Controls applied to the projected area source emissions are those mandated under the CAAA and
address VOC, NOX, and PM emissions as described below.
6.4.2.1 VOC Controls
Control measures for VOC include RACT, new CTGs, Stage II vapor recovery, federal consumer
solvent controls, and Title III MACT standards. VOC percent reduction and rule effectiveness are
summarized in table 6.4-1.
6.4.2.2 NOX Controls
As with point sources, NOX RACT had already been implemented in the 1995 emission estimates for
every nonattainment area except for the Louisville nonattainment area. NOX RACT controls were added
for Louisville for the projections. Table 6.4-2 shows the area source industrial fuel combustion NOX
RACT penetration rates.
6.4.2.3 PM Controls
For the area source projections, PM controls were implemented in PM nonattainment areas. The
controls modeled depend on the severity of PM nonattainment and the level of emissions from source
categories for which controls are available. Table 6.4-3 shows the area source PM-10 control measures.
6.4.3 Other Issues
Efficiency adjustment factors were applied to area source fuel combustion sources within the
industrial, commercial/institutional, and residential sectors. These factors were calculated using the same
procedure used for efficiency adjustment factors for nonutility point sources described in sections 6.2.3.1
and 6.2.3.2.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-19 Projections
-------
Table 6.4-1. Area Source VOC Control Measures
Control Measure
VOC
Percentage
Reduction
VOC
Rule
Effectiveness
Federal Control Measures (National)
Consumer Solvents
Architectural and Industrial Maintenance (AIM) Coatings
Onboard Refueling Vapor Recovery Systems
Treatment, Storage, and Disposal Facilities
Municipal Solid Waste Landfills
Title III MACT (National)
Wood Furniture Surface Coating
Aerospace Surface Coating
Marine Vessel Surface Coating
Halogenated Solvent Cleaners
Autobody Refinishing
Perchloroethylene Dry Cleaning
Petroleum Refinery Fugitives
SOCMI Fugitives
Title I RACT (Ozone NAAs)
Synthetic Fiber Manufacture
Pharmaceutical Manufacture
Petroleum Dry Cleaning
Bulk Terminals
Paper Surface Coating
Oil and Natural Gas Production Fields
Service Stations - Stage I
Cutback Asphalt
New CTGs (Moderate and Above)
SOCMI Batch Reactor
Web Offset Lithography
Stage II Vapor Recovery (Serious and Above, OTR)
25
25
*
94
82
30
60
24
63
37
44
78
60
54
37
44
51
78
37
95
100
78
80
100
100
100
100
100
100
100
80
100
100
100
100
80
80
80
80
80
80
80
80
80
80
The effects of onboard vapor recovery and Stage II are modeled using MOBILESa. Because MOBILESa does not model the phase-in
schedule for onboard, a series of runs were performed with different start dates and a weighted gram per gallon emission factor was
calculated.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-20
1997-2010 Methodology
Projections
-------
Table 6.4-2. Area Source Industrial Fuel Combustion NOV RACT Penetration Rates
RACT Size Cutoff
Moderate
Serious and Above
LNB Control Efficiencies
Coal
23
45
21
NOX Penetration Rate (%)
Oil
8
16
Residual: 42
Distillate: 36
Gas
11
22
31
Table 6.4-3. Area Source PM-10 Control Measures
Category
Serious
Moderate
Paved Roads
Unpaved Roads
Construction
Cattle Feedlots
Residential Wood Combustion
Agricultural Burning
Vacuum sweeping - urban and rural roads - 2
times per month to achieve 79% control level.
Penetration factor varies by road type.
Pave urban unpaved roads (96% control and
50% penetration). Water rural roads (96%
control and 25% penetration)
Dust control plan (50% control, 75%
penetration)
Watering (50% control)
Switch to natural gas (44% reduction in 2000,
74% reduction in 2010)
Propane and bale/stack burning (control level
varies from 50% to 63 % by state according to
the types of crop)
Vacuum sweeping - urban roads - 2
times per month to achieve 79% control
level. Penetration factor varies by road
type.
Pave urban paved roads (96% control
and 50% penetration)
Dust control plan (50% control, 75%
penetration)
Watering (50% control)
EPA Phase II stoves (41% reduction in
2000, 63% reduction in 2010)
Propane and bale/stack burning (control
level varies from 50% to 63% by state
according to the types of crop)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-21
1997-2010 Methodology
Projections
-------
6.5 HIGHWAY MOBILE SOURCE PROJECTIONS
This section describes how highway mobile source emissions were projected to future years. Note
that this section does not provide guidance for using the MOBILESb model. MOBILESb guidance is
available in Reference 1 .
6.5.1 VMT Projection Methodologies
The 1995 vehicle miles traveled (VMT) data were used as the starting point for calculating the
projection year VMT estimates. Growth factors used in the projection year VMT calculations were
developed at the Metropolitan Statistical Area (MSA) level by vehicle class. These VMT growth factors
were calculated by multiplying national vehicle class growth factors, calculated from national VMT
projection data by vehicle type output by EPA's MOBILE4.1 Fuel Consumption Model (FCM),2 by the
ratio of MSA-specific population growth to national population growth. The equation below illustrates
how the projection year VMT growth factors were calculated.
VMT< POP POP
py VT ,.
PY'VT'M
VMT95VTUS POP95M POPPYUS
where: VMTGFPY VT M = 1995 to projection year PY growth factor for vehicle type VT and
MSA M
VMTpY VT us = U.S. total projection year VMT for vehicle type VT obtained from the
MOBILE4.1 Fuel Consumption Model
VMT95 VT us = U.S. total 1995 VMT for vehicle type VT obtained from the
MOBILE4.1 Fuel Consumption Model
POPPY; M = Projection year population for MSA M obtained from the BEA
population projections
POP95 M = 1995 population for MSA M obtained from BEA data
POP95' us = U.S. total population for 1995 from BEA data
POPPY;US = U.S. total population for projection year PY from BEA population
projections
An electronic file was developed, containing the resultant VMT growth factors for each projection year
by MSA and vehicle type. Due to the vehicle classes used in the FCM, the light-duty gasoline truck
(LDGT) 1 and LDGT2 growth factors are identical, and motorcycles are assigned the same growth
factors as light-duty gasoline vehicles (LDGVs). Also, in determining these growth factors, heavy-duty
diesel vehicles (HDDVs) are treated as a single vehicle class.
A county correspondence file was developed that indicated which counties are included in each
MSA and rest-of-state area. Each data point in the 1995 VMT file at the county/vehicle type/road type
level was then multiplied by the corresponding VMT growth factor projected at the MSA/vehicle type
level for each projection year. These resulting projected annual VMT at the county/roadway type/vehicle
type level of detail were then temporally allocated by month. The temporal allocation procedure used the
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-22 Projections
-------
same temporal allocation factors used for the 1995 VMT allocation. Table 6.5-1 summarizes the VMT
data for the projection years by vehicle type. State-level VMT totals for the same years are shown in
table 6.5-2.
6.5.2 Registration Distribution for Projection Years Used as MOBILESb Inputs
Due to the uncertainties and shifts in the automobile and truck sales markets, creating projection
year registration distributions result in a high degree of uncertainty. Several methodologies were
considered for projecting the registration distributions. In consultation with EPA's Office of Mobile
Sources (OMS), it was determined that the default MOBILESb and PART5 registration distributions
would provide sufficiently reasonable values to use as the registration distributions for the projection
years. However, because the State-provided distributions include valuable information on local trends in
fleet turnover, any county modeled with a State-supplied registration distribution in 1995 and 1996 was
modeled with the same distribution in the projection years. All other counties were modeled with the
MOBILESb and PART5 registration distribution defaults.
6.5.3 Additional MOBILESb Inputs
Additional MOBILESb inputs include Reid vapor pressure (RVP), temperature, speed data,
operating mode, altitude, MONTH flag, and control program data. These inputs for the projection years
inventories are described in this section.
6.5.3.1 RVP Values
The RVP values calculated for 1996 for all months except May through September were used in all
of the projection years. For the months from May through September, the RVP values were replaced
with the appropriate Phase II RVP limit, using 8.7 psi in 9.0 psi areas to account for the allowable margin
of safety in meeting the RVP limits. Table 6.5-3 lists the RVP modeled by month for all areas in the
projection years.
6.5.3.2 Temperature Data
Actual temperature data are not available for the projection years. Also, due to the variability in
temperature patterns from year to year, selecting a single historical year's data to model in the projection
years would be inappropriate. Therefore, 30-year average temperature data are used in the projection
year estimates. The average minimum and maximum daily temperature for each month and state were
obtained from the Statistical Abstracts.3 A single site within each state was chosen to be representative of
the temperature conditions within the entire state. As with the temperature data for historical years,
California was modeled with two temperature regions. Table 6.5-4 shows the temperatures modeled by
state and month in the projection years.
6.5.3.3 Speed Data
The 1990 speeds used for 1995 and 1996 (obtained from the HPMS impact analysis output4) were
also used for the projection years. Table 6.5-5 presents the average speed used for each road type/vehicle
type combination.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-23 Projections
-------
6.5.3.4 Operating Mode
The operating mode assumptions of the Federal Test Procedure (FTP) were used for 1995 and 1996
were also used in the projection years MOBILESb input files.
6.5.3.5 Altitude
The entire states of Colorado, Nevada, New Mexico, and Utah were modeled as high altitude areas
for the projection years. All other states were modeled as low altitude areas.
6.5.3.6 MONTHFlag
When modeling months from January through June for the projection years, the MONTH flag within
the MOBILESb input files was set to "1" to simulate January registration distributions. For months from
July through December, the flag was set for "2" to model July registration distributions.
6.5.3.7 Additional Inputs from OTAG
In addition to the inputs described above, several additional MOBILESb inputs (trip length
distributions, alcohol fuel market shares, and diesel sales shares) were supplied by the states for the
OTAG modeling and were incorporated into the Trends MOBILESb input files. Specifically, State-
supplied trip length distribution data were applied in the 1995, 1996, and in the projection years. Table
6.5-6 summarizes the state-supplied trip length distribution data.
6.5.3.8 Control Program Inputs
6.5.3.8.1 Inspection and Maintenance Programs — The primary sources of data describing inspection
and maintenance (I/M) program inputs for the 1999, 2000, and 2002 projection years was the latest OMS
I/M program summary sheet.5 In consultation with OMS, it was agreed that the stringency rate inputs,
waiver rate inputs, and compliance rate inputs should be standardized for all areas. Stringency rate were
set to 20 percent, waiver rates were set to 3 percent, and compliance rates were set to 96 percent. These
rates are consistent with the corresponding rates included in EPA's enhanced I/M performance standard
and are by far the most common rates claimed in the modeling demonstrations submitted to EPA by the
states. There is very little variance from these rates in state I/M program plans. States may change these
rates at some time in the future, but for now they should be considered accurate. The specific inputs
modeled for each area's I/M program in 1999, 2000, and 2002 are shown in table 6.5-7. This table also
indicates which year or years the inputs were modeled in. Table 6.5-8 shows which counties each set of
I/M program inputs were applied to.
For the 2005, 2007, 2008, and 2010 projection years, the area-specific inputs were replaced with the
corresponding EPA I/M program performance standards (i.e., it was assumed that any area that is
supposed to have enhanced I/M receives full credit for it). EPA's rationale behind this approach is that in
that time frame, by whatever means, EPA is assuming I/M programs would improve to the point where
higher credits are appropriate. The split between 2002 and 2005 was a semi-arbitrary split between
current/near term years and later years. The specific inputs modeled for each of the I/M program
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-24 Projections
-------
performance standards are shown in table 6.5-9. Table 6.5-10 shows which counties each set of I/M
program inputs were applied to.
I/M program coverage for the projection years was based on data collected by EPA for OTAG and
Section 812 emission projections.6'7 During this data collection process, each state was contacted to
confirm which counties in that state would be implementing an I/M program. Each state was also asked
to indicate which of the EPA I/M program types the program would most closely resemble-high
enhanced, low enhanced, basic, or OTR low enhanced. Responses were collected from each state with a
planned CAAA I/M program. These data were used in the Trends emission projection calculations by
assigned the I/M programs defined in the OMS I/M program summary for a given state to the counties
within that state listed as having a projected I/M program.
6.5.3.8.2 Reformulated Gasoline — Table 6.5-11 lists the areas that participated in the federal
reformulated gasoline program. The only change in coverage between 1995 and 1996 and the projection
years is the addition of the Phoenix, Arizona nonattainment area. This area opted in to the program in
1997 and therefore was modeled with reformulated gasoline in the projection years, but not in 1995 or
1996.
6.5.3.8.3 Oxygenated Fuel — The areas modeled with oxygenated fuel for the projection years were the
same as those modeled with oxygenated fuel for 1995 and 1996.
6.5.3.8.4 National Low Emission Vehicle Program — A National Low Emission Vehicle (NLEV)
program was modeled in the projection years using EPA's most current (at the time the modeling was
performed) assumptions about the characteristics of the proposed NLEV program. This program was
modeled as starting in the Northeast Ozone Transport Commission (OTC) states in 1999 and in the
remaining (non-California) states in 2001. The implementation schedule of the NLEV program is shown
below.
Model Year
1999
2000
2001 and later
Federal Tier
I
Standards
30%
Transitional
LEV
Standards
40%
40%
LEV
Standards
30%
60%
100%
States in the OTC that had already adopted a LEV program on their own at this time were modeled
with the characteristics of the OTC-LEV program until the start date of the NLEV program. These
states included Massachusetts, New York, and Connecticut. The programs in Massachusetts and New
York began with the 1996 model year. The Connecticut program began with the 1998 model year. The
implementation schedule followed by these states prior to 1999 (the start year of the NLEV program)
was based on the implementation schedule of the OTC-LEV program, and is shown below. Only the
1998 model year is applicable in Connecticut.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-25 Projections
-------
Model
Year
1996
1997
1998
Federal Tier I
Standards
80%
73%
47%
Intermediate
TLEV Standards LEV Standards
20%
25%
Intermediate
LEV Standards ULEV Standards
2%
51%
ULEV Standards
2%
These implementation schedules differ from the MOBILESb default LEV implementation schedule,
which was designed to model the California LEV program. For the model to access the implementation
schedule of the NLEV program, the PROMPT flag in the applicable MOBILESb input files was set to
"5" and the name of the file containing the NLEV implementation schedule was entered when prompted
by MOBILESb. In addition to setting the PROMPT flag, the REGION flag was set to "4" to properly
model the NLEV program in the MOBILESb input files. The setting of "4" for the REGION flag
indicates that an additional line is being added to the input file to model a LEV program. The necessary
inputs for this additional program line include the start year of the LEV program and whether an
"appropriate" I/M program will be implemented in conjunction with the LEV program. The start year of
the LEV program was set to "96" for input files modeling Massachusetts and New York, "98" for input
files modeling Connecticut, "99" for input files modeling all other states within the OTC (including the
Washington, DC nonattainment area portion of Virginia), and "01" for all remaining States (including the
remainder of Virginia), except California.
With an "appropriate" I/M program, maximum benefits of the LEV program are modeled by
MOBILESb, implementing a lower set of deterioration rates (DRs). For the modeling projection years
1999, 2000, and 2002, areas implementing an IM240 program were assumed to meet this requirement
and were modeled with the maximum LEV program benefits (flag setting of "2"). These I/M programs
are identified in table 6.5-8 with an asterisk following the I/M program name. In addition, for the 2005
and later emission projections, all areas modeled with the enhanced I/M program performance standard
were modeled with this same setting. All other areas in all projection years were modeled to receive the
minimum LEV program benefits (i.e., a flag setting of "1").
The following table shows the emission standards of the Federal Tier 1 program, the transitional
LEV (TLEV) standards, the LEV standards, and the Ultra-Low Emission Vehicle (ULEV) standards.
These standards apply to the LDGV and LDGTla classes of vehicles, according to the implementation
schedules shown above. The LDGTlb category is also included in the NLEV program, but the emission
standards for these vehicles are slightly less stringent than those listed below for the lighter vehicles.
