United States
Environmental Protection
Agency
Office of Air Quality
Planning and Standards
Research Triangle Park NC 27711
EPA-454/R-98-008/^
June 1998
Air
NATIONAL AIR POLLUTANT
EMISSION TRENDS
PROCEDURES DOCUMENT,
1900-1996
PROJECTIONS 1999-2010
Sources
Point
Area
On-road
Top 25 Emitting Point, Area, and On-road Sources
of VOC Emissions in 1996 by MSAs
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CONTENTS
Page
TABLES AND FIGURES ................... ____ v -
..... • • • ....... •••••..... ............ A.A.11
ACRONYMS AND ABBREVIATIONS .......
" ..... ••••••••••••••••••••.......„
SECTION 1.0
INTRODUCTION ....................... ............. ll
1.1 REFERENCES ............................. "'"'"'''' '.'. ......... ........... i~2
SECTION 2.0
1900 - 1939 METHODOLOGY .............................. 2-1
2. 1 DESCRIPTION OF EMISSION ESTIMATION METHODOLOGIES FOR SO^ AND NO^ 2-1
2.1.1 State-Level Estimates ................................ .............. * 2_i
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 ..................... 25
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 211
2.3 REFERENCES ............................................. '.'.'.'.'.'.' '* ....... 2-11
SECTION 3.0
1940 - 1984 METHODOLOGY ........................ 3 1
3.1 INTRODUCTION ...... . ..................... .'.'.'.".'.'.'" '.'. '.'.. '.'.. ...... ..... 3~i
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_2j
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
n
c
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CONTENTS (continued)
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
335 References 3-29
3.4 FUEL COMBUSTION ELECTRIC UTILITY- GAS: 01-03 3-31
3.4.1 Technical Approach 3~3^
3.4.2 Activity Indicator 3"3^
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-S4
3.5.1 Technical Approach 3~34
3.5.2 Activity Indicator 3~34
3.5.3 Emission Factors 3"3^
3.5.4 Control Efficiency 3-35
355 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 3~4Q
3.6.5 References • 3'40
3.7 FUEL COMBUSTION INDUSTRIAL- GAS: 02-03 5-42
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"4^
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-COMMERCIAUINSTrrUTIONAL 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~->4
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 IV Contents
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CONTENTS (continued)
3.10 FUEL COMBUSTION OTHER - COMMERCIAUINSTrrUTIONAL OIL: 03-02 . 3-56
Technical Approach ............... .......................... 3.55
Activity Indicator ...................................... ^-56
Emission Factor ........................................ 3_57
Control Efficiency ............ .............................. 3,5-7
References .................. ............. . ........... 3_5g
3.11 FUEL COMBUSTION OTHER - COMMERCIAL/INSTrrUTIONAL GAS : 03-03 3-59
Technical Approach .............................. 3.59
Activity Indicator ............................................ 3,59
Emission Factor ........................................ 3-60
Control Efficiency ............ ............................. T>-6Q
References .................. ....................... 3-60
3.12 FUEL COMBUSTION OTHER - RESIDENTIAL WOOD: 03-05 ".'.'.'.'.'.'.'.'.'.'.'.'. . 3-61
3.12.1 Technical Approach ....... . .................................. ^-61
Activity Indicator ............................................. 3_gj
Emission Factor ................................... . ......... 3_g2
Control Efficiency ............................................ 3.53
References ......................................... 3-63
3.13 FUEL COMBUSTION OTHER - RESIDENTIAL OTHER: 03-06 . . '.'.'.'. '. '. '. . .... 3-64
Technical Approach: .............. • ................................ 3.54
Activity Indicator: ................................................. 3,55
Emission Factors: ............................................ ^,-66
Control Efficiency ............ . ................................... 3.67
3.10.1
3.10.2
3.10.3
3.10.4
3.10.5
3.11.1
3.11.2
3.1 1.3
3.11.4
3.11.5
3.12.2
3.12.3
3.12.4
3.12.5
3.13.1
3.13.2
3.13.3
3.13.4
3.13.5
References
3 . 14
3-67
CHEMICAL AND ALLIED PRODUCT MANUFACTURING - ORGANIC CHEMICAL
MANUFACTURING: 04-01 ............................................ 3_69