Nonmethane Organic Gas
Emission Standard (NMOG) CO NOX
Federal Tier 1 0.250 grams/mile 3.4 grams/mile 0.40 grams/mile
nonmethane hydrocarbon (NMHC)
Transitional LEV (TLEV) 0.125 grams/mile 3.4 grams/mile 0.40 grams/mile
LEV 0.075 grams/mile 3.4 grams/mile 0.20 grams/mile
ULEV 0.040 grams/mile 1.7 grams/mile 0.20 grams/mile
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-26 Projections
-------
The REGION flag, used to indicate that a LEV program is being modeled in a MOBILESb input
file, is the same flag that is used to indicate that an area is a high altitude area. An area cannot be
modeled as being both a high altitude area and having a LEV program simultaneously. Thus, when the
NLEV program was modeled for the four high altitude states, the standards modeled for LDGT2s,
HDGVs, and all diesel vehicles are those for low altitude areas. To correct this, two sets of input files
were created for the high altitude areas for projection years 2002 and beyond. In the first set, the
REGION flag was set to "4" and the additional line was added for each scenario to model the NLEV
program. In the second set, the REGION flag was set to "2" to model the high altitude standards. The
LDGV and LDGT1 emission factors from the first set of files, including the effects of the NLEV
program, were then combined with the LDGTs, HDGV, light duty diesel vehicle (LDDV), light duty
diesel truck (LDDT), HDDV, and motorcycle (MC) emission factors from the second set of files, which
included the effects of the high altitude standards. This was done by replacing the LDGV and LDGT1
emission factors created by the second, or high altitude, set of files with the LDGV and LDGT1 emission
factors created by the first, or NLEV, set of files.
6.5.3.8.5 Heavy Duty Diesel Engine Corrections and Controls —
Basic Emission Rate Corrections. The same input corrections for the basic emission rates (BERs)
for HDDVs and HDGVs used in the 1995 and 1996 input files were used for the projection year input
files. The zero mile level (ZML) and DR inputs are given below.
Vehicle
Category
HDGV
HDGV
HDDV
Model Year
1998 +
1994 +
1994-2003
ZML
(g/bhp-
hr)
3.19
NOX
DR
(g/bhp-hr/10k
mi)
0.045
voc
ZML
(g/bhp-
hr)
0.364
0.283
DR
(g/bhp-hr/10k
mi)
0.023
0.000
HDDV Controls. EPA has determined that additional reductions in NOX and NMHC emissions are
needed at the national level from heavy duty vehicles. In response, EPA has issued more stringent
emission standards for HDDVs starting with the 2004 model year. These standards are found in 40 CFR,
62, No. 203, 54694-54730, October 21, 1997. This new standard, referred to as the HDDV 2.0 g/bhp-hr
NOX standard, is not incorporated in MOBILE5b. To simulate the effects of the new HDDV standard,
BERs for heavy-duty diesel vehicles were input to MOBILE5b, as shown below. This input line was
included in the projection year files for 2005 and beyond, for both low and high altitude areas. These
input files also included the heavy-duty vehicle (HDV) BER corrections as documented above. As with
the files that only included the BER corrections, NEWFLG was set to "2."
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-27
1997-2010 Methodology
Projections
-------
NOX
Vehicle
Category Model Year
HDDV 2004 +
ZML
(g/bhp-
hr)
1.84
DR
(g/bhp-hr/10k
mi)
0.000
voc
ZML
(g/bhp-
hr)
0.257
DR
(g/bhp-hr/10k
mi)
0.000
6.5.3.8.6 California-specific Inputs — Because California's highway vehicle fleet has been subject to
different emission standards than the rest of the county, an EPA-modified version of MOBILES a,
referred to as CALI5, was used for California. Input files used with this model are essentially identical to
MOBILESa input files, and the model internally handles the different emission standards.
Phase II of California's reformulated gasoline program began on June 1, 1996. This was modeled by
setting the reformulated gasoline flag to "5" starting with the June 1996 scenarios in the CALI5 input
files and in all of the projection year files. The RVP value modeled for California in all projection years
was 7.0 psi, following EPA guidance.
California's low emission vehicle program began in 1994. This was modeled in the CALI5 input
files indicating a start year of 1994 for this program and minimum LEV credits. Because MOBILESa did
not include LDGT2s in the LEV modeling, this was carried forward to CALI5. However, California's
LEV program does include LDGT2s. To model the LDGT2s in the LEV program, additional BER input
lines were added to model the ZML and DR of the California LEV program standard for LDGT2s. Two
sets of BERs were developed-one modeling the maximum LEV benefits for LDGT2s and the other
modeling the minimum benefits. The maximum LEV benefits were applied in areas modeled with the
high enhanced I/M program beginning in 2005. Table 6.5-12 shows the ZMLs and DRs modeled for both
areas.
6.5.4 Additional PARTS Model Inputs
The HDDV VMT splits used in 1995 and 1996 were also used for the projection years. In addition,
the values developed for the average number of wheels per vehicle per vehicle class were used for all
years, including the projection years.
6.5.5 Calculation of Highway Vehicle Emission Inventories
Emissions from highway vehicles were calculated the same way (multiplying the appropriate
emission factors by the corresponding VMT values) for all years, including the projection years.
6.5.6 References
1. MOBILE5b Users Manual, U.S. Environmental Protection Agency, Office of Mobile Sources, Ann
Arbor, MI.
2. MOBILE4.1 Fuel Consumption Model (Draft), U.S. Environmental Protection Agency, Office of
Mobile Sources, Ann Arbor, MI, August 1991.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-28 Projections
-------
3. Statistical Abstract of the United States -1993, U.S. Department of Commerce, Bureau of the
Census, Washington, DC, 1994.
4. Highway Performance Monitoring System Field Manual, U.S. Department of Transportation,
Federal Highway Administration, Washington, DC, December 1987.
5. Major Modeling Elements for Operating I/M Programs, table provided by Joseph Somers, U.S.
Environmental Protection Agency, Office of Mobile Sources, to E.H. Pechan & Associates, Inc.,
February 25, 1997.
6. Ozone Transport Assessment Group (OTAG) Emission Inventory Development Report-Volume III:
Projections and Controls, Draft report prepared by E.H. Pechan & Associates, Inc., for the U.S.
Environmental Protection Agency, Research Triangle Park, NC, June 1997.
7. Emission Projections for the Clean Air Act Section 812 Prospective Analysis, External draft report
prepared by E.H. Pechan & Associates, Inc., for Industrial Economics, Inc., Cambridge, MA,
February 1997.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-29 Projections
-------
Table 6.5-1. National Annual Highway Vehicle VMT Projections by Vehicle Type
Vehicle
Type
National Annual Highway Vehicle VMT Projections (million miles/year)
1999
2000
2002
2005
2007
2008
2010
LDGV
LDGT1
LDGT2
HDGV
LDDV
LDDT
HDDV
2B HDDV
Light HDDV
Medium HDDV
Heavy HDDV
Buses
MC
TOTAL
1, 720, 746
451,510
230,022
57,188
7,970
2,931
154,067
191
4,049
15,646
126,374
7,808
11,281
2,422,820
1,750,598
465,153
236,973
58,881
5,983
2,569
159,931
798
4,203
16,241
131,184
8,105
1 1 ,476
2,691,564
1,809,586
491,886
250,592
62,357
3,529
2,028
171,272
273
4,502
77,393
140,484
8,680
11,862
2,803,112
1,901,018
531,881
270,967
67,627
2,107
1,753
188,361
233
4,957
79, 728
754,504
9,546
12,460
2,976,174
1,963,516
558,639
284,599
71,539
678
1,427
199,580
248
5,246
20,267
763,704
70,774
12,868
3,092,846
1,995,184
572,088
291,450
73,547
463
1,327
205,211
256
5,395
20,840
768,320
70,400
13,076
3,152,346
2,059,873
599,170
305,248
77,537
65
1,264
216,487
270
5,692
27,985
177,569
10,972
13,499
3,273,141
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-30
1997-2010 Methodology
Projections
-------
Table 6.5-2. Annual State VMT Totals by Year
(million miles/year)
State
Alabama
Alaska
Arizona
Arkansas
California
Colorado
Connecticut
Delaware
DC
Florida
Georgia
Hawaii
Idaho
Illinois
Indiana
Iowa
Kansas
Kentucky
Louisiana
Maine
Maryland
Massachusetts
Michigan
Minnesota
Mississippi
Missouri
Montana
Nebraska
Nevada
New Hampshire
New Jersey
New Mexico
New York
North Carolina
North Dakota
Ohio
Oklahoma
Oregon
Pennsylvania
Rhode Island
South Carolina
South Dakota
Tennessee
Texas
Utah
Vermont
Virginia
Washington
West Virginia
Wisconsin
Wyoming
Total
1995
50,628
4,121
39,653
26,653
276,372
35,059
28,043
7,517
3,467
127,809
85,384
7,945
12,297
94,189
64,551
25,986
25,152
41,095
38,647
12,590
44,881
48,054
85,702
44,072
29,558
59,347
9,440
15,808
13,974
10,643
61,013
21,149
115,091
76,054
6,545
100,788
38,490
30,034
94,518
6,894
38,722
7,668
56,213
181,096
18,781
6,206
69,811
49,248
17,422
51,396
7,045
2,422,820
1999
54,366
4,531
44,759
28,946
304,433
39,045
29,969
8,201
3,805
142,451
94,812
8,636
13,696
101,036
69,136
27,673
27,252
44,047
41 ,494
13,554
48,812
51 ,484
90,695
47,907
31,803
64,007
10,392
17,086
16,239
11,509
65,465
23,615
121,278
83,957
6,991
107,151
41 ,622
33,144
100,641
7,332
42,371
8,388
61,530
199,555
21 ,249
6,788
75,784
54,652
18,493
55,304
7,628
2,635,715
2000
55,342
4,638
46,100
29,541
311,847
40,086
30,483
8,383
3,896
147,558
97,288
8,816
14,063
102,847
70,334
28,107
27,801
44,816
42,246
13,804
49,837
52,403
91 ,988
48,906
32,383
65,222
10,639
17,412
16,832
11,738
66,633
24,265
122,919
86,034
7,108
108,831
42,446
33,955
102,206
7,443
43,329
8,576
62,920
204,410
21,903
6,939
77,357
56,073
18,772
56,307
7,784
2,691,564
2002
57,342
4,845
48,637
30,725
326,719
42,116
31 ,620
8,731
4,077
155,709
102,031
9,178
14,718
106,583
72,786
29,041
28,877
46,420
43,779
14,358
51,907
54,334
94,707
50,888
33,540
67,713
11,114
18,072
17,954
12,207
68,986
25,514
126,199
89,991
7,342
112,240
44,055
35,562
1055,545
7,698
45,266
8,948
65,559
213,615
23,179
7,245
80,599
59,005
19,341
58,420
8,080
2,803,112
2005
60,408
5,169
52,591
32,550
349,935
45,288
33,372
9,274
4,356
168,402
109,442
9,742
15,735
112,439
76,570
30,481
30,530
48,884
46,156
15,208
55,101
57,306
98,878
53,936
35,317
71,568
11,853
19,088
19,702
12,928
72,629
27,466
131,250
96,136
7,701
17,499
46,550
38,055
110,671
8,098
48,273
9,530
69,667
227,923
25,180
7,716
85,615
63,582
20,210
61,678
8,538
2,976,174
2007
62,557
5,376
55,188
33,786
365,126
48,401
34,592
9,641
4,546
176,919
114,430
10,122
16,406
116,339
79,206
31,465
31,645
50,600
47,751
15,790
57,268
59,376
101,810
55,966
36,546
74,175
12,339
19,772
20,858
13,424
75,103
28,754
134,739
100,321
7,949
121,143
48,249
39,710
114,280
8,371
50,297
9,913
72,454
237,359
26,474
8,035
89,082
66,614
20,836
63,902
8,843
3,092,846
2008
63,663
5,480
56,522
34,427
372,854
48,474
35,210
9,829
4,642
181,271
116,957
10,315
16,743
118,353
80,544
31 ,969
32,209
51 ,468
48,570
16,089
58,363
60,407
103,298
57,000
37,166
75,512
12,590
20,121
21,451
13,673
76,370
29,412
136,501
102,464
8,074
123,024
49,111
40,548
116,115
8,516
51,340
10,112
73,870
242,198
27,144
8,199
90,839
68,151
21,162
65,030
8,996
3, 1 52,346
2010
65,874
5,695
59,235
35,704
388,693
50,672
36,454
10,212
4,838
190,143
122,143
10,711
17,436
122,367
83,254
32,985
33,362
53,218
50,212
16,693
60,606
62,536
106,314
59,083
38,421
78,211
13,094
20,822
22,657
14,185
78,932
30,752
140,085
106,815
8,328
126,769
50,865
42,256
119,828
8,803
53,440
10,506
76,742
252,007
28,493
8,528
94,403
71,312
21,813
67,326
9,309
3,273,141
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-31
1997-2010 Methodology
Projections
-------
Table 6.5-3. Monthly RVP Values Modeled in Projection Years
(in psi)
State
AL
AL
AK
AZ
AZ
AR
CA
CO
CT
DE
DC
FL
FL
FL
GA
GA
HI
ID
IL
IN
IA
KS
KY
LA
LA
LA
ME
MD
MD
MD
MD
MD
MA
Ml
MN
MS
MO
MO
MT
NE
NV
NV
NH
NJ
NM
NY
NC
NC
NC
NC
ND
OH
OK
OR
OR
Nonattainment Area or
Other Applicable Area
Birmingham
Rest of State
Entire State
Phoenix
Rest of State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Miami-Ft Laud-W Pirn Bea
Tampa-St Petersbg-Clrwtr
Rest of State
Atlanta
Rest of State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Entire State
Baton Rouge
Lake Charles
Rest of State
Entire State
Baltimore
Phila- Wilmington-Trenton
Washington DC
Kent & Queen Anne Cos
Rest of State
Entire State
Entire State
Entire State
Entire State
St. Louis
Rest of State
Entire State
Entire State
Reno
Rest of State
Entire State
Entire State
Entire State
Entire State
Charlotte-Gastonia
Greensboro
Raleigh-Durham
Rest of State
Entire State
Entire State
Entire State
Portland-Vancouver
Rest of State
Jan
12.4
12.4
14.1
8.7
8.7
13.7
7.0
13.2
13.0
13.5
12.8
11.8
11.8
11.8
12.4
12.4
10.0
13.9
14.1
14.5
14.9
14.0
14.2
12.4
12.4
12.4
13.2
13.2
13.2
13.2
13.2
13.2
12.9
14.1
14.9
13.7
13.9
13.9
13.8
14.5
10.5
10.5
12.9
13.7
11.7
14.3
12.4
12.4
12.4
12.4
14.9
14.6
13.9
13.1
13.1
Feb
12.4
12.4
14.1
7.9
7.9
13.7
7.0
12.1
13.0
13.5
10.3
11.8
11.8
11.8
12.4
12.4
10.0
12.3
14.1
14.5
14.9
12.1
11.7
12.4
12.4
12.4
13.2
13.2
13.2
13.2
13.2
13.2
12.9
14.1
14.9
13.7
11.9
11.9
13.8
14.5
9.2
9.2
12.9
13.7
11.7
14.3
12.4
12.4
12.4
12.4
14.9
14.6
13.9
10.8
10.8
Mar
9.5
9.5
14.1
7.2
7.2
9.8
7.0
10.7
10.8
11.1
10.3
7.4
7.4
7.4
9.4
9.4
10.0
12.3
11.4
12.0
13.3
9.5
11.7
9.6
9.6
9.6
11.0
10.8
10.8
10.8
10.8
10.8
10.7
11.2
12.6
9.8
11.9
11.9
12.3
12.7
8.2
8.2
10.7
11.3
10.2
11.9
12.4
12.4
12.4
12.4
13.3
12.1
10.1
10.8
10.8
Apr
9.5
9.5
14.1
7.2
7.2
9.8
7.0
10.7
10.8
11.1
7.0
7.4
7.4
7.4
9.4
9.4
10.0
10.2
11.4
12.0
11.2
9.5
8.4
9.6
9.6
9.6
11.0
10.8
10.8
10.8
10.8
10.8
10.7
11.2
12.6
9.8
9.2
9.2
10.2
10.4
8.2
8.2
10.7
11.3
9.1
11.9
9.4
9.4
9.4
9.4
13.3
12.1
10.1
10.8
10.8
May
7.8
8.7
9.5
7.8
8.7
8.7
7.0
8.7
8.7
8.7
7.8
7.8
7.8
8.7
7.8
8.7
9.5
8.7
8.7
8.7
8.7
8.7
8.7
7.8
7.8
8.7
8.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
7.8
8.7
8.7
8.7
7.8
8.7
8.7
8.7
8.7
8.7
7.8
7.8
7.8
8.7
8.7
8.7
8.7
7.8
8.7
Jun
7.8
8.7
9.5
7.8
8.7
8.7
7.0
8.7
8.7
8.7
7.8
7.8
7.8
8.7
7.8
8.7
9.5
8.7
8.7
8.7
8.7
8.7
8.7
7.8
7.8
8.7
8.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
7.8
8.7
8.7
8.7
7.8
8.7
8.7
8.7
8.7
8.7
7.8
7.8
7.8
8.7
8.7
8.7
8.7
7.8
8.7
Jul
7.8
8.7
9.5
7.8
8.7
8.7
7.0
8.7
8.7
8.7
7.8
7.8
7.8
8.7
7.8
8.7
9.5
8.7
8.7
8.7
8.7
8.7
8.7
7.8
7.8
8.7
87.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
7.8
8.7
8.7
8.7
7.8
8.7
8.7
8.7
8.7
8.7
7.8
7.8
7.8
8.7
8.7
8.7
8.7
7.8
8.7
Aug
7.8
8.7
9.5
7.8
8.7
8.7
7.0
8.7
8.7
8.7
7.8
7.8
7.8
8.7
7.8
8.7
9.5
8.7
8.7
8.7
8.7
8.7
8.7
7.8
7.8
8.7
8.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
7.8
8.7
8.7
8.7
7.8
8.7
8.7
8.7
8.7
8.7
7.8
7.8
7.8
8.7
8.7
8.7
8.7
7.8
8.7
Sep
7.8
8.7
9.5
7.8
8.7
8.7
7.0
8.7
8.7
8.7
7.8
7.8
7.8
8.7
7.8
8.7
9.5
8.7
8.7
8.7
8.7
8.7
8.7
7.8
7.8
8.7
8.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
7.8
8.7
8.7
8.7
7.8
8.7
8.7
8.7
8.7
8.7
7.8
7.8
7.8
8.7
8.7
8.7
8.7
7.8
8.7
Oct
9.5
9.5
14.1
6.8
6.8
9.8
7.0
9.6
10.8
7.9
7.0
7.4
7.4
7.4
9.4
9.4
10.0
8.6
7.8
8.7
11.2
7.6
8.4
9.6
9.6
9.6
11.0
7.5
7.5
7.5
7.5
7.5
10.7
11.2
9.6
9.8
9.2
9.2
10.2
8.6
7.6
7.6
10.7
11.3
9.1
11.9
9.4
9.4
9.4
9.4
11.2
8.7
7.2
7.7
7.7
Nov
9.5
9.5
14.1
7.2
7.2
13.7
7.0
10.7
10.8
11.1
10.3
7.4
7.4
7.4
9.4
9.4
10.0
10.2
11.4
12.0
13.3
9.5
11.7
9.6
9.6
9.6
1.0
10.8
10.8
10.8
10.8
10.8
10.7
11.2
12.6
9.8
11.9
11.9
12.3
10.4
8.2
8.2
10.7
11.3
10.2
11.9
12.4
12.4
12.4
12.4
13.3
12.1
10.1
10.8
10.8
Dec
12.4
12.4
14.1
7.9
7.9
13.7
7.0
12.1
13.0
13.5
12.8
11.8
11.8
11.8
12.4
12.4
10.0
12.3
14.1
14.5
14.9
12.1
14.2
12.4
12.4
12.4
13.2
13.2
13.2
13.2
13.2
13.2
12.9
14.1
14.9
13.7
11.9
11.9
13.8
12.7
9.2
9.2
12.9
13.7
11.7
14.3
12.4
12.4
12.4
12.4
14.9
14.6
13.9
13.1
13.1
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-32
1997-2010 Methodology
Projections
-------
Table 6.5-3 (continued)
State
PA
Rl
SC
SC
SD
TN
TN
TN
TN
TX
TX
TX
TX
TX
UT
UT
VT
VA
VA
VA
VA
VA
WA
WV
Wl
WY
Nonattainment Area or
Other Applicable Area
Entire State
Entire State
Cherokee Co SC
Rest of State
Entire State
Knoxville
Memphis
Nashville
Rest of State
Beaumont-Port Arthur
Dallas-Fort Worth
El Paso
Houstn-Galvestn-Brazonia
Rest of State
Salt Lake City
Rest of State
Entire State
Norfolk-Virginia
Richmond-Petersburg
Washington DC
Smyth Co VA
Rest of State
Entire State
Entire State
Entire State
Entire State
Jan
14.4
12.9
12.4
12.4
14.9
12.7
12.7
12.7
12.7
12.2
12.2
12.2
12.2
12.2
13.2
13.2
14.9
12.6
12.6
12.6
12.6
12.6
14.0
14.6
14.6
13.5
Feb
14.4
12.9
12.4
12.4
14.9
12.7
12.7
12.7
12.7
12.2
12.2
12.2
12.2
12.2
12.1
12.1
14.9
10.2
10.2
10.2
10.2
10.2
14.0
14.6
14.6
13.5
Mar
12.0
10.7
12.4
12.4
13.3
12.7
12.7
12.7
12.7
10.0
10.0
10.0
10.0
10.0
12.1
12.1
12.6
10.2
10.2
10.2
10.2
10.2
11.6
12.1
12.2
12.1
Apr
12.0
10.7
9.4
9.4
11.2
9.5
9.5
9.5
9.5
10.0
10.0
10.0
10.0
10.0
10.7
10.7
12.6
7.1
7.1
7.1
7.1
7.1
11.6
12.1
12.2
10.2
May
8.7
8.7
7.8
8.7
8.7
7.8
7.8
7.8
8.7
7.8
7.8
7.8
7.8
8.7
7.8
8.7
8.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
Jun
8.7
8.7
7.8
8.7
8.7
7.8
7.8
7.8
8.7
7.8
7.8
7.8
7.8
8.7
7.8
8.7
8.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
Jul
8.7
8.7
7.8
8.7
8.7
7.8
7.8
7.8
8.7
7.8
7.8
7.8
7.8
8.7
7.8
8.7
8.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
Aug
8.7
8.7
7.8
8.7
8.7
7.8
7.8
7.8
8.7
7.8
7.8
7.8
7.8
8.7
7.8
8.7
8.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
Sep
8.7
8.7
7.8
8.7
8.7
7.8
7.8
7.8
8.7
7.8
7.8
7.8
7.8
8.7
7.8
8.7
8.7
7.8
7.8
7.8
7.8
8.7
8.7
8.7
8.7
8.7
Oct
12.0
10.7
9.4
9.4
9.6
9.5
9.5
9.5
9.5
8.3
8.3
8.3
8.3
8.3
9.6
9.6
12.6
7.1
7.1
7.1
7.1
7.1
8.5
8.8
9.0
8.8
Nov
12.0
10.7
12.4
12.4
11.2
12.7
12.7
12.7
12.7
10.0
10.0
10.0
10.0
10.0
10.7
10.7
12.6
10.2
10.2
10.2
10.2
10.2
11.6
12.1
12.2
10.2
Dec
14.4
12.9
12.4
12.4
13.3
12.7
12.7
12.7
12.7
12.2
12.2
12.2
12.2
12.2
12.1
12.1
14.9
12.6
12.6
12.6
12.6
12.6
14.0
14.6
14.6
12.1
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-33
1997-2010 Methodology
Projections
-------
Table 6.5-4. Projection Year Monthly Temperature Inputs (°F)
January
State Max Min Ambient
Alabama 60 40 49.9
Alaska 29 19 24.2
Arizona 66 41 53.6
Arkansas 49 29 39.1
California (LA) 66 48 56.8
California (SF) 56 42 48.7
Colorado 43 16 29.7
Connecticut 33 16 24.5
Delaware 39 22 30.6
DC 42 27 34.6
Florida 75 59 67.2
Georgia 50 32 41.0
Hawaii 80 66 72.9
Idaho 36 22 29.0
Illinois 29 13 21.0
Indiana 34 17 25.5
Iowa 28 11 19.4
Kansas 40 19 29.5
Kentucky 40 23 31.8
Louisiana 61 42 51.3
Maine 30 11 20.9
Maryland 40 23 31.8
Massachusetts 36 22 28.7
Michigan 30 16 23.0
Minnesota 21 3 11.8
Mississippi 56 33 44.2
Missouri 35 17 25.7
Montana 31 12 21.1
Nebraska 31 11 21.1
Nevada 45 21 32.9
New Hampshire 30 7 18.6
New Jersey 40 21 30.9
New Mexico 47 22 34.3
New York 38 25 31.5
North Carolina 49 29 38.9
North Dakota 20 0 9.3
February
Max Min Ambient
64 43 53.2
34 23 28.4
71 45 57.7
54 33 43.6
66 49 57.6
59 45 52.2
47 20 33.4
36 19 27.5
42 25 33.4
46 29 37.5
76 60 68.5
55 34 44.8
80 65 73.0
44 28 35.9
34 17 25.4
38 21 29.6
34 16 24.7
46 24 34.8
45 26 35.7
64 44 54.3
33 14 23.3
44 26 34.8
38 23 30.3
33 18 25.5
27 9 17.9
60 36 47.9
41 22 31.2
38 17 27.4
37 17 26.9
52 24 38.0
33 10 21.7
42 24 33.0
54 26 40.0
40 27 33.6
53 31 42.0
26 5 15.8
March
Max Min Ambient
71 50 60.5
39 27 32.7
76 49 62.2
64 42 53.1
66 50 58.0
61 46 53.3
52 26 39.0
47 28 37.5
52 33 42.6
56 38 47.1
79 64 71.7
64 42 53.4
82 67 74.4
53 32 42.4
46 28 37.2
51 32 41.4
47 28 37.3
57 34 45.4
56 36 46.3
72 52 61 .6
41 24 33.0
54 34 44.1
46 31 38.6
44 27 35.7
39 23 31.0
69 44 56.7
53 33 42.7
44 23 33.3
49 28 38.6
56 29 42.8
43 22 32.5
52 31 41.5
61 32 46.8
50 35 42.4
62 39 50.4
38 18 28.2
April
Max Min Ambient
78 57 67.8
47 32 39.7
84 55 69.9
73 51 62.1
67 53 60.1
64 47 55.6
62 34 48.2
60 38 48.7
63 42 52.2
67 46 56.6
82 68 75.1
73 50 61.5
83 69 75.8
61 37 49.1
59 39 48.6
63 42 52.4
62 40 50.9
68 44 56.4
67 45 56.4
78 58 68.5
52 34 43.2
64 42 53.4
56 40 48.1
58 37 47.3
56 36 46.4
77 52 64.7
65 44 54.5
55 32 43.6
64 40 51 .9
64 33 48.5
56 32 43.9
61 39 50.0
71 40 55.2
61 44 52.5
72 46 59.0
55 31 43.0
May
Max Min Ambient
85 64 74.5
55 39 47.0
94 64 78.8
81 59 70.2
69 56 62.7
66 50 58.1
71 44 57.2
72 48 59.6
73 52 62.6
76 57 66.4
85 72 78.7
80 59 69.2
85 70 77.5
71 44 57.5
70 48 58.9
74 52 62.8
73 52 62.3
77 54 65.6
76 55 65.4
84 65 74.8
63 43 53.3
74 53 63.4
67 50 58.2
70 47 58.4
69 48 58.5
84 60 72.0
74 54 64.1
65 41 53.1
74 51 62.5
73 40 56.5
69 41 55.2
71 50 60.4
80 49 64.2
72 54 62.7
79 55 67.0
68 42 55.0
June
Max Min Ambient
90 71 80.4
61 45 53.0
104 73 88.2
89 67 78.4
72 60 65.7
70 53 61.5
81 52 66.9
80 57 68.5
81 62 71.5
85 66 75.6
88 75 81.4
86 66 76.0
86 72 79.4
81 52 66.5
80 58 68.6
83 61 71.9
82 61 71.7
87 65 75.7
84 63 73.2
89 71 80.0
73 52 62.4
83 62 72.5
76 59 67.7
79 56 67.6
79 58 68.2
91 67 78.9
83 63 73.2
75 49 61.6
84 60 72.1
83 47 65.0
77 51 64.3
80 59 69.4
90 58 74.2
80 63 71.6
85 64 74.3
77 52 64.4
-------
Table 6.5-4 (continued)
January
State Max Min Ambient
Ohio 34 18 26.3
Oklahoma 47 25 36.0
Oregon 45 11 28.4
Pennsylvania 38 23 30.4
Rhode Island 37 19 27.9
South Carolina 55 32 43.7
South Dakota 24 3 1 3.8
Tennessee 46 26 36.2
Texas 54 33 43.4
Utah 36 19 27.9
Vermont 25 8 16.3
Virginia 46 26 35.7
Washington 45 35 40.1
West Virginia 41 23 32.1
Wisconsin 26 12 18.9
Wyoming 38 15 26.5
February
Max Min Ambient
38 21 29.6
52 30 40.9
51 14 32.3
41 25 32.9
38 21 29.6
59 34 46.8
30 10 19.7
51 30 40.4
59 37 47.9
44 25 34.1
28 9 18.2
49 28 38.7
50 37 43.5
45 26 35.5
30 16 23.0
40 18 29.3
March
Max Min Ambient
50 31 40.9
62 38 50.3
56 24 40.3
52 33 42.4
46 29 37.5
68 42 55.2
42 23 32.5
61 39 50.2
68 46 56.7
52 31 41.8
39 22 30.7
60 36 47.9
53 38 45.6
57 35 45.9
40 26 33.3
45 22 33.5
April
Max Min Ambient
62 40 51 .0
72 49 60.4
61 34 47.4
63 42 52.4
57 38 47.4
76 49 63.0
59 35 46.9
71 48 59.2
76 55 65.5
61 38 49.6
54 34 43.9
70 45 57.3
57 41 49.2
67 43 54.8
53 36 44.4
55 30 42.4
May
Max Min Ambient
72 50 61 .2
79 58 68.4
67 43 55.3
73 53 62.9
67 47 57.3
84 58 70.9
71 46 58.3
79 57 67.7
83 63 72.8
72 46 58.8
67 45 56.3
78 54 66.0
64 46 55.1
76 52 63.5
64 45 54.6
65 39 52.0
June
Max Min Ambient
80 58 69.2
87 66 76.7
74 52 63.1
82 62 71 .8
77 57 66.9
89 66 77.4
80 56 68.3
86 65 75.6
92 70 81 .0
83 55 69.1
76 55 65.2
85 63 73.9
70 52 60.9
83 60 71.5
75 55 65.0
74 48 61 .4
-------
Table 6.5-4 (continued)
July
State Max Min Ambient
Alabama 91 73 82.3
Alaska 64 48 56.0
Arizona 106 81 93.5
Arkansas 92 72 82.0
California (LA) 75 63 69.1
California (SF) 72 54 62.8
Colorado 88 59 73.4
Connecticut 85 62 73.6
Delaware 86 67 76.4
DC 88 71 80.0
Florida 89 76 82.6
Georgia 88 70 78.8
Hawaii 88 74 80.5
Idaho 90 58 74.0
ON Illinois 84 63 73.2
w Indiana 86 65 75.4
ON
Iowa 87 66 76.6
Kansas 93 70 81.4
Kentucky 87 67 77.2
Louisiana 91 73 81.9
Maine 79 58 68.6
Maryland 87 67 77.0
Massachusetts 82 65 73.5
Michigan 83 61 72.3
Minnesota 84 63 73.6
Mississippi 92 70 81.5
Missouri 89 68 78.5
Montana 83 53 68.3
Nebraska 88 66 76.9
Nevada 92 51 71.6
New Hampshire 82 56 69.5
New Jersey 84 65 74.7
New Mexico 92 64 78.5
New York 85 68 76.8
North Carolina 88 68 78.1
North Dakota 84 56 70.4
August
Max Min Ambient
90 73 81.7
63 47 55.0
104 79 91.5
91 70 80.6
77 64 70.4
72 55 63.7
86 57 71.4
83 60 71.6
84 66 75.0
87 70 78.5
89 77 82.9
87 69 78.1
89 74 81.5
88 57 72.5
82 62 71.7
84 63 73.2
84 64 73.9
91 68 79.3
86 66 75.8
90 73 81.5
77 57 67.3
85 66 75.6
80 64 71 .9
81 60 70.5
81 60 70.5
92 70 80.9
86 66 76.1
82 52 66.9
85 63 74.1
90 50 69.6
80 55 67.3
83 64 73.4
89 63 75.8
84 67 75.5
87 68 77.2
83 54 68.3
September
Max Min Ambient
87 69 77.8
56 43 49.4
98 73 85.6
85 64 74.1
77 63 69.9
74 55 64.4