3.14.1 Technical Approach ............................................... 3.59
3.14.2 Activity Indicator .............................................. 3.59
3.14.2.1 CO Emissions ................................... ............. 3-69
3.14.2.2 NOX Emissions ........................................ 3-10
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
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 NOxEmissions 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 vi - Contents
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CONTENTS (continued)
3.19.4 Control Efficiency 3.91
3.19.5 References 3.9 j
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 3.93
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_1 JQ
3.22.2 Activity Indicator 3-111
3.22.2.1 CO Emissions 3-111
3.22.2.2 NOX Emissions 2-111
3.22.2.3 PM-10 and TSP Emissions '.'.'.'.'.'.'.'.'.'.'. 3-111
3.22.2.4 SO2 Emissions 3-113 •
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
Vll
Contents
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CONTENTS (continued)
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: 661Q8
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
3.25.4.1 CO Emissions 3-134
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
vm
Contents
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CONTENTS (continued)
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
3.26.1
3.26.2
3.26.3
3.26.4
3.26.5
3-138
Technical Approach ., 3-138
Activity Indicator 3-138
Emission Factor 3-139
Control Efficiency 3-139
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
3.30.2.2 NOX Emissions 3-157
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
IX
Contents
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CONTENTS (continued)
Pas
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
3.35.5 References 3-185
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
Contents
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CONTENTS (continued)
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 E: 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
3.42.4 Control Efficiency 3-200
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Contents
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CONTENTS (continued)
Page
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
348 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
3.49.3 Emission Factor 3-228
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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CONTENTS (continued)
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_j
4.1 INTRODUCTION ... .........................4-1
4.1.1 Lead Emissions 4_2
4.1.2 Carbon Monoxide, Nitrogen Oxides, Volatile Organic Compounds, Sulfur Dioxide,
Paniculate 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/CEMData .... 4_27
4.2.1.6 Ozone Season Daily Emissions Data 4-28
4.2.2 1996 Steam Emission Inventory 4_2g
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
4.3.1 1990 Interim Inventory 4.37
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
Xlll
Contents
-------
CONTENTS (continued)
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'm
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
4.4.5 1995 Emissions 4'115
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 XIV Contents
-------
CONTENTS (continued)
'age
4.4.5.1 Grown Estimate . 4-115
4.4.5.2 NOX RACT 4_H5
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-llB
4.4.1.4 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_i46
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
4.6.2.4 Operating Mode 4-184
National Mr Pollutant Emission Trends
Procedures Document for 1900-1996
XV
Contents
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CONTENTS (continued)
Page
4.6.2.5 Altitude 4-184
4.6.2.6 Registration Distribution/Month 4-184
4.6.2.7 MONTHFlag 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 FUGmVEDUST 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
4.8.2.5 PM Emissions from Reentrained Road Dust from Paved Roads 4-281
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
XVI
Contents
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CONTENTS (continued)
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_!