77 48 62.3
75 52 63.3
78 58 68.0
80 62 71.3
88 76 81 .9
82 64 72.7
88 74 81 .0
77 48 62.6
75 54 64.4
78 56 66.6
76 54 65.1
81 59 70.3
80 59 69.5
87 70 78.1
69 49 59.1
78 58 68.5
73 57 64.8
74 52 63.2
71 50 60.5
88 64 75.9
78 57 67.5
70 44 56.6
76 54 65.1
80 41 60.4
72 46 58.8
77 56 66.1
82 55 68.6
76 60 68.2
81 61 71.1
71 43 57.0
October
Max Min Ambient
80 57 68.4
47 37 42.2
88 61 74.5
75 51 63.0
74 59 66.8
70 52 61 .0
66 36 51 .4
64 41 52.2
67 46 56.2
69 50 59.7
84 72 78.3
73 52 62.3
87 72 79.6
65 39 51.8
63 42 52.8
66 44 54.7
64 43 53.5
71 47 58.6
69 46 57.5
79 59 69.1
59 38 48.5
67 46 56.6
63 47 54.8
62 41 51.2
59 39 48.8
79 50 64.7
68 46 56.6
59 36 47.6
66 41 53.4
69 33 50.8
61 35 47.8
66 44 54.9
71 43 57.0
65 50 57.5
72 48 60.0
59 32 45.6
November
Max Min Ambient
70 49 59.7
37 27 32.0
75 49 61.9
63 42 52.1
70 53 61.6
62 47 54.8
52 25 39.0
51 33 41.9
56 37 46.3
58 41 49.7
80 67 73.6
63 43 53.1
84 70 77.2
49 31 39.9
48 32 40.0
52 34 43.0
48 30 39.0
55 34 44.6
57 37 47.1
71 51 61.1
47 30 38.7
56 37 46.8
52 38 45.3
48 32 40.2
41 25 33.1
69 42 55.8
53 34 43.1
44 24 33.9
49 29 39.0
54 27 40.3
47 27 37.1
56 36 45.8
57 31 44.3
54 41 47.6
63 40 51.2
39 18 28.6
December
Max Min Ambient
63 43 53.0
32 23 27.1
66 42 54.0
52 33 42.8
66 48 56.9
56 43 49.4
44 17 31.0
38 21 29.4
44 28 35.8
47 32 39.4
77 62 69.1
54 35 44.5
81 67 74.1
38 22 30.1
34 19 26.6
38 23 30.9
33 16 24.4
43 23 33.0
45 29 36.9
64 45 54.6
35 18 26.5
45 28 36.7
40 27 33.6
35 21 28.3
26 10 17.9
60 36 47.8
39 22 30.4
33 15 23.9
35 16 25.1
46 20 32.7
34 14 24.3
45 26 35.8
48 23 35.3
42 31 36.6
53 32 42.6
24 3 13.9
-------
Table 6.5-4 (continued)
July
State Max Min Ambient
Ohio 84 63 73.2
Oklahoma 93 71 82.0
Oregon 80 58 69.1
Pennsylvania 86 67 76.7
Rhode Island 82 63 72.7
South Carolina 92 70 80.8
South Dakota 86 62 74.3
Tennessee 90 69 79.2
Texas 96 74 85.3
Utah 92 64 78.0
Vermont 81 60 70.5
Virginia 88 68 78.0
Washington 75 55 65.2
West Virginia 86 64 75.1
Wisconsin 80 62 71.0
Wyoming 82 55 68.4
August
Max Min Ambient
82 61 71.5
92 70 81.1
80 57 68.7
85 66 75.5
81 62 71.3
90 69 79.7
83 59 71.4
88 68 78.1
96 74 84.9
89 62 75.6
78 58 67.9
87 66 76.8
75 56 65.5
84 63 73.9
78 61 69.3
80 53 66.4
September
Max Min Ambient
76 55 65.5
84 62 73.0
75 49 61.8
78 59 68.2
74 54 64.1
85 63 74.2
73 49 60.9
82 61 71.8
88 67 77.4
79 51 65.1
69 49 58.9
81 59 70.0
69 52 60.6
79 56 67.7
71 53 61.7
71 44 57.4
October
Max Min Ambient
64 43 53.7
74 50 62.0
64 38 51 .2
66 46 56.4
64 43 53.6
76 50 63.2
61 36 48.6
72 48 60.4
78 56 67.2
66 40 53.2
57 39 47.8
71 46 58.6
60 46 52.8
68 44 56.2
59 42 50.3
60 34 47.0
November
Max Min Ambient
51 34 42.9
60 39 49.5
53 30 41.5
55 38 46.4
53 35 44.0
68 42 54.7
43 23 33.0
60 40 50.0
67 45 56.1
51 31 40.9
44 30 36.8
61 38 49.6
50 40 45.3
57 36 46.8
45 31 37.7
47 24 35.3
December
Max Min Ambient
39 25 31.9
50 29 39.3
46 18 31.7
43 28 35.8
41 24 32.8
59 35 46.9
28 9 18.3
50 31 40.6
58 36 46.9
38 22 29.7
30 16 23.0
50 30 40.1
45 36 40.5
46 28 37.0
31 18 24.4
39 17 27.8
--J
-------
Table 6.5-5. Average Speeds by Road Type and Vehicle Type
(MPH)
Rural
Principa Minor Major Minor
Interstate 1 Arterial Collector Collector Loca
Arterial 1
LDV 60 45 40 35 30 30
LOT 55 45 40 35 30 30
HDV 40 35 30 25 25 25
Urban
Other Freeways Principa Minor
Interstate & Expressways 1 Arterial Collector Loca
Arterial 1
LDV 45 45 20 20 20 20
LOT 45 45 20 20 20 20
HDV 35 35 15 15 15 15
Table 6.5-6. State-Supplied Trip Length Distribution Inputs
Percentage of Total VMT Accumulated in Trips of:
<10 11 to 20 21 to 30 31 to 40 41 to 50
Nonattainment Area Minutes Minutes Minutes Minutes Minutes
Washington, DC/MD/VA 16.6 33.9 23.4 13.3 6.1
Baltimore 15.1 31.7 26 13.3 6.5
Houston 14.8 27.9 22.4 14.3 8.5
Dallas 9.8 19 23.8 19.4 13.6
>50
Minutes
6.7
7.4
12.1
14.4
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-38
1997-2010 Methodology
Projections
-------
Table 6.5-7. State-Specific I/M Program Inputs - Projection Years
I/M Program Name
AKIM991
AKIM992
AZIM991
AZIM992
IIM Program Control Flag Record
Technical Training and Certification Program
Remote Sensing Device Inspections Program
IIM Program Parameters
Program Start Year 1986 1986
Model Years Covered 1968-2020 1975-2020
Program Type TRC TRC
Inspection Frequency Biennial Biennial
Vehicle Types Inspected
LDGV YES YES
LDGT1 YES YES
LDGT2 YES YES
HDGV NO NO
Test Type 2500/ldle Test 2500/ldle Test
I/M Cutpoints 220/1.2/999 220/1.2/999
Effectiveness Rates (% HC/CO/NOX) 0.85/0.85/0.85 0.85/0.85/0.85
IIM Program Parameters
Program Start Year
Model Years Covered
Program Type
Inspection Frequency
Vehicle Types Inspected
LDGV
LDGT1
LDGT2
HDGV
Test Type
I/M Cutpoints
Effectiveness Rates (% HC/CO/NOX)
0.85/0.85/0.85 0.85/0.85/0.85
Anti-Tampering Program Parameters
Program Start Year 1986 1986
Model Years Covered 1968-2020 1975-2020
Program Type TRC TRC
Effectiveness Rate 0.85 0.85
Vehicle Types Inspected
LDGV YES YES
LDGT1 YES YES
LDGT2 YES YES
HDGV NO NO
Inspection Frequency Biennial Biennial
Inspections Performed
Air Pump System YES YES
Catalyst YES YES
Fuel Inlet Restrictor NO NO
Tailpipe Lead Deposit Test NO NO
1978
1967-1980
TO
Annual
YES
YES
YES
YES
Idle Test
220/1.2/999
1.00/1.00/1.00
1978
1981-2020
TO
Biennial
YES
YES
YES
YES
Transient Test
1.20/20.0/3.00
1.00/1.00/1.00
1977
1975-2020
TO
1.00
YES
YES
YES
YES
Biennial
YES
YES
NO
NO
1978
1967-2020
TO
Biennial
YES
YES
YES
YES
Idle Test
220/1.2/999
1.00/1.00/1.00
1.00/1.00/1.00
1977
1975-2020
TO
1.00
YES
YES
YES
YES
Biennial
YES
YES
NO
NO
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-39
1997-2010 Methodology
Projections
-------
Table 6.5-8. Counties Included in State-Specific I/M Projection Year Programs
I/M Program
Name
Included Counties
AKIM991 Anchorage Ed
AKIM992 Fairbanks Ed
AZIM991 Maricopa Co
AZIM992 Pima Co
CAIM991 Alameda Co, Butte Co, Contra Costa Co, El Dorado Co, Merced Co, Orange Co, Placer Co, Riverside
Co, San Bernardino Co, Solano Co, Stanislaus Co, Sutler Co, Yolo Co, Marin Co, Monterey Co, San
Mateo Co, Sonoma Co, Fresno Co, Kern Co, Los Angeles Co, Napa Co, Sacramento Co, San Diego Co,
San Francisco Co
CAIM992 Colusa Co, Glenn Co, Kings Co, Madera Co, Nevada Co, San Benito Co, San Joaquin Co, Santa Clara
Co, Shasta Co, Tehama Co, Tulare Co, Ventura Co, Yuba Co, San Luis Obispo Co, Santa Barbara Co,
Santa Cruz Co
COIM991* Adams Co, Arapahoe Co, Boulder Co, Douglas Co, Jefferson Co, Denver Co
COIM992 Pitkin Co, El Paso Co, Larimer Co, Weld Co
CTIM99 Fairfield Co, Hartford Co, Litchfield Co, Middlesex Co, New Haven Co, New London Co, Tolland Co,
Windham Co
DCIM99* Washington
DEIM991 Kent Co, Sussex Co
DEIM992 New Castle Co
FLIM99 Broward Co, Dade Co, Duval Co, Hillsborough Co, Palm Beach Co, Pinellas Co
GAIM001 Cobb Co, De Kalb Co, Fulton Co, Gwinnett Co
GAIM002 Cherokee Co, Clayton Co, Coweta Co, Douglas Co, Fayette Co, Forsyth Co, Henry Co, Paulding Co,
Rockdale Co
GAIM021 Cobb Co, De Kalb Co, Fulton Co, Gwinnett Co
GAIM022 Cherokee Co, Clayton Co, Coweta Co, Douglas Co, Fayette Co, Forsyth Co, Henry Co, Paulding Co,
Rockdale Co
GAIM991 Cobb Co, De Kalb Co, Fulton Co, Gwinnett Co
GAIM992 Cherokee Co, Clayton Co, Coweta Co, Douglas Co, Fayette Co, Forsyth Co, Henry Co, Paulding Co,
Rockdale Co
IDIM99 Ada Co
ILIM991* Cook Co, Du Page Co, Lake Co, Madison Co, St. Clair Co
ILIM992* Kane Co, Kendall Co, McHenry Co, Will Co, Monroe Co
INIM99* Clark Co, Floyd Co, Lake Co, Porter Co
KYIM991 Boone Co, Campbell Co, Kenton Co
KYIM992 Jefferson Co
KYIM993 Boyd Co, Greenup Co
LAIM99 Ascension Par, East Baton Rouge Par, Iberville Par, Livingston Par, Pointe Coupee Par, West Baton
Rouge Par
MAIM99 Barnstable Co, Berkshire Co, Bristol Co, Dukes Co, Essex Co, Franklin Co, Hampden Co, Hampshire Co,
Middlesex Co, Nantucket Co, Norfolk Co, Plymouth Co, Suffolk Co, Worcester Co
MDIM001* Anne Arundel Co, Baltimore Co, Carroll Co, Harford Co, Howard Co, Baltimore, Montgomery Co, Prince
Georges Co
MDIM002* Calvert Co, Cecil Co, Queen Annes Co, Charles Co, Frederick Co, Washington Co
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-40
1997-2010 Methodology
Projections
-------
Table 6.5-8 (continued)
I/M Program
Name
Included Counties
MDIM021* Anne Arundel Co, Baltimore Co, Carroll Co, Harford Co, Howard Co, Baltimore, Montgomery Co, Prince
Georges Co
MDIM022* Calvert Co, Cecil Co, Queen Annes Co, Charles Co, Frederick Co, Washington Co
MDIM991* Anne Arundel Co, Baltimore Co, Carroll Co, Harford Co, Howard Co, Baltimore, Montgomery Co, Prince
Georges Co
MDIM992* Calvert Co, Cecil Co, Queen Annes Co, Charles Co, Frederick Co, Washington Co
MEIM99 Cumberland Co
MNIMOO Anoka Co, Carver Co, Dakota Co, Hennepin Co, Ramsey Co, Scott Co, Washington Co
MNIN02 Anoka Co, Carver Co, Dakota Co, Hennepin Co, Ramsey Co, Scott Co, Washington Co
MNIN99 Anoka Co, Carver Co, Dakota Co, Hennepin Co, Ramsey Co, Scott Co, Washington Co
MOIM02 Jefferson Co, St. Charles Co, St. Louis Co, St. Louis
MOIM99 Jefferson Co, St. Charles Co, St. Louis Co, St. Louis
NCIM991 Mecklenburg Co
NCIM992 Durham Co, Wake Co
NCIM993 Forsyth Co, Guilford Co, Gaston Co
NCIM994 Cabarrus Co, Union Co, Orange Co
NHIM99 Hillsborough Co, Rockingham Co
NJIM99 Atlantic Co, Cape May Co, Warren Co, Burlington Co, Camden Co, Cumberland Co, Gloucester Co,
Salem Co, Bergen Co, Essex Co, Hudson Co, Hunterdon Co, Middlesex Co, Monmouth Co, Morris Co,
Ocean Co, Passaic Co, Somerset Co, Sussex Co, Union Co, Mercer Co
NMIM99 BernalilloCo
NVIM99 Clark Co, Washoe Co
NYIM001 Bronx Co, Kings Co, Nassau Co, New York Co, Queens Co, Richmond Co, Rockland Co, Suffolk Co,
Westchester Co
NYIM002 Orange Co
NYIM021 Bronx Co, Kings Co, Nassau Co, New York Co, Queens Co, Richmond Co, Rockland Co, Suffolk Co,
Westchester Co
NYIM022 Orange Co
NYIM993 Albany Co, Allegany Co, Broome Co, Cattaraugus Co, Cayuga Co, Chautauqua Co, Chemung Co,
Chenango Co, Clinton Co, Columbia Co, Cortland Co, Delaware Co, Erie Co, Essex Co, Franklin Co,
Fulton Co, Genessee Co, Greene Co, Hamilton Co, Herkimer Co, Jefferson Co, Lewis Co, Livingston Co,
Madison Co, Monroe Co, Montgomery Co, Niagara Co, Oneida Co, Onondaga Co, Ontario Co, Orleans
Co, Oswego Co, Otsego Co, Rensselaer Co, St. Lawrence Co, Saratoga Co, Schenectady Co, Schoharie
Co, Schuyler Co, Seneca Co, Steuben Co, Sullivan Co, Tioga Co, Tompkins Co, Ulster Co, Warren Co,
Washington Co, Wayne Co, Wyoming Co, Yates Co, Duchess Co, Putnam Co
OHIM001* Clermont Co, Geauga Co, Medina Co, Portage Co, Summit Co, Warren Co, Butler Co, Hamilton Co,
Lake Co, Lorain Co, Cuyahoga Co
OHIM002* Clark Co, Greene Co, Montgomery Co
OHIM021* Clermont Co, Geauga Co, Medina Co, Portage Co, Summit Co, Warren Co, Butler Co, Hamilton Co,
Lake Co, Lorain Co, Cuyahoga Co
OHIM022* Clark Co, Greene Co, Montgomery Co
OHIM991* Clermont Co, Geauga Co, Medina Co, Portage Co, Summit Co, Warren Co, Butler Co, Hamilton Co,
Lake Co, Lorain Co, Cuyahoga Co
OHIM992* Clark Co, Greene Co, Montgomery Co
ORIM991* Jackson Co, Josephine Co
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-41
1997-2010 Methodology
Projections
-------
Table 6.5-8 (continued)
I/M Program
Name
Included Counties
ORIM992* Clackamas Co, Multnomah Co, Washington Co
PAIM991 Lehigh Co, Northampton Co
PAIM992 Berks Co, Clair Co, Cambria Co, Centre Co, Cumberland Co, Dauphin Co, Lackawanna Co, Lancaster
Co, Lebanon Co, Luzerne Co, Lycoming Co, York Co, Erie Co, Mercer Co
PAIM993 Bucks Co, Chester Co, Delaware Co, Montgomery Co, Philadelphia Co
PAIM994 Allegheny Co, Beaver Co, Washington Co, Westmoreland Co
RIIM99 Bristol Co, Kent Co, Newport Co, Providence Co, Washington Co
TNIM991 Davidson Co
TNIM992 Shelby Co
TNIM993 Rutherford Co, Sumner Co, Williamson Co, Wilson Co
TXIM001 Harris Co
TXIM002 Dallas Co, Tarrant Co
TXIM003 El Paso Co
TXIM021 Harris Co
TXIM022 Dallas Co, Tarrant Co
TXIM023 El Paso Co
TXIM991 Harris Co
TXIM992 Dallas Co, Tarrant Co
TXIM993 El Paso Co
UTIM991 Utah Co
UTIM992 Weber Co
UTIM993 Davis Co, Salt Lake Co
VAIM991 Arlington Co, Fairfax Co, Prince William Co, Alexandria, Manassas, Manassas Park, Fairfax, Falls
Church
VAIM992 Loudoun Co, Stafford Co
VTIM99 Addison Co, Bennington Co, Caledonia Co, Chittenden Co, Essex Co, Franklin Co, Grand Isle Co,
Lamoille Co, Orange Co, Orleans Co, Rutland Co, Washington Co, Windham Co, Windsor Co
WAIM001 King Co, Snohomish Co
WAIM002 Pierce Co, Clark Co
WAIM003 Spokane Co
WAIM021 King Co, Snohomish Co
WAIM022 Pierce Co, Clark Co
WAIM023 Spokane Co
WAIM991 King Co, Snohomish Co
WAIM992 Pierce Co, Clark Co
WAIM993 Spokane
WIIM991* Kenosha Co, Milwaukee Co, Ozaukee Co, Racine Co, Washington Co, Waukesha Co
WIIM992* Sheboygan Co
*lndicates that the maximum LEV benefits were applied.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-42
1997-2010 Methodology
Projections
-------
Table 6.5-9. I/M Performance Standard Program Inputs
I/M Program Name
I/M Program Parameters
Program Start Year
Stringency Level (Percent)
Model Years Covered
Waiver Rate for Pre-1981 Model Years (%)
Waiver Rate for 1981 and Later Models (%)
Compliance Rate (%)
Program Type
Inspection Frequency
Vehicle Types Inspected
LDGV
LDGT1
LDGT2
HDGV
Test Type
I/M Cutpoints
Effectiveness Rates (% HC/CO/NCg
IIM Program Parameters
Program Start Year
Stringency Level (Percent)
Model Years Covered
Waiver Rate for Pre-1981 Model Years (%)
Waiver Rate for 1981 and Later Models (%)
Compliance Rate (%)
Program Type
Inspection Frequency
Vehicle Types Inspected
LDGV
LDGT1
LDGT2
HDGV
Test Type
I/M Cutpoints (g/mi HC/CO/NOJ
Anti-Tampering Program Parameters
Program Start Year
Model Years Covered
Vehicle Types Inspected
LDGV
LDGT1
LDGT2
HDGV
Program Type
Effectiveness Rate
Inspection Frequency
Compliance Rate (%)
Inspections Performed
Air Pump System
Catalyst
Fuel Inlet Restrictor
Tailpipe Lead Deposit Test
EGR System
Evaporative Emission Control System
PCV System
Gas Cap
Basic I/M
Performance Standard
1983
20
1968-2020
0
0
100
TO
Annual
YES
NO
NO
NO
Idle Test
220/1 .2/999
1 .00/1 .00/1 .00
Low Enhanced I/M
Performance Standard
1983
20
1968-2020
3
3
96
TO
Annual
YES
YES
YES
NO
Idle Test
220/1 .2/999
1 .00/1 .00/1 .00
1995
1972-2020
YES
YES
YES
NO
TO
1.00
Annual
96
NO
NO
NO
NO
YES
NO
NO
NO
High Enhanced I/M
Performance Standard
1983
20
1968-1985
3
3
96
TO
Annual
YES
YES
YES
NO
2500/ldle Test
220/1 .2/999
1 .00/1 .00/1 .00
1983
20
1986-2020
3
3
96
TO
Annual
YES
YES
YES
NO
Transient Test
0.80/20.0/2.00
1 .00/1 .00/1 .00
1995
1984-2020
YES
YES
YES
NO
TO
1.00
Annual
96
NO
YES
YES
NO
NO
NO
NO
NO
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-43
1997-2010 Methodology
Projections
-------
Table 6.5-9 (continued)
I/M Program Name
Basic I/M
Performance Standard
Low Enhanced I/M
Performance Standard
High Enhanced I/M
Performance Standard
Functional Pressure Test Program
Parameters
Program Start Year
Model Years Covered
Effectiveness Rate
Vehicle Types Tested
LDGV
LDGT1
LDGT2
HDGV
Program Type
Inspection Frequency
Compliance Rate (%)
Purge Test Program Parameters
Program Start Year
Model Years Covered
Effectiveness Rate
Vehicle Types Tested
LDGV
LDGT1
LDGT2
HDGV
Program Type
Inspection Frequency
Compliance Rate (%)
Years of Program Usage
05,07,08, 10
05,07,08, 10
1995
1983-2020
1.00
YES
YES
YES
NO
TO
Annual
96
1995
1986-2020
1.00
YES
YES
YES
NO
TO
Annual
96
05,07,08, 10
Notes: TO = Test Only
TRC = Test and Repair (Computerized)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-44
1997-2010 Methodology
Projections
-------
Table 6.5-10. States Modeled with I/M Performance Standard Inputs
in 2005, 2007, 2008, and 2010
I/M Performance
Standard Modeled State
Basic Alaska
Arizona
Colorado
Florida
Idaho
Kentucky
Minnesota
New Mexico
North Carolina
County
Fairbanks Ed
Pima Co
Pitkin Co, El Paso Co, Larimer Co, Weld Co
Broward Co, Dade Co, Duval Co, Hillsborough Co, Palm Beach Co, Pinellas Co
Ada Co
Boyd Co, Greenup Co, Boone Co, Campbell Co,
Anoka Co, Carver Co, Dakota Co, Hennepin Co,
Bernalillo Co
Cabarrus Co, Union Co, Orange Co, Forsyth Co,
Kenton Co, Jefferson Co
Ramsey Co, Scott Co, Washington Co
Guilford Co, Durham Co, Gaston Co,
Tennessee
Mecklenburg Co, Wake Co
Rutherford Co, Sumner Co, Williamson Co, Wilson Co, Davidson Co, Shelby Co
Low Enhanced
Delaware
Louisiana
Nevada
Pennsylvania
Texas
Utah
Washington
Kent Co, New Castle Co, Sussex Co
Ascension Par, East Baton Rouge Par, Iberville Par, Livingston Par, Pointe Coupee Par, West
Baton Rouge Par
Clark Co, Washoe Co
Berks Co, Blair Co, Cambria Co, Centre Co, Cumberland Co, Dauphin Co, Lackawanna Co,
Lancaster Co, Lebanon Co, Luzerne Co, Lycoming Co, York Co, Allegheny Co, Beaver Co,
Washington Co, Westmoreland Co, Erie Co, Mercer Co, Lehigh Co, Northampton Co
El Paso Co
Davis Co, Salt Lake Co, Utah Co, Weber Co
Pierce Co, Clark Co, King Co, Snohomish Co, Spokane Co
High Enhanced
Alaska
Arizona
California
Colorado
Connecticut
DC
Anchorage Ed
Maricopa Co
Alameda Co, Butte Co, Colusa Co, Contra Costa Co, El Dorado Co, Glenn Co, Kings Co,
Madera Co, Merced Co, Nevada Co, Orange Co, Placer Co, Riverside Co, San Benito Co, San
Bernardino Co, San Joaquin Co, Santa Clara Co, Shasta Co, Solano Co, Stanislaus Co, Sutler
Co, Tehama Co, Tulare Co, Ventura Co, Yolo Co, Yuba Co, Marin Co, Monterey Co, San Luis
Obispo Co, San Mateo Co, Santa Barbara Co, Santa Cruz Co, Sonoma Co, Fresno Co, Kern
Co, Los Angeles Co, Napa Co, Sacramento Co, San Diego Co, San Francisco CO
Adams Co, Arapahoe Co, Boulder Co, Douglas Co, Jefferson Co, Denver CO
Fairfield Co, Hartford Co, Litchfield Co, Middlesex Co, New Haven Co, New London Co,
Tolland Co, Windham Co
Washington
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-45
1997-2010 Methodology
Projections
-------
Table 6.5-10 (continued)
I/M Performance
Standard Modeled
State
County
High Enhanced
(continued)
Georgia
Illinois
Indiana
Maryland
Massachusetts
Missouri
New Hampshire
New Jersey
New York
Ohio
Oregon
Pennsylvania
Rhode Island
Texas
Virginia
Wisconsin
Cherokee Co, Clayton Co, Coweta Co, Douglas Co, Fayette Co, Forsyth Co, Henry Co,
Paulding Co, Rockdale Co, Cobb Co, De Kalb Co, Fulton Co, Gwinnett Co
Cook Co, Du Page Co, Lake Co, Kane Co, Kendall Co, McHenry Co, Will Co, Madison Co, St.
Clair Co, Monroe Co
Clark Co, Floyd Co, Lake Co, Porter Co
Anne Arundel Co, Baltimore Co, Carroll Co, Harford Co, Howard CO, Baltimore, Calvert Co,
Cecil Co, Queen Annes Co, Charles Co, Frederick Co, Montgomery Co, Prince Georges CO,
Washington Co
Barnstable Co, Berkshire Co, Bristol Co, Dukes Co, Essex Co, Franklin Co, Hampden Co,
Hampshire Co, Middlesex Co, Nantucket Co, Norfolk Co, Plymouth Co, Suffolk Co, Worcester
Co
Jefferson Co, St. Charles Co, St. Louis Co, St. Louis
Hillsborough Co, Rockingham Co, Strafford Co
Atlantic Co, Cape May Co, Warren Co, Burlington Co, Camden Co, Cumberland Co,
Gloucester Co, Salem Co, Bergen Co, Essex Co, Hudson Co, Hunterdon Co, Middlesex Co,
Monmouth Co, Morris Co, Ocean Co, Passaic Co, Somerset Co, Sussex Co, Union Co,
Mercer Co
Bronx Co, Kings Co, Nassau Co, New York Co, Queens Co, Richmond Co, Rockland Co,
Suffolk Co, Westchester Co, Orange Co
Clark Co, Clermont Co, Geauga Co, Greene Co, Medina Co, Montgomery Co, Portage Co,
Summit Co, Warren Co, Butler Co, Hamilton Co, Lake Co, Lorain Co, Cuyahoga Co
Clackamas Co, Jackson Co, Multnomah Co, Washington Co, Josephine Co
Bucks Co, Chester Co, Delaware Co, Montgomery Co, Philadelphia Co
Bristol Co, Kent Co, Newport Co, Providence Co, Washington Co
Dallas Co, Tarrant Co, Harris Co
Arlington Co, Fairfax Co, Loudoun Co, Prince William Co, Stafford Co, Alexandria, Manassas,
Manassas Park, Fairfax, Falls Church
Kenosha Co, Milwaukee Co, Ozaukee Co, Racine Co, Washington Co, Waukesha Co,
Sheboygan
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-46
1997-2010 Methodology
Projections
-------
Table 6.5-11. Counties Modeled with Federal Reformulated Gasoline
State (ASTM Class*)/
Nonattainment Area County
State (ASTM Class*)/
Nonattainment Area County
Arizona (B)
Phoenix**
Maricopa Co
Connecticut (C)
Greater Connecticut
Hartford Co
Litchfield Co
Middlesex Co
New Haven Co
New London Co
Tolland Co
Windham Co
New York-Northern New Jersey-Long Island
Fairfield Co
District of Columbia (B)
Washington DC
Washington
Delaware (C)
Philadelphia-Wilmington-Trenton
Kent Co
New Castle Co
Sussex County
Sussex Co
Illinois (C)
Chicago-Gary-Lake County
Cook Co
Du Page Co
Grundy Co
Kane Co
Kendall Co
Lake Co
McHenry Co
Will Co
Indiana (C)
Chicago-Gary-Lake County
Lake Co
Porter Co
Kentucky (C)
Cincinnati-Hamilton
Boone Co
Campbell Co
Kenton Co
Maine (C)
Knox & Lincoln Counties
Knox Co
Lincoln Co
Lewiston-Auburn
Androscoggin Co
Kennebec Co
Portland
Cumberland Co
Sagadahoc Co
York Co
Maryland (B)
Baltimore
Anne Arundel Co
Baltimore
Baltimore Co
Carroll Co
Harford Co
Howard Co
Kent & Queen Annes Counties
Kent Co
Queen Annes Co
Philadelphia-Wilmington-Trenton
Cecil Co
Washington DC
Calvert Co
Charles Co
Frederick Co
Montgomery Co
Prince Georges Co
Massachusetts (C)
Boston-Lawrence-Worcester-Eastern MA
Barnstable Co
Bristol Co
Dukes Co
Essex Co
Middlesex Co
Nantucket Co
Norfolk Co
Plymouth Co
Suffolk Co
Worcester Co
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-47
1997-2010 Methodology
Projections
-------
Table 6.5-11 (continued)
State (ASTM Class*)/
Nonattainment Area County
State (ASTM Class*)/
Nonattainment Area County
Louisville
Bullitt Co
Jefferson Co
Oldham Co
New Hampshire (C)
Manchester
Hillsborough Co
Merrimack Co
Portsmouth-Dover-Rochester
Rockingham Co
Strafford Co
New Jersey (C)
Allentown-Bethlehem-Easton
Warren Co
Atlantic City
Atlantic Co
Cape May Co
New York-Northern New Jersey-Long Island
Bergen Co
Essex Co
Hudson Co
Hunterdon Co
Middlesex Co
Monmouth Co
Morris Co
Ocean Co
Passaic Co
Somerset Co
Sussex Co
Union Co
Philadelphia-Wilmington-Trenton
Burlington Co
Camden Co
Cumberland Co
Gloucester Co
Mercer Co
Salem Co
New York (C)
New York-Northern New Jersey-Long Island
Bronx Co
Kings Co
Nassau Co
New York Co
Springfield/Pittsfield-Western MA
Berkshire Co
Franklin Co
Hampden Co
Hampshire Co
New York (C)
Poughkeepsie
Dutchess Co
Putnam Co
Pennsylvania (C)
Philadelphia-Wilmington-Trenton
Bucks Co
Chester Co
Delaware Co
Montgomery Co
Philadelphia Co
Rhode Island (C)
Providence
Bristol Co
Kent Co
Newport Co
Providence Co
Washington Co
Texas(B)
Dallas-Fort Worth
Collin Co
Dallas Co
Denton Co
Tarrant Co
Houston-Galveston-Brazoria
Brazoria Co
Chambers Co
Fort Bend Co
Galveston Co
Harris Co
Liberty Co
Montgomery Co
Waller Co
Virginia (B)
Norfolk-Virginia Beach-Newport News
Chesapeake
Hampton
James City Co
Newport News
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-48
1997-2010 Methodology
Projections
-------
Table 6.5-11 (continued)
State (ASTM Class*)/
Nonattainment Area
County
Orange Co
Queens Co
Richmond Co
Rockland Co
Suffolk Co
Westchester Co
State (ASTM Class*)/
Nonattainment Area County
Norfolk
Poquoson
Portsmouth
Suffolk
Virginia Beach
Williamsburg
York Co
Virginia (B)
Richmond-Petersburg
Wisconsin (C)
Milwaukee-Racine
Washington DC
Charles City Co
Chesterfield Co
Colonial Heights
Hanover Co
Henrico Co
Hopewell
Richmond
Alexandria
Arlington Co
Fairfax
Fairfax Co
Falls Church
Loudoun Co
Manassas
Manassas Park
Prince William Co
Stafford Co
Kenosha Co
Milwaukee Co
Ozaukee Co
Racine Co
Washington Co
Waukesha Co
Notes: * ASTM Class B areas are subject to the Southern reformulated gasoline region requirements while ASTM Class C areas are subject to the
Northern reformulated gasoline region requirements.