5.1 INTRODUCTION ; ........................5-1
5.1.1 Background 5_1
5.1.2 General Procedure 5_j_
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_g
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_H
5.4.2 Activity Indicator 5_U
5.4.3 Emission Factors 5_U
5.4.4 Control Efficiency 5_11
5.4.5 References 5-\2
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 5.44
5.5.5 References 5-14
5.6 FUEL COMBUSTION OTHER - COMMERCIAITTNSTITUTIONAL 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 •. .
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
XV11
Contents
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CONTENTS (continued)
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
,C -I Q
C *7 £? R.Gfi5T"GTlCGS .........••••••••••••••• 3~J.s
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
5O C TO ofoYV^T'l/^P'O
,o.D jtxciGrencco
5.9 FUEL COMBUSTION OTHER - RESIDENTIAL OTHER:
5.9.1
5.9.2
03-06 5-22
Technical Approach 5-22
Activity indicator 5-22
5.9.3
5.9.4
5.9.5
5.10.3
5.10.4
5.10.5
Emission Factors 5-23
Control Efficiency 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
Emission Factor 5-25
Control Efficiency 5-25
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
XV111
Contents
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CONTENTS (continued)
5.12.2 Activity Indicator 5.39
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 5.35
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 5.33
5.15.1 Technical Approach 5.33
5.15.2 Activity Indicator 5.33
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 5/1/1
5.17.5 Allocation of Emissions to the Tier n 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)
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 MOBUJBSb Inputs 6-23
6.5.3 Additional MOBELESb 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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6.6
CONTENTS (continued)
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 MONTHFlag '.'.'.'.'.'.'.'.'.'.'.'.'.'. 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 PARTS Model Inputs 6-28
6.5.5 Calculation of Highway Vehicle Emission Inventories 6-28
6.5.6 References 6-28
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
Pas
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 and NOX 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 H 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
-------
TABLES AND FIGURES (continued)
Tables
Pat
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
xxm
Tables and Figures
-------
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 n 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 n 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 t 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
-------
TABLES AND FIGURES (continued)
Tables
Pai
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 n Programs that use Reformulated Gasoline ... 4-97
4.3-27. VOC Area Source RACT 4.93
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
MOBILESa 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
4.6-6. Cities Used for Temperature Data Modeling from 1970 through 1996
4.6-7. Surrogate City Assignment
4.6-8. Substitute Survey City Assignment
4.6-9. Monthly RVP Values Modeled in 1995
4.6-10. Monthly RVP Values Modeled in 1996
4.6-11. HPMS Average Overall Travel Speeds for 1990
4.6-12. Average Speeds by Road Type and Vehicle Type
4.6-13. State-Supplied Operating Mode Inputs
4.6-14. I/M Program Documentation (1995 and 1996)
4.6-15. Counties Included in 1995 and 1996 I/M Programs
4.6-16. Oxygenated Fuel Modeling Parameters
4.6-17. State-Supplied Trip Length Distribution Inputs
4.6-18. State-Supplied Alcohol Fuels Data
4.6.19. State-Provided Diesel Sales Inputs
4.6-20. Counties Modeled with Federal Reformulated Gasoline
4.6-21. PARTS Vehicle Classes
4.6-22. Average Speeds by Road Type and Vehicle Type
4.6-23. PM-10 Emission Factors used in the Emission Trends Inventory .
4.6-24. Fuel Economy Values Used in Calculation of SO2 Emission Factors for the Emission
Trends Inventory
4.6-25. SO2 Emission Factors used in the Emission Trends Inventory
4.6-26. Fractions of Vehicles Equipped with 3-Way Catalysts by Vehicle Type and Model Year
4.6-27. Ammonia Emission Factors by Year and Vehicle Type
4.7-1. Ozone Nonattainment Areas with QMS-Prepared Non-road Emissions
4.7-2. Source Categories Used for Nonroad Emissions
4.7-3. Railroad Locomotives Diesel Fuel Consumption, 1985 to 1990
4.7-4. Railroad Emission Factors
4.7-5. Civil Aircraft SO2 Emission Factors
4.7-6. Area Source Growth Indicators
4.7-7. Bureau of Economic Analysis's SA-5 National Changes in Earnings by Industry
4.7-8. AMS to NAPAP Source Category Correspondence
4.7-9. Non-road Data Submitted for OTAG Inventory
4.7-10. Area Source Listing by SCC and Growth Basis
4.7-11. SEDS National Fuel Consumption, 1990-1996 (trillion Btu)
4.7-12. BEA SA-5 National Earnings by Industry, 1990-1996
4.7-13. Counties in the United States with Stage n Programs that use Reformulated Gasoline .
4.7-14. NOX Nonroad Control Efficiencies by SCC
4.7-15. National Nonroad Diesel Emissions
4.7-16. National Spark Ignition Marine Engine Emissions
4.7-17. National Locomotive Emissions
4.8-1. Particle Size Ratios
4.8-2. Silt Content by Soil Type, 1985 to 1989
4-213
4-214
4-218
4-219
4-221
4-223
4-224
4-225
4-226
4-228
4-231
4-232
4-232
4-233
4-235
4-238
4-238
4-239
4-239
4-240
4-241
4-242
4-257
4-258
4-259
4-259
4-260
4-261
4-261
4-262
4-263
4-264
4-265
4-265
4-266
4-267
4-268
4-269
4-269
4-300
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_30Q
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 n 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_2i
5.17-1. Number of Grams of Lead/Gasoline (Y) 5.45
5.17-2. Relative VMT Fractions for Each Tier H 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 ' g.g
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 LTVI 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
XX Vll
Tables and Figures
-------
Tables
6.5-11.