** Reformulated gasoline was only modeled in Phoenix beginning with the projection years, as the opt-in date for Phoenix was 1997.
California reformulated gasoline was modeled statewide in California.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-49
1997-2010 Methodology
Projections
-------
Table 6.5-12. California Basic Emission Rate Limits
Y.ehicle Pollutant
Type
HDGV NOX
NOX
NOX
NOX
NOX
VOC
VOC
VOC
VOC
LDGT2 VOC
VOC
VOC
VOC
VOC
VOC
VOC
CO
CO
CO
CO
CO
CO
CO
NOX
NOX
NOX
NOX
NOX
LDGT2 VOC
VOC
VOC
VOC
VOC
VOC
VOC
CO
CO
CO
CO
CO
CO
CO
NOX
NOX
NOX
NOX
NOX
LEV
Credits
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Minimum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Maximum
Model Years
Covered
1998-2003
2004 +
1991 -1997
1998-2003
2004 +
1994-2003
2004 +
1994-2003
2004 +
1995-1997
1998
1999
2000
2001
2002
2003 +
1995-1997
1998
1999
2000
2001
2002
2003 +
1995-1997
1998
1999
2000
2001 +
1995-1997
1998
1999
2000
2001
2002
2003 +
1995-1997
1998
1999
2000
2001
2002
2003 +
1995-1997
1998
1999
2000
2001 +
Zero Mile Level •
(HDVs: g/bhp-hr)
(LDVs: g/mi)
3.1900
1 .6600
4.6000
3.6800
1 .8400
0.3640
0.2770
0.2830
0.2570
0.2413
0.2345
0.2297
0.1780
0.1547
0.1522
0.1403
2.9111
2.9823
3.0957
3.2091
2.8523
2.5961
2.3399
0.3744
0.3594
0.3454
0.3315
0.2125
0.2413
0.2345
0.2297
0.1780
0.1547
0.1522
0.1403
2.9111
2.9823
3.0957
3.2091
2.8523
2.5961
2.3399
0.3744
0.3594
0.3454
0.3315
0.2125
Deterioration Rate
<50,000 mi
(HDVs: G/bhp-hr/10 kmi)
(LDVs: g/mi/10 kmi)
0.0450
0.0210
0.0000
0.0000
0.0000
0.0230
0.0180
0.0000
0.0000
0.0720
0.0720
0.0720
0.0720
0.0720
0.0720
0.0720
1 .4480
1 .4480
1 .4480
1 .4480
1 .4480
1 .4480
1 .4480
0.0830
0.0830
0.0830
0.0830
0.0830
0.0272
0.0263
0.0257
0.0190
0.0159
0.0156
0.0140
0.3398
0.3585
0.3718
0.3850
0.4373
0.4596
0.4819
0.0931
0.0894
0.0859
0.0825
0.0528
>50,000 mi
(HDVs: g/bhp-hr/10 kmi)
(LDVs: g/mi/10 kmi)
0.0450
0.0210
0.0000
0.0000
0.0000
0.0230
0.0180
0.0000
0.0000
0.2730
0.2730
0.2730
0.2730
0.2730
0.2730
0.2730
3.4340
3.4340
3.4340
3.4340
3.4340
3.4340
3.4340
0.1860
0.1860
0.1860
0.1860
0.1860
0.0272
0.0263
0.0257
0.0190
0.0159
0.0156
0.0140
0.3398
0.3585
0.3718
0.3850
0.4373
0.4596
0.4819
0.0931
0.0894
0.0859
0.0825
0.0528
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-50
1997-2010 Methodology
Projections
-------
6.6 NON-ROAD MOBILE SOURCES
Non-road emissions were projected to 1999, 2000, 2002, 2005, 2007, 2008, and 2010. The Trends
1995 emission estimates were used as the base year for the emission projections.
6.6.1 Growth Factors
1995 emissions were projected to each projection year using BEA GSP projections by state and
industry1 as a surrogate for growth. These growth factors were applied in much the same manner as the
growth factors were applied to the 1990 data to estimate 1995 and 1996 emissions. There were several
minor differences in the procedures used to project future year emissions. First, since the BEA GSP
projection data were already in constant dollars, no adjustments to account for inflation were needed.
Second, the BEA GSP projection data did not contain data points for all years of interest. The BEA data
project GSP for the following years: 1998, 2000, 2005, 2010, 2015, 2025, and 2040. Data points for
1999, 2002, 2007, and 2008 were developed by assuming linear growth between the two closest
surrounding years.
The crosswalk between SCC and growth factors is the same as the one used for the 1995 and 1996
estimates, and is shown in table 6.6-1. Zero growth was assumed for all railroad SCCs. This assumption
is based on information that shows railroad use and earning increasing, but fuel use remaining constant
due to efficiency gains in locomotive design.2 For the 1995 and 1996 estimates, Federal Aviation
Administration (FAA) landing-takeoff (LTO) data were used as the growth surrogates for commercial
aircraft. The FAA LTO data included all years of interest except 2010. 2010 LTO estimates were
developed assuming straight line growth in air carrier LTOs from 1996 through 2010. Table 6.6-2 lists
the 1999 through 2010 growth factors by state and SIC.
6.6.2 Control Factors
The impact of the following four non-road control programs are included in the emission
projections: 1) Phase I of the compression ignition standards for diesel engines, 2) Phase I of the spark
ignition standards for gasoline engines, 3) recreational marine vessel controls, and 4) reformulated
gasoline. The impact of the compression ignition standards and the recreational marine controls were
incorporated in the adjustments to emissions from non-road diesel engines and recreational marine
engines based on the OMS national emission estimates. The procedure for adjusting emissions based on
the OMS national emission estimates is described below.
Emission reductions resulting from Phase I of the spark ignition standard were modeled using overall
percentage reductions estimated by OMS.3
6.6.3 Use of OMS National Emissions Estimates
OMS supplied national emission estimates from its rulemaking analyses that were used to develop
emissions for each projection year. The OMS emission estimates (for 1992) were developed by taking
per capita emissions values from one of 27 areas and then applying these estimates to the remainder of
the country (applied at the county level). This method provides total non-road emissions for each county.
The emissions from OMS were provided in 27 7-digit SCCs. The percent of the total emissions
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-51 Projections
-------
represented by each of these 27 SCCs was calculated for each of the 27 areas for which OMS provided
detailed emission inventories. These percentages were then applied to the total emissions for each county
based on the per capita emissions scaling described above in order to apportion the total emissions to the
27 SCCs. New national totals for each year (including the projection years) were obtained by using the
growth factors described above.
OMS also used the EPCD non-road model to calculate new national non-road diesel values for all
years. These diesel emissions did not reflect the proposed Phase II standards. For the non-road diesel
estimates, a factor reflecting the "final/initial" ratio for all years was developed for the eight diesel 7-digit
SCCs. These eight ratios were then applied to the initial county estimates to develop final county
emission estimates. The only difference in the way these data were applied was for the emissions from
railroads. Railroad emissions for all pollutants were held constant after 1996 for all projection years.
Some of the emissions data used as the basis for the projections was obtained directly from States.
As part of the OTAG effort, 24 States provided actual data for these sources (17 States provided
complete State data, 7 provided partial State data). The data provided as part of the OTAG effort were
generally daily emissions data. The daily data were converted to annual data.
Finally, the national diesel non-road agriculture emissions were allocated to the county using
information on the acreage of crops harvested, rather than population.
6.6.4 References
1. Regional Projections to 2045, data files, U.S. Department of Commerce, Bureau of Economic
Analysis, Washington, DC, August 1995.
2. Notice of Proposed Rulemaking (40 CFR, 62, No. 28, 6366-6405), February 11, 1995.
3. Fleet Average Annual Emission Reduction Percentages Small Gasoline Engines Phase I, E-mail
sent to Sharon Nizich, U.S. Environmental Protection Agency, Office of Air Quality Planning and
Standards, from U.S. Environmental Protection Agency, Office of Mobile Sources, July 23, 1997.
National Air Pollutant Emission Trends 1997-2010 Methodology
Procedures Document for 1900-1996 6-52 Projections
-------
Table 6.6-1. SCC-SIC Crosswalk
SCCs
2260001 , 2265001 , 2270001
2260002, 2265002, 2270002
2260003, 2265003, 2270003
2260004, 2265004, 2270004
2260005, 2265005, 2270005
2260006, 2265006, 2270006
2260007, 2265007, 2270007
2260008, 2265008, 2270008
2275 (except 2275001 and 2275002)
2275001
2275002
2280
2282
2283
2285**
Non-road Segment
Recreational Vehicles
Construction
Industrial
Lawn and Garden
Farm
Light Commercial
Logging
Airport Service
Aircraft (except Military and
Commercial)
Military Aircraft
Commercial Aircraft
Commercial Marine Vessels
Recreational Marine Vessels
Military Marine Vessels
Railroads
SIC
999*
15
998*
999*
01
998*
07
45
45
992*
LTD*
44
999*
992*
40
SIC Name
Population
Construction
Total Manufacturing
Population
Farm
Total Manufacturing
Agricultural Services, Forestry, Fisheries,
and Other
Transportation by Air
Transportation by Air
Federal, military
Landing-Takeoff Operations
Water Transportation
Population
Federal, military
Railroad Transportation
NOTES: *Growth factor does not correspond to an SIC.
**E-GAS growth factors
used for 1995 and 1996 NOX emissions.
Zero growth assumed after 1996 for all pollutants.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-53
1997-2010 Methodology
Projections
-------
Table 6.6-2. 1999 - 2010 Growth Factors
State
Code
01
01
01
01
01
01
01
01
01
01
02
02
02
02
02
02
02
02
02
02
04
04
04
04
04
04
04
04
04
04
05
05
05
05
05
05
05
05
05
05
06
06
06
06
06
06
06
06
06
06
08
08
08
08
08
08
08
SIC
01
07
15
40
44
44
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
SIC Name
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Water Transportation
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
1999
1.092
1.214
1.044
1.136
1.007
1.237
0.949
1.114
1.030
1.095
1.131
1.172
1.087
1.000
1.058
1.156
0.946
1.045
1.057
1.095
1.154
1.229
1.140
1.213
1.140
1.196
0.988
1.145
1.084
1.095
1.029
1.210
1.064
1.168
1.162
1.262
0.877
1.125
1.035
1.095
1.076
1.176
1.046
1.162
0.984
1.164
0.905
1.084
1.055
1.095
1.123
1.242
1.116
1.242
1.114
1.226
0.962
2000
1.123
1.259
1.046
1.170
1.008
1.296
0.939
1.136
1.036
1.124
1.166
1.212
1.083
1.000
1.072
1.195
0.942
1.070
1.071
1.124
1.202
1.280
1.154
1.266
1.158
1.245
0.993
1.172
1.104
1.124
1.045
1.259
1.070
1.210
1.198
1.327
0.870
1.145
1.042
1.124
1.105
1.219
1.066
1.203
0.980
1.205
0.894
1.113
1.072
1.124
1.157
1.292
1.121
1.303
1.143
1.283
0.955
Growth Factors
2002 2005 2007
1.166
1.365
1.064
1.243
1.011
1.396
0.947
1.183
1.048
1.182
1.217
1.294
1.110
1.000
1.078
1.261
0.948
1.106
1.095
1.182
1.251
1.393
1.199
1.360
1.175
1.328
0.999
1.229
1.139
1.182
1.080
1.366
1.090
1.286
1.216
1.413
0.870
1.194
1.056
1.182
1.145
1.313
1.109
1.272
0.978
1.289
0.900
1.154
1.099
1.182
1.203
1.408
1.149
1.410
1.200
1.386
0.963
1.231
1.523
1.092
1.353
1.014
1.547
0.960
1.254
1.067
1.263
1.297
1.417
1.151
1.000
1.086
1.360
0.957
1.160
1.131
1.263
1.324
1.564
1.267
1.500
1.211
1.454
1.008
1.314
1.190
1.263
1.132
1.526
1.119
1.399
1.243
1.540
0.871
1.267
1.078
1.263
1.204
1.453
1.173
1.376
0.975
1.415
0.908
1.215
1.140
1.263
1.274
1.581
1.189
1.570
1.257
1.541
0.974
1.268
1.627
1.111
1.419
1.020
1.649
0.971
1.300
1.082
1.328
1.343
1.495
1.177
1.000
1.093
1.424
0.966
1.196
1.153
1.328
1.365
1.677
1.309
1.589
1.228
1.536
1.017
1.366
1.223
1.328
1.162
1.632
1.138
1.467
1.261
1.624
0.876
1.315
1.093
1.328
1.237
1.544
1.212
1.438
0.976
1.497
0.916
1.254
1.166
1.328
1.316
1.696
1.217
1.672
1.286
1.645
0.985
2008
1.286
1.679
1.121
1.452
1.022
1.701
0.976
1.323
1.089
1.358
1.366
1.533
1.190
1.000
1.096
1.457
0.971
1.213
1.163
1.358
1.386
1.734
1.331
1.633
1.246
1.577
1.021
1.392
1.240
1.358
1.177
1.685
1.148
1.502
1.270
1.667
0.877
1.339
1.101
1.358
1.253
1.590
1.231
1.469
0.977
1.538
0.920
1.274
1.178
1.358
1.337
1.754
1.230
1.722
1.314
1.697
0.990
2010
1.324
1.783
1.140
1.518
1.028
1.803
0.988
1.369
1.103
1.387
1.411
1.611
1.216
1.000
1.103
1.521
0.980
1.248
1.185
1.387
1.427
1.848
1.373
1.722
1.263
1.659
1.030
1.445
1.272
1.387
1.206
1.791
1.167
1.570
1.288
1.751
0.882
1.386
1.116
1.387
1.286
1.680
1.271
1.532
0.978
1.620
0.929
1.313
1.204
1.387
1.379
1.870
1.257
1.824
1.343
1.801
1.000
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-54
1997-2010 Methodology
Projections
-------
Table 6.6-2 (continued)
State
Code
08
08
08
09
09
09
09
09
09
09
09
09
09
10
10
10
10
10
10
10
10
10
10
11
11
11
11
11
11
11
11
11
11
12
12
12
12
12
12
12
12
12
12
13
13
13
13
13
13
13
13
13
13
15
15
15
15
SIC
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
SIC Name
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
1999
1.120
1.073
1.095
1.114
1.211
1.039
1.000
1.005
1.165
0.924
1.053
1.023
1.095
0.978
1.208
1.049
1.263
0.982
1.145
1.002
1.036
1.047
1.095
1.000
1.282
0.937
1.311
1.283
1.135
0.959
1.007
0.976
1.095
1.149
1.203
1.105
1.189
1.068
1.225
0.911
1.117
1.075
1.095
1.043
1.227
1.090
1.130
1.032
1.152
0.989
1.118
1.059
1.095
1.157
1.197
1.049
1.000
2000
1.145
1.089
1.124
1.147
1.257
1.050
1.000
1.005
1.206
0.917
1.065
1.032
1.124
0.995
1.250
1.076
1.328
0.977
1.182
1.011
1.045
1.059
1.124
1.000
1.350
0.926
1.388
1.348
1.167
0.951
1.010
0.974
1.124
1.188
1.252
1.127
1.236
1.085
1.282
0.902
1.143
1.095
1.124
1.062
1.273
1.093
1.162
1.040
1.190
0.990
1.140
1.072
1.124
1.212
1.251
1.070
1.000
Growth Factors
2002 2005 2007
1.193
1.119
1.182
1.194
1.356
1.071
1.000
1.012
1.288
0.924
1.087
1.047
1.182
1.014
1.351
1.097
1.439
0.982
1.271
1.018
1.073
1.080
1.182
1.000
1.476
0.926
1.502
1.337
1.228
0.951
1.019
0.970
1.182
1.241
1.356
1.163
1.332
1.117
1.359
0.908
1.191
1.131
1.182
1.095
1.382
1.123
1.232
1.047
1.255
0.998
1.187
1.097
1.182
1.291
1.355
1.089
1.000
1.265
1.164
1.263
1.263
1.504
1.102
1.000
1.022
1.412
0.935
1.120
1.071
1.263
1.044
1.502
1.127
1.605
0.991
1.402
1.029
1.114
1.110
1.263
1.000
1.670
0.925
1.675
1.315
1.321
0.952
1.033
0.965
1.263
1.320
1.512
1.218
1.475
1.166
1.474
0.918
1.263
1.184
1.263
1.144
1.546
1.168
1.337
1.058
1.353
1.011
1.257
1.133
1.263
1.410
1.510
1.118
1.000
1.312
1.193
1.328
1.303
1.600
1.123
1.000
1.031
1.494
0.945
1.140
1.087
1.328
1.059
1.599
1.148
1.711
1.000
1.492
1.040
1.142
1.131
1.328
1.000
1.796
0.926
1.781
1.315
1.381
0.956
1.042
0.966
1.328
1.364
1.615
1.252
1.563
1.196
1.547
0.927
1.307
1.218
1.328
1.171
1.653
1.198
1.401
1.068
1.416
1.022
1.302
1.158
1.328
1.481
1.612
1.137
1.000
2008
1.335
1.207
1.358
1.323
1.649
1.134
1.000
1.037
1.535
0.950
1.151
1.096
1.358
1.066
1.649
1.158
1.765
1.000
1.534
1.045
1.155
1.141
1.358
1.000
1.854
0.927
1.834
1.304
1.409
0.957
1.047
0.966
1.358
1.386
1.667
1.269
1.607
1.211
1.584
0.931
1.330
1.235
1.358
1.185
1.707
1.213
1.432
1.072
1.448
1.028
1.325
1.170
1.358
1.517
1.663
1.147
1.000
2010
1.381
1.236
1.387
1.362
1.745
1.155
1.000
1.046
1.617
0.960
1.171
1.112
1.387
1.082
1.747
1.178
1.871
1.009
1.623
1.055
1.183
1.162
1.387
1.000
1.981
0.928
1.940
1.304
1.470
0.961
1.056
0.967
1.387
1.429
1.769
1.304
1.695
1.241
1.657
0.941
1.374
1.270
1.387
1.212
1.814
1.244
1.496
1.082
1.512
1.039
1.370
1.194
1.387
1.588
1.765
1.166
1.000
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-55
1997-2010 Methodology
Projections
-------
Table 6.6-2 (continued)
State
Code
15
15
15
15
15
15
16
16
16
16
16
16
16
16
16
16
17
17
17
17
17
17
17
17
17
17
18
18
18
18
18
18
18
18
18
18
19
19
19
19
19
19
19
19
19
19
20
20
20
20
20
20
20
20
20
20
21
SIC
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
SIC Name
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
1999
1.041
1.130
0.965
1.007
1.053
1.095
1.116
1.226
1.087
1.142
1.056
1.248
0.965
1.182
1.067
1.095
0.970
1.195
1.038
1.158
1.118
1.199
0.912
1.102
1.027
1.095
1.038
1.218
1.055
1.166
1.064
1.292
0.944
1.121
1.027
1.095
0.955
1.191
1.057
1.166
1.132
1.207
0.967
1.115
1.015
1.095
1.013
1.225
1.048
1.145
1.150
1.198
0.976
1.107
1.032
1.095
1.066
2000
1.051
1.163
0.965
1.012
1.068
1.124
1.147
1.278
1.090
1.178
1.056
1.310
0.953
1.216
1.080
1.124
0.994
1.239
1.045
1.198
1.148
1.249
0.901
1.119
1.035
1.124
1.068
1.266
1.059
1.207
1.080
1.364
0.930
1.140
1.033
1.124
1.006
1.234
1.060
1.208
1.160
1.258
0.952
1.132
1.019
1.124
1.032
1.276
1.048
1.182
1.150
1.248
0.973
1.128
1.041
1.124
1.100
Growth Factors
2002 2005 2007
1.066
1.232
0.971
1.027
1.093
1.182
1.195
1.392
1.105
1.249
1.093
1.415
0.960
1.288
1.102
1.182
1.021
1.345
1.062
1.258
1.156
1.327
0.905
1.151
1.049
1.182
1.118
1.380
1.077
1.283
1.106
1.474
0.939
1.179
1.045
1.182
1.050
1.331
1.077
1.278
1.188
1.338
0.961
1.171
1.027
1.182
1.067
1.391
1.066
1.256
1.150
1.337
0.979
1.171
1.055
1.182
1.153
1.088
1.336
0.980
1.051
1.129
1.263
1.268
1.564
1.128
1.355
1.148
1.572
0.972
1.394
1.134
1.263
1.062
1.504
1.088
1.347
1.168
1.444
0.911
1.201
1.070
1.263
1.193
1.549
1.105
1.397
1.145
1.638
0.952
1.238
1.063
1.263
1.116
1.477
1.103
1.384
1.236
1.459
0.974
1.230
1.039
1.263
1.119
1.563
1.092
1.366
1.200
1.473
0.988
1.236
1.075
1.263
1.233
1.104
1.403
0.990
1.068
1.154
1.328
1.310
1.678
1.144
1.419
1.185
1.678
0.982
1.463
1.155
1.328
1.085
1.609
1.105
1.400
1.179
1.521
0.918
1.231
1.084
1.328
1.236
1.662
1.124
1.467
1.172
1.748
0.964
1.275
1.076
1.328
1.153
1.572
1.119
1.447
1.264
1.536
0.986
1.267
1.048
1.328
1.148
1.677
1.109
1.433
1.200
1.561
0.997
1.277
1.089
1.328
1.280
2008
1.112
1.437
0.994
1.077
1.166
1.358
1.331
1.735
1.152
1.452
1.204
1.732
0.987
1.497
1.165
1.358
1.096
1.662
1.113
1.427
1.183
1.559
0.922
1.247
1.091
1.358
1.257
1.718
1.133
1.502
1.185
1.803
0.970
1.294
1.083
1.358
1.172
1.620
1.127
1.479
1.271
1.574
0.992
1.285
1.053
1.358
1.163
1.734
1.118
1.467
1.250
1.606
1.002
1.297
1.096
1.358
1.304
2010
1.128
1.505
1.004
1.094
1.190
1.387
1.373
1.850
1.169
1.516
1.241
1.838
0.998
1.566
1.186
1.387
1.119
1.767
1.130
1.479
1.194
1.636
0.929
1.278
1.105
1.387
1.301
1.830
1.152
1.571
1.212
1.913
0.981
1.331
1.096
1.387
1.210
1.715
1.144
1.543
1.299
1.651
1.003
1.322
1.062
1.387
1.192
1.848
1.135
1.534
1.250
1.694
1.011
1.338
1.110
1.387
1.351
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-56
1997-2010 Methodology
Projections
-------
Table 6.6-2 (continued)
State
Code
21
21
21
21
21
21
21
21
21
22
22
22
22
22
22
22
22
22
22
23
23
23
23
23
23
23
23
23
23
24
24
24
24
24
24
24
24
24
24
25
25
25
25
25
25
25
25
25
25
26
26
26
26
26
26
26
26
SIC
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
SIC Name
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
1999
1.201
1.062
1.077
0.964
1.222
0.970
1.114
1.028
1.095
1.042
1.192
1.035
1.176
0.992
1.122
0.916
1.075
1.024
1.095
1.102
1.143
1.042
1.076
1.043
1.388
0.863
1.080
1.026
1.095
1.010
1.197
1.024
0.998
0.949
1.193
0.954
1.044
1.043
1.095
1.110
1.141
1.088
1.232
1.023
1.172
0.881
1.059
1.025
1.095
1.055
1.206
1.048
1.119
1.078
1.152
0.869
1.082
2000
1.248
1.068
1.097
0.955
1.277
0.967
1.132
1.034
1.124
1.071
1.235
1.041
1.220
0.990
1.153
0.913
1.090
1.030
1.124
1.142
1.175
1.053
1.093
1.051
1.484
0.848
1.098
1.035
1.124
1.035
1.240
1.028
0.998
0.936
1.241
0.946
1.052
1.054
1.124
1.142
1.177
1.097
1.290
1.028
1.215
0.857
1.072
1.031
1.124
1.082
1.249
1.048
1.149
1.097
1.190
0.847
1.090
Growth Factors
2002 2005 2007
1.356
1.086
1.148
0.961
1.370
0.974
1.170
1.047
1.182
1.112
1.332
1.062
1.294
0.989
1.210
0.922
1.125
1.042
1.182
1.198
1.250
1.073
1.147
1.060
1.595
0.854
1.131
1.050
1.182
1.074
1.341
1.042
1.027
0.928
1.346
0.950
1.073
1.074
1.182
1.189
1.253
1.118
1.384
1.035
1.294
0.864
1.091
1.046
1.182
1.125
1.355
1.064
1.200
1.113
1.254
0.851
1.115
1.518
1.112
1.224
0.970
1.509
0.985
1.226
1.065
1.263
1.173
1.478
1.093
1.406
0.988
1.296
0.935
1.178
1.061
1.263
1.282
1.363
1.104
1.228
1.077
1.760
0.863
1.180
1.074
1.263
1.132
1.493
1.062
1.070
0.916
1.503
0.956
1.103
1.104
1.263
1.260
1.367
1.149
1.526
1.044
1.413
0.876
1.119
1.068
1.263
1.188
1.516
1.088
1.277
1.135
1.350
0.859
1.152
1.626
1.130
1.267
0.979
1.603
0.995
1.263
1.079
1.328
1.208
1.572
1.113
1.474
0.990
1.351
0.947
1.212
1.073
1.328
1.332
1.433
1.124
1.277
1.085
1.871
0.872
1.212
1.091
1.328
1.164
1.591
1.076
1.091
0.913
1.608
0.963
1.123
1.124
1.328
1.301
1.439
1.169
1.613
1.052
1.491
0.886
1.137
1.083
1.328
1.224
1.621
1.104
1.323
1.151
1.413
0.866
1.177
2008
1.679
1.139
1.289
0.983
1.650
0.999
1.281
1.086
1.358
1.226
1.620
1.124
1.508
0.991
1.378
0.952
1.229
1.080
1.358
1.356
1.469
1.134
1.300
1.094
1.928
0.876
1.228
1.100
1.358
1.180
1.639
1.083
1.101
0.910
1.662
0.967
1.133
1.133
1.358
1.321
1.475
1.179
1.656
1.057
1.530
0.891
1.146
1.091
1.358
1.242
1.674
1.112
1.346
1.160
1.444
0.870
1.190
2010
1.786
1.157
1.332
0.992
1.744
1.009
1.318
1.100
1.387
1.261
1.714
1.144
1.576
0.993
1.433
0.964
1.263
1.092
1.387
1.406
1.539
1.154
1.349
1.102
2.039
0.885
1.260
1.116
1.387
1.212
1.737
1.097
1.122
0.906
1.768
0.974
1.153
1.153
1.387
1.362
1.547
1.200
1.744
1.065
1.609
0.901
1.164
1.107
1.387
1.278
1.779
1.128
1.392
1.176
1.507
0.878
1.215
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-57
1997-2010 Methodology
Projections
-------
Table 6.6-2 (continued)
State
Code
26
26
27
27
27
27
27
27
27
27
27
27
28
28
28
28
28
28
28
28
28
28
29
29
29
29
29
29
29
29
29
29
30
30
30
30
30
30
30
30
30
30
31
31
31
31
31
31
31
31
31
31
32
32
32
32
32
SIC
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
SIC Name
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
1999
1.017
1.095
0.976
1.191
1.051
1.154
0.947
1.110
0.950
1.125
1.037
1.095
0.980
1.200
1.115
1.157
1.000
1.259
1.027
1.119
1.026
1.095
1.021
1.201
1.056
1.161
0.835
1.032
0.929
1.083
1.032
1.095
1.155
1.225
1.095
1.199
1.000
1.207
1.001
1.060
1.056
1.095
1.022
1.200
1.097
1.177
1.000
1.191
0.893
1.117
1.028
1.095
1.183
1.240
1.194
1.178
1.197
2000
1.021
1.124
1.035
1.234
1.061
1.193
0.934
1.138
0.946
1.148
1.046
1.124
0.991
1.244
1.118
1.196
0.999
1.324
1.027
1.142
1.031
1.124
1.061
1.246
1.051
1.201
0.794
1.040
0.918
1.097
1.040
1.124
1.173
1.278
1.109
1.249
1.000
1.259
0.994
1.077
1.069
1.124
1.045
1.246
1.105
1.222
1.000
1.238
0.887
1.133
1.036
1.124
1.237
1.283
1.212
1.222
1.246
Growth Factors
2002 2005 2007
1.029
1.182
1.103
1.334
1.080
1.254
0.927
1.211
0.953
1.194
1.062
1.182
1.029
1.346
1.143
1.261
1.000
1.431
1.035
1.191
1.041
1.182
1.105
1.346
1.069
1.275
0.776
1.084
0.925
1.130
1.055
1.182
1.237
1.388
1.139
1.322
1.000
1.351
1.001
1.107
1.091
1.182
1.079
1.349
1.132
1.304
1.000
1.320
0.894
1.174
1.048
1.182
1.292
1.404
1.257
1.293
1.279
1.041
1.263
1.205
1.483
1.109
1.345
0.918
1.321
0.965
1.262
1.086
1.263
1.087
1.498
1.179
1.359
1.001
1.592
1.047
1.264
1.057
1.263
1.171
1.497
1.095
1.387
0.748
1.150
0.935
1.179
1.077
1.263
1.334
1.555
1.185
1.433
1.200
1.487
1.011
1.152
1.125
1.263
1.130
1.503
1.172
1.428
1.043
1.443
0.904
1.235
1.067
1.263
1.375
1.585
1.323
1.400
1.344
1.050
1.328
1.262
1.580
1.127
1.399
0.915
1.393
0.975
1.306
1.101
1.328
1.121
1.599
1.203
1.418
1.006
1.700
1.058
1.310
1.069
1.328
1.209
1.595
1.113
1.455
0.735
1.191
0.945
1.211
1.092
1.328
1.392
1.666
1.213
1.500
1.200
1.578
1.021
1.181
1.146
1.328
1.158
1.604
1.196
1.504
1.043
1.522
0.914
1.274
1.080
1.328
1.424
1.706
1.366
1.465
1.377
2008
1.055
1.358
1.291
1.629
1.136
1.426
0.915
1.429
0.981
1.327
1.109
1.358
1.138
1.648
1.215
1.447
1.009
1.754
1.064
1.334
1.075
1.358
1.228
1.644
1.121
1.489
0.729
1.212
0.950
1.227
1.100
1.358
1.421
1.721
1.227
1.533
1.400
1.622
1.026
1.196
1.157
1.358
1.172
1.654
1.208
1.542
1.043
1.562
0.919
1.294
1.086
1.358
1.448
1.767
1.387
1.496
1.410
2010
1.064
1.387
1.349
1.725
1.154
1.479
0.913
1.502
0.991
1.370
1.125
1.387
1.172
1.749
1.239
1.505
1.013
1.863
1.075
1.381
1.086
1.387
1.266
1.742
1.139
1.556
0.715
1.253
0.959
1.258
1.116
1.387
1.479
1.832
1.255
1.600
1.400
1.713
1.036
1.226
1.178
1.387
1.200
1.755
1.233
1.618
1.043
1.642
0.929
1.333
1.099
1.387
1.497
1.888
1.429
1.561
1.443
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-58