6.6-1.
6.6-2.
TABLES AND FIGURES (continued)
Counties Modeled with Federal Reformulated Gasoline 6-47
SCC-SIC Crosswalk 6-53
1999 - 2010 Growth Factors 6-54
Figures
4.3-1.
4.3-2.
4.6-1.
4.6-2.
4.7-1.
OTAG Inventory Data Source - Area Sources 4-99
OTAG Inventory Data Source - Point Sources 4-100
State-Provided Registration Distributions 4-243
OTAG Inventory Source of Data - VMT 4-244
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
GEM
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
VM
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
LDV
LTO
MACT
MRI
MW
NAA
NADB
NAPAP
NEDS
NESHAP
NH3
NPI
NSPS
OAQPS
QMS
OSD
OTAG
OTR
Pb
PCE
PM
PM-2.5
PM-10
ppm
QA
QC
RACT
RCRA
ROM
RVP
SCC
SEDS
SIC
SIP
SO2
SO4
SUPROXA
TOG
tpy
TSDF
TSP
light duty truck
light duty vehicle
landing and takeoff
maximum available control technology
Midwest Research Institute
megawatts
nonattainment area
National Allowance Data Base
National Acid Precipitation Assessment Program
National Emission Data System
National Emission Standards for Hazardous Air Pollutants
National Emissions Trends (inventory)
ammonia
oxides of nitrogen
National Particulates Inventory
New Source Performance Standards
EPA, Office of Air Quality Standards and Planning
EPA, Office of Mobile Sources
ozone season daily
Ozone Transport Assessment Group
ozone transport region
lead
personal consumption expenditures
paniculate matter
particulate matter less than 2.5 microns in diameter
particulate matter less than 10 microns in diameter
parts per million
quality assurance
quality control
Reasonably Available Control Technology
Resource Conservation and Recovery Act
Regional Oxidant Model
Reid vapor pressure
source classification code
State Energy Data System
Standard Industrial Classification (code)
State Implementation Plan
sulfur dioxide
sulfates
Super Regional Oxidant A
total organics
tons per year
hazardous waste treatment, storage, and disposal facility
total suspended particulate matter
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
XXX
Acronyms and Abbreviations
-------
ACRONYMS AND ABBREVIATIONS (continued)
USDA
USFS
VMT
VOC
U.S. Department of Agriculture
USDA Forest Service
vehicle miles traveled
volatile organic compound(s)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
XXXI
-------
-------
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), paniculate matter less than 10 microns
(PM-10), sulfur dioxide (SO2), and volatile organic compounds (VOC). In addition, total paniculate
matter (TSP) has been estimated in the past. For the years 1990-1996, paniculate 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 HI 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
1 985 through 1 989 and
1 990 through 1 996
1 999, 2000, 2002, 2005,
2007,2008,2010
1900-1939
1940 through 1969
1 970 through 1 993
1999,2000,2002,2005,
2007,2008,2010
Pollutant(s)
VOC, SO2> and NOX
VOC, SO2, NOX, CO,
and PM-10
Pb
VOC, SO2, NOX, CO,
and PM-10
VOC, S02, NOX, CO,
PM-10, PM-2.5, and
NHa
Pb
VOC, S02, 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, S02, NOX, CO,
and PM-1 0
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
_ead
Methodology
1985-1993
Methodology
1990-1996
Methodology
Lead
Methodology
Rejection
Methodoloqy
Section
2
3
5
4
4
5
6
2
3
. 5
4
4
5
6
NOTE(S): SO2, VOC, and NOX estimated 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.'
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 1960.a 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.
SO2 emissions f
x
(Eq.2.1-1)
NOY emissions. . .
A *» J i K-
= FC
' P^
X
EF
^ j, NOX
(Eq. 2.1-2)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-2
1900-1939 Methodology
-------
where: PC =
EF =
S =
fuel consumption
emission factor
sulfur content
i = year
j = source category/fuel type
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 .
FE. )
x
(Eq. 2.1-3)
On-road Vehicle Emissions
. k x EF^, j, k
(Eq. 2.1-4)
where: EC
FE
EF
i
j
k
VMT
fuel consumption
fuel efficiency (gasoline-powered vehicles only)
emission factor
year
SO2 or NOX
state
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
x
(Eq.2.1-5)
where: E =
A =
EF =
emission estimate
activity indicator
emission factor
i = year
j = SO2orNOx
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 I960, 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
-------
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.
SEi =
NEi
NE
1980
(Eq.2.1-6)
where: SE =
NE =
i =
SO2 or NOX state emission estimate
SO2 or NOX national emission estimate
year
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-5
1900-1939 Methodology
-------
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.
r^ (Eq. 2.1-7)
SE. = SE
1980
X
1980
where: SE =
S =
i =
SO2 or NOX state emissions
state population
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.
= (SEt.s - SEi+j) x
NF
N
- NF
. .
(Eq. 2.1-9)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-6
1900-1939 Methodology
-------
where: SE =
NF =
i =
1 ~~
SO2 or NOX state emissions by source category and fuel type
national fuel consumption data corresponding to source category and fuel type
study year (i.e., 1900, 1905, ..., 1970)
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.+5 - SE.) x 775)
(Eq. 2.1-10)
where: SE =
i =
SO2 or NOX state emissions by source category
study year (i.e., 1900, 1905, ..., 1970)
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-7
1900-1939 Methodology
-------
which 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.
i ^Historic, i X
^Tierl
IE (*,
rier\ 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.
Tierl.i+j
Total, i+j X
Tier 1, i + ^ Tier I, ;+5
^
Total, i
'Total, i + 5
(Eq. 2.1-12)
where: E
i
= SO,
J
Tier I
Total
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
20
-O
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.
NEF.
NE.
(Eq. 2.2-1)
where: NEF
NE
NA
national emission factor
national emissions
national activity indicator
year
source subcategory
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
-------
= NEF
x NAtiJ
(Eq. 2.2-2)
where: NEF
NE
NA
national emission factor i
national emission estimate j
national activity indicator
year
source subcategory
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.
NE
t+J
NE..
(Eq. 2.2-3)
NEt.j = NE,
x
7/5
(Eq. 2.2-4)
where: NE =
NA =
i =
j
national emissions by source subcategory
national activity by source category
study year (1900, 1905,...,1970)
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 (NTTS 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 (NTTS 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 (NTTS
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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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-12
1900-1939 Methodology
-------
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
* 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
-------
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 1 945)
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 1 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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Procedures Document for 1900-1996
2-15
1900-1939 Methodology
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-16
1900-1939 Methodology
-------
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
1 1 .47
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9.57
8.94
7.79
6.65
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
2-17
1900-1939 Methodology
-------
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
-------
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)
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 n category. The estimation
procedures are presented in this section by the Tier n categories. Correspondence between these Tier n
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 n 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.
(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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-2
1940-1984 Methodology
-------
TRENDSxx.XLS spreadsheet from the previous year 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 n 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 ton (long)
1 ton (short)
Mb (metric)
Ibbl
1.1023 tons (short)
1.12 tons (short)
0.9072 tons (metric)
1.10231b
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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-3
1940-1984 Methodology
-------
Calculation of the control efficiency involves three steps.
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
emissions
' 100° 1 x 5 19
gallons\
Ibs
1000
gallons
„ l[to«]
2000[lbs]
For SCC = 1-01-005-01
Uncontrolled
emissions
F 1000
\gauons
Ibs
1000
gallons
The control efficiency for this source category was calculated as follows:
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-4
1940-1984 Methodology
-------
Control ((1089 + 36) - (723 + U))[tons]
efficiency
(1089 + 36)[tons]
x 100 = 35%
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 n 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 n 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, n category.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-5
1940-1984 Methodology
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-16
1940-1984 Methodology
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-17
1940-1984 Methodology
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
1940-1984 Methodology
3-18
-------
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 gal Ions
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
Comont Manufacture
Fugitives
Lime Manufacture
Fugitives
Miscellaneous Process Sources
Pulp and Paper
Sulfito
Semtehemlcal, recovery furnace
Wood Products
Plywood
Lumber
Solid Waste Disposal
Incinerators
Residential Single Chamber
w/o Primary Burner
w/ Primary Burner
Forest Rres 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 H category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(01) FUEL COMBUSTION -
ELECTRIC UTILITY
3.2.1 Technical Approach
Tier n Category
(01) Coal
Tier n Subcategory
Bituminous, Subbituminous, and
Lignite Coal
Anthracite Coal
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 Emissions^ = PM-10 Emissions^ x r5P Emissions year
TSP Emissions
1975
(Eq. 3.2-1)
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,^ ,, coal = A/,,. coal x EF^ „ ^ x [l - [RE x ^^ *"*] } (Eq. 3.2-2)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-21
1940-1984 Methodology
Category: 01-01
-------
where: AI =
EF =
RE =
CE =
activity indicator
emission factor
rule effectiveness of 0.80
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
Procedures Document for 1900-1996
3-22
1940-1984 Methodology
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.
EF
(Q
uncontrolled
SBxEFSBx SSB)
EFLx
(Eq. 3.2-3)
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
Procedures Document for 1900-1996
3-23
1940-1984 Methodology
Category: 01-01
-------
controlled TSP emissions. These values were used in Equation 3.2-4 to calculate the TSP control
efficiencies.
CE -
UE
(Eq. 3.2-4)
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.
SO.
2,removed
= C x
UC
PC
x EF.
uncontrolled
x RF x SC x OP
(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 S.2.-6 and was then applied to the uncontrolled
emission factor to obtain the controlled emission factor.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-24
1940-1984 Methodology
Category: 01-01
-------
CE,
SO
SO-,
2, removed
EF x AJ
uncontrolled Bituminous Coal
(Eq. 3.2-6)
where: CE =
EF =
control efficiency
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/lQ). 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
Procedures Document for 1900-1996
3-25
1940-1984 Methodology
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..
1.1. 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 Polluiant Emission Trends
Procedures Document for 1900-1996
3-26
1940-1984 Methodology
Category: 01-01
-------
3.3 FUEL COMBUSTION ELECTRIC UTILITY - OIL: 01-02
The emissions for this Tier H category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(01) FUEL COMBUSTION -
ELECTRIC UTILITY
Tier n Category
(02) Oil
Tier n Subcategorv
Residual
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.
PM-10 Emissionsyear = PM-10 Emissions 19?5 x
TSP Emissions.
TSP Emissions 19J5
(Eq. 3.3-1)
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.
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3.3.3 Emission Factors
The emission factors for residual oil were calculated from the emission factors for the following
fourSCCs: 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 n category.
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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 19xx. 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.
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Table 3.3-1. Emission Factor SCCs for Distillate
Oil Combustion by Electric Utility
sec
Description
Weighting
Factors
1-01-005-01
1-01-005-04
2-01-001-01
2-01-001-02
Boiler - #2 oil
Boiler - #4 oil
Nonboiler - gas turbine
Nonboiler - reciprocating
0.9
0.1
0.9
0.1
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3.4 FUEL COMBUSTION ELECTRIC UTILITY-GAS: 01-03
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(01) FUEL COMBUSTION -
ELECTRIC UTILITY
Tier n Category
(03) Gas
Tier n Subcategory
Natural Gas
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.
PM-10 Emissions,.,., = PM-10 Emissions,^ x
year
1975
TSP Emissions
TSP Emissions 1975
(Eq. 3.4-1)
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.
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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 n 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.
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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 I9xx. 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
sec
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
Tangential
New Source Performance Standard
550
275
200
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3.5 FUEL COMBUSTION INDUSTRIAL - COAL: 02-01
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(02) FUEL COMBUSTION -
INDUSTRIAL
Tier n Category
(01) Coal
Tier n 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
TSP Emissions
year
1975 . . -
Iy7i TSP Emissions
(Eq. 3.5-1)
1975
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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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 percept 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 n 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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CE
\(UE-AE)]
~ [ UE~\
(Eq. 3.5-2)
where: CE =
UE =
AE =
control efficiency
emissions before control
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/lQ). 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 E category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(02) FUEL COMBUSTION-
INDUSTRIAL
Tier H Category
(02) Oil
Tier n Subcategory
Residual
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,^, x .—: y-—
year iyo TSP Emissions,
(Eq. 3.6-1)
'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
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were 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 n category.
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3.6.4 Control Efficiency
The PM-10 control efficiencies for all emission sources included in this Tier n 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 n 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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Procedures Document for 1900-1996
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1940-1984 Methodology
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3.7 FUEL COMBUSTION INDUSTRIAL - GAS: 02-03
The emissions for this Tier H category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(02) FUEL COMBUSTION-
INDUSTRIAL
Tier n Category
(03) Gas
Tier n Subcategory
Natural Gas - boilers and gas
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.
PM-10 Emissionsvear = PM-10 Emissions
y£ar
TSP Emissions
x
year
. .
TSP Emissions
(Eq. 3.7-1)
1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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1940-1984 Methodology
Category: 02-03
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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
National Air Pollutant Emission Trends
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.1940-1984 Methodology
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emission factors were obtained from Reference 9a, and the VOC emission factor from Reference 9d. In
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 n category.
3.7.4 Control Efficiency
The PM-10 control efficiencies for all emission sources included in this Tier H 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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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1940-1984 Methodology
Category. 02-03
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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 CVOC) 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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Procedures Document for 1900-1996
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3.8 FUEL COMBUSTION INDUSTRIAL - OTHER: 02-04
The emissions for this Tier E category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(02) FUEL COMBUSTION -
INDUSTRIAL
Tier n Category
(04) Other External
Combustion
Tier n 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.
TSP Emissions
PM-10 Emissions Vfnr = PM-10 Emissions 1975 x . .
year y TSP Emissions
year
(Eq. 3.8-1)
1975
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.
National Air Pollutant Emission Trends
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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:
LPG
Industrial, i
Products
'industrial, 1982
X
Supplied, i
Products
Supplied, 1982
(Eq. 3.8-2)
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 n category.
3.8.4 Control Efficiency
The PM-10 control efficiencies for all emission sources included in this Tier n 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 n 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/lQ). 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
Coal Coke 4.6 30.3 14.0 0.64
0.54
0.54
1.2
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 E category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(03) FUEL COMBUSTION -
OTHER
Tier n Category
Tier n Subcategory
(01) Commercial/Institutional Anthracite Coal
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.
PM-10 Emissionsyear = PM-10 Emissions 1975 x
TSP Emissions
year
Emissians
(Eq. 3.9-1)
1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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3.9.2 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
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 Coalc/l = Anthracite CoalR and c// - Anthracite CoalR
. 3.9.2)
where: C/I =
R =
commercial/institutional consumption
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.
Anthracite Coal
R, i
= Anthracite Coal,, . , x
A, / - 1
Dwelling Units.
Dwelling Units._l
(Eq. 3.9-3)
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 Coalc/l = (All CoalR antl a, - Anthracite CoalR and c//) - Bituminous CoalR
(Eq. 3.9-4)
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where: C/I = commercial/institutional consumption
R = residential consumption
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 burnedldwellinglyear) - 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.
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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 n category.
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-AE)]
UE
\
(Eq. 3.9-6)
where: CE =
UE =
AE =
control efficiency
uncontrolled emissions
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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Category. 03-01
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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.
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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
(03) FUEL COMBUSTION -
OTHER
Tier H Category
Tier n Subcategory
(02) Commercial/Institutional Residual
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.
PM-10 Emissions,,,^ = PM-10 Emissions 10_- x
TSP Emissions
year
year
TSP Emissions
(Eq. 3.10-1)
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.
Residual Oil
x „ 13
87)
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 n category.
3.10.4 Control Efficiency
The PM-10 control efficiencies for all emission sources included in this Tier n 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 n 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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Procedures Document for 1900-1996
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3.11 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL GAS: 03-03
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(03) FUEL COMBUSTION -
OTHER
Tier n Category
Tier II Subcategorv
(03) Commercial/Institutional Natural Gas
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:
PM-10 Emissions = PM-10 Emissions 19?5 x misslonsyear
TSP Emissions 19J5
(Eq. 3.11-1)
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.
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 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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Procedures Document for 1900-1996
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Category: 03-03
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3.12 FUEL COMBUSTION OTHER - RESIDENTIAL WOOD: 03-05
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(03) FUEL COMBUSTION -
OTHER
Tier n Category
(05) Residential Wood
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:
PM-10 Emissionsyear = PM-10 Emissions