1997-2010 Methodology
Projections
-------
Table 6.6-2 (continued)
State
Code
32
32
32
32
32
33
33
33
33
33
33
33
33
33
33
34
34
34
34
34
34
34
34
34
34
35
35
35
35
35
35
35
35
35
35
36
36
36
36
36
36
36
36
36
36
37
37
37
37
37
37
37
37
37
37
38
38
SIC
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
SIC Name
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
1999
1.217
0.970
1.198
1.114
1.095
1.084
1.210
1.069
1.090
1.069
1.433
0.963
1.110
1.045
1.095
1.085
1.180
1.055
1.177
0.962
1.236
0.934
1.028
1.033
1.095
1.114
1.240
1.152
1.161
1.250
1.322
0.985
1.207
1.062
1.095
1.063
1.162
0.996
1.130
0.912
1.084
0.959
1.014
1.010
1.095
1.020
1.219
1.103
1.102
0.988
1.192
1.008
1.107
1.054
1.095
0.918
1.207
2000
1.271
0.972
1.225
1.137
1.124
1.104
1.257
1.079
1.101
1.086
1.542
0.949
1.130
1.057
1.124
1.115
1.215
1.066
1.220
0.952
1.295
0.930
1.035
1.042
1.124
1.142
1.300
1.167
1.201
1.250
1.402
0.981
1.241
1.076
1.124
1.097
1.199
0.999
1.162
0.890
1.105
0.949
1.019
1.013
1.124
1.043
1.265
1.118
1.127
0.984
1.240
1.010
1.127
1.067
1.124
0.932
1.252
Growth Factors
2002 2005 2007
1.367
0.977
1.295
1.185
1.182
1.150
1.367
1.104
1.157
1.103
1.705
0.959
1.169
1.077
1.182
1.160
1.297
1.087
1.289
0.941
1.387
0.937
1.049
1.057
1.182
1.196
1.426
1.208
1.273
1.375
1.523
0.987
1.312
1.102
1.182
1.142
1.276
1.004
1.220
0.857
1.146
0.960
1.027
1.017
1.182
1.067
1.373
1.149
1.183
1.004
1.326
1.018
1.168
1.090
1.182
0.969
1.354
1.511
0.984
1.398
1.257
1.263
1.218
1.533
1.140
1.236
1.121
1.950
0.973
1.227
1.107
1.263
1.227
1.421
1.119
1.392
0.925
1.523
0.949
1.071
1.080
1.263
1.277
1.615
1.270
1.382
1.500
1.705
0.996
1.418
1.141
1.263
1.210
1.391
1.011
1.306
0.809
1.206
0.976
1.039
1.023
1.263
1.103
1.536
1.195
1.268
1.033
1.455
1.031
1.229
1.123
1.263
1.025
1.509
1.611
0.992
1.466
1.302
1.328
1.258
1.642
1.164
1.281
1.138
2.115
0.986
1.262
1.128
1.328
1.266
1.499
1.139
1.453
0.918
1.614
0.959
1.085
1.096
1.328
1.325
1.736
1.310
1.448
1.500
1.828
1.005
1.485
1.165
1.328
1.248
1.460
1.017
1.356
0.784
1.243
0.989
1.047
1.029
1.328
1.123
1.643
1.226
1.318
1.053
1.542
1.043
1.269
1.146
1.328
1.057
1.610
2008
1.661
0.995
1.500
1.325
1.358
1.277
1.697
1.177
1.315
1.138
2.198
0.990
1.280
1.138
1.358
1.285
1.538
1.149
1.484
0.915
1.659
0.964
1.092
1.103
1.358
1.349
1.797
1.330
1.481
1.625
1.890
1.010
1.518
1.178
1.358
1.268
1.495
1.020
1.381
0.771
1.262
0.996
1.051
1.031
1.358
1.132
1.696
1.242
1.343
1.064
1.585
1.048
1.288
1.157
1.358
1.074
1.661
2010
1.761
1.003
1.568
1.370
1.387
1.317
1.806
1.201
1.360
1.155
2.363
1.002
1.315
1.158
1.387
1.324
1.616
1.169
1.545
0.909
1.749
0.975
1.106
1.119
1.387
1.397
1.918
1.370
1.547
1.625
2.013
1.019
1.585
1.203
1.387
1.307
1.565
1.025
1.431
0.747
1.299
1.009
1.059
1.037
1.387
1.152
1.804
1.273
1.393
1.084
1.672
1.060
1.328
1.180
1.387
1.106
1.763
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-59
1997-2010 Methodology
Projections
-------
Table 6.6-2 (continued)
State
Code
38
38
38
38
38
38
38
38
39
39
39
39
39
39
39
39
39
39
40
40
40
40
40
40
40
40
40
40
41
41
41
41
41
41
41
41
41
41
42
42
42
42
42
42
42
42
42
42
44
44
44
44
44
44
44
44
44
SIC
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
SIC Name
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
1999
1.097
1.256
1.000
1.227
0.963
1.182
1.012
1.095
1.028
1.192
1.073
1.112
1.006
1.170
0.933
1.091
1.019
1.095
1.105
1.237
1.085
1.114
1.151
1.173
0.981
1.129
1.030
1.095
1.031
1.189
1.092
1.183
1.004
1.233
0.966
1.097
1.055
1.095
1.041
1.183
1.020
1.188
0.973
1.210
0.931
1.061
1.017
1.095
1.105
1.133
1.049
1.134
0.954
1.215
0.917
1.068
1.017
2000
1.109
1.320
1.000
1.284
0.952
1.211
1.016
1.124
1.056
1.236
1.079
1.141
1.008
1.213
0.923
1.105
1.023
1.124
1.142
1.293
1.098
1.143
1.189
1.216
0.983
1.153
1.038
1.124
1.049
1.228
1.103
1.229
1.004
1.291
0.958
1.117
1.067
1.124
1.070
1.226
1.023
1.235
0.966
1.262
0.922
1.070
1.023
1.124
1.129
1.166
1.059
1.165
0.939
1.269
0.910
1.083
1.025
Growth Factors
2002 2005 2007
1.135
1.418
1.000
1.382
0.957
1.271
1.023
1.182
1.098
1.339
1.098
1.185
1.014
1.287
0.930
1.137
1.031
1.182
1.195
1.418
1.121
1.201
1.208
1.294
0.990
1.199
1.052
1.182
1.096
1.324
1.133
1.301
1.000
1.399
0.966
1.158
1.091
1.182
1.114
1.318
1.032
1.297
0.963
1.341
0.929
1.090
1.032
1.182
1.167
1.242
1.078
1.216
0.939
1.358
0.916
1.108
1.038
1.173
1.566
1.000
1.527
0.966
1.360
1.032
1.263
1.162
1.492
1.126
1.253
1.025
1.399
0.942
1.186
1.045
1.263
1.276
1.606
1.157
1.288
1.245
1.409
1.001
1.268
1.072
1.263
1.167
1.468
1.178
1.408
0.993
1.562
0.979
1.219
1.125
1.263
1.180
1.457
1.047
1.391
0.958
1.460
0.939
1.120
1.045
1.263
1.225
1.356
1.107
1.299
0.934
1.493
0.927
1.146
1.058
1.197
1.655
1.000
1.615
0.974
1.416
1.040
1.328
1.199
1.593
1.144
1.290
1.034
1.473
0.953
1.217
1.055
1.328
1.323
1.732
1.180
1.339
1.283
1.485
1.012
1.311
1.086
1.328
1.208
1.561
1.207
1.473
0.993
1.670
0.990
1.258
1.147
1.328
1.218
1.546
1.057
1.445
0.959
1.539
0.948
1.139
1.056
1.328
1.258
1.428
1.127
1.351
0.934
1.582
0.936
1.171
1.072
2008
1.208
1.700
1.000
1.662
0.979
1.444
1.044
1.358
1.217
1.644
1.154
1.309
1.039
1.510
0.958
1.233
1.060
1.358
1.347
1.795
1.192
1.364
1.283
1.523
1.017
1.332
1.093
1.358
1.229
1.607
1.222
1.505
0.992
1.725
0.996
1.278
1.158
1.358
1.237
1.590
1.062
1.473
0.959
1.578
0.953
1.149
1.061
1.358
1.274
1.464
1.136
1.371
0.934
1.627
0.941
1.183
1.079
2010
1.232
1.790
1.000
1.751
0.987
1.500
1.052
1.387
1.253
1.745
1.172
1.346
1.048
1.583
0.968
1.264
1.070
1.387
1.395
1.921
1.215
1.416
1.321
1.599
1.027
1.375
1.108
1.387
1.271
1.701
1.250
1.570
0.992
1.833
1.007
1.318
1.181
1.387
1.275
1.679
1.072
1.527
0.959
1.657
0.962
1.168
1.072
1.387
1.307
1.536
1.156
1.423
0.934
1.716
0.951
1.208
1.093
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-60
1997-2010 Methodology
Projections
-------
Table 6.6-2 (continued)
State
Code
44
45
45
45
45
45
45
45
45
45
45
46
46
46
46
46
46
46
46
46
46
47
47
47
47
47
47
47
47
47
47
48
48
48
48
48
48
48
48
48
48
49
49
49
49
49
49
49
49
49
49
50
50
50
50
50
50
SIC
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
SIC Name
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
1999
1.095
1.060
1.201
1.081
1.096
1.023
1.215
0.906
1.139
1.044
1.095
1.018
1.195
1.083
1.213
1.000
1.220
0.960
1.225
1.037
1.095
1.045
1.218
1.091
1.122
1.063
1.212
0.949
1.123
1.048
1.095
1.108
1.207
1.073
1.201
1.025
1.209
0.998
1.112
1.056
1.095
1.094
1.264
1.150
1.179
1.150
1.246
0.953
1.186
1.087
1.095
1.064
1.202
1.072
1.127
1.000
1.283
2000
1.124
1.085
1.248
1.100
1.119
1.029
1.268
0.907
1.172
1.056
1.124
1.041
1.232
1.092
1.267
1.000
1.273
0.948
1.265
1.047
1.124
1.076
1.264
1.103
1.152
1.078
1.265
0.944
1.146
1.060
1.124
1.133
1.253
1.087
1.252
1.032
1.261
0.998
1.134
1.068
1.124
1.128
1.319
1.167
1.224
1.150
1.308
0.951
1.225
1.108
1.124
1.097
1.253
1.087
1.155
1.000
1.350
Growth Factors
2002 2005 2007
1.182
1.120
1.349
1.133
1.184
1.043
1.382
0.914
1.231
1.077
1.182
1.076
1.325
1.116
1.342
1.000
1.360
0.959
1.353
1.064
1.182
1.124
1.375
1.128
1.217
1.100
1.366
0.952
1.191
1.079
1.182
1.187
1.362
1.115
1.335
1.037
1.352
1.002
1.180
1.090
1.182
1.174
1.450
1.219
1.304
1.150
1.412
0.957
1.302
1.147
1.182
1.144
1.358
1.110
1.211
1.000
1.448
1.263
1.173
1.499
1.183
1.280
1.065
1.551
0.924
1.319
1.109
1.263
1.130
1.463
1.150
1.455
1.000
1.493
0.974
1.485
1.089
1.263
1.196
1.541
1.166
1.315
1.134
1.519
0.964
1.257
1.108
1.263
1.269
1.526
1.156
1.461
1.044
1.489
1.009
1.248
1.123
1.263
1.243
1.646
1.297
1.423
1.200
1.567
0.967
1.418
1.206
1.263
1.215
1.516
1.143
1.289
1.019
1.601
1.328
1.202
1.597
1.215
1.338
1.079
1.664
0.934
1.375
1.130
1.328
1.162
1.553
1.172
1.524
1.000
1.583
0.987
1.570
1.106
1.328
1.238
1.650
1.191
1.373
1.156
1.618
0.975
1.299
1.127
1.328
1.317
1.634
1.183
1.538
1.052
1.581
1.018
1.292
1.144
1.328
1.282
1.779
1.347
1.497
1.200
1.672
0.976
1.490
1.242
1.328
1.256
1.619
1.165
1.331
1.038
1.704
2008
1.358
1.216
1.647
1.231
1.367
1.086
1.720
0.939
1.402
1.141
1.358
1.177
1.597
1.183
1.557
1.000
1.627
0.993
1.612
1.114
1.358
1.260
1.705
1.204
1.402
1.166
1.668
0.981
1.320
1.137
1.358
1.341
1.688
1.196
1.577
1.056
1.627
1.022
1.314
1.154
1.358
1.302
1.846
1.372
1.534
1.250
1.725
0.980
1.527
1.260
1.358
1.276
1.670
1.176
1.359
1.038
1.753
2010
1.387
1.245
1.745
1.264
1.425
1.101
1.832
0.949
1.458
1.162
1.387
1.209
1.687
1.205
1.626
1.000
1.717
1.006
1.697
1.130
1.387
1.302
1.815
1.229
1.460
1.188
1.768
0.992
1.363
1.157
1.387
1.388
1.796
1.222
1.654
1.064
1.718
1.030
1.358
1.175
1.387
1.342
1.979
1.421
1.608
1.250
1.830
0.989
1.599
1.295
1.387
1.317
1.774
1.198
1.401
1.058
1.857
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-61
1997-2010 Methodology
Projections
-------
Table 6.6-2 (continued)
State
Code
50
50
50
50
51
51
51
51
51
51
51
51
51
51
53
53
53
53
53
53
53
53
53
53
54
54
54
54
54
54
54
54
54
54
55
55
55
55
55
55
55
55
55
55
56
56
56
56
56
56
56
56
56
56
SIC
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
01
07
15
40
44
45
992*
998*
999*
LTD*
SIC Name
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
Farm
Agricultural services, forestry, fisheries, and other
Construction
Railroad Transportation
Water Transportation
Transportation by air
Federal, military
Total Manufacturing
Population
Landing-Takeoff Operations
1999
1.007
1.085
1.041
1.095
0.948
1.213
1.067
1.164
0.996
1.174
0.963
1.062
1.043
1.095
1.013
1.146
1.053
1.201
0.996
1.137
0.981
1.062
1.064
1.095
1.144
1.233
1.069
1.109
1.011
1.164
0.979
1.035
1.014
1.095
1.014
1.214
1.064
1.206
1.000
1.188
0.971
1.120
1.032
1.095
1.138
1.228
1.075
1.162
1.071
1.209
1.047
1.116
1.039
1.095
2000
1.005
1.110
1.053
1.124
0.967
1.256
1.074
1.205
0.994
1.218
0.963
1.075
1.054
1.124
1.020
1.186
1.068
1.251
0.995
1.171
0.979
1.079
1.079
1.124
1.192
1.286
1.073
1.136
1.014
1.205
0.995
1.040
1.018
1.124
1.060
1.265
1.075
1.258
1.000
1.235
0.957
1.140
1.041
1.124
1.162
1.279
1.083
1.203
1.071
1.257
1.071
1.139
1.048
1.124
Growth Factors
2002 2005 2007
1.018
1.146
1.072
1.182
0.991
1.363
1.100
1.286
1.003
1.292
0.971
1.108
1.074
1.182
1.065
1.272
1.096
1.331
1.002
1.249
0.986
1.125
1.109
1.182
1.278
1.408
1.082
1.199
1.017
1.276
1.005
1.060
1.024
1.182
1.130
1.373
1.096
1.325
0.996
1.322
0.967
1.183
1.055
1.182
1.218
1.395
1.108
1.282
1.071
1.340
1.079
1.184
1.064
1.182
1.037
1.200
1.100
1.263
1.028
1.524
1.138
1.406
1.017
1.404
0.982
1.158
1.104
1.263
1.132
1.400
1.137
1.449
1.012
1.366
0.997
1.193
1.154
1.263
1.407
1.591
1.097
1.293
1.022
1.380
1.022
1.090
1.032
1.263
1.233
1.535
1.128
1.426
0.991
1.452
0.983
1.247
1.078
1.263
1.301
1.568
1.146
1.402
1.143
1.461
1.090
1.253
1.088
1.263
1.050
1.234
1.120
1.328
1.048
1.631
1.164
1.481
1.028
1.478
0.993
1.190
1.125
1.328
1.172
1.481
1.164
1.523
1.022
1.442
1.008
1.238
1.183
1.328
1.485
1.714
1.108
1.349
1.028
1.451
1.034
1.109
1.041
1.328
1.288
1.642
1.150
1.486
0.991
1.539
0.996
1.287
1.093
1.328
1.350
1.684
1.171
1.476
1.143
1.545
1.100
1.297
1.103
1.328
2008
1.059
1.251
1.130
1.358
1.058
1.684
1.177
1.518
1.033
1.515
0.998
1.207
1.135
1.358
1.193
1.522
1.177
1.559
1.027
1.481
1.013
1.261
1.197
1.358
1.525
1.774
1.114
1.377
1.034
1.486
1.042
1.119
1.046
1.358
1.316
1.695
1.160
1.516
0.991
1.583
1.003
1.308
1.101
1.358
1.374
1.741
1.183
1.513
1.143
1.581
1.106
1.319
1.110
1.358
2010
1.073
1.285
1.150
1.387
1.078
1.790
1.203
1.592
1.045
1.589
1.008
1.240
1.156
1.387
1.233
1.604
1.203
1.632
1.036
1.557
1.023
1.306
1.226
1.387
1.603
1.897
1.126
1.433
1.039
1.557
1.054
1.139
1.055
1.387
1.371
1.802
1.181
1.576
0.991
1.670
1.016
1.348
1.117
1.387
1.423
1.857
1.208
1.587
1.143
1.665
1.116
1.363
1.126
1.387
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-62
1997-2010 Methodology
Projections
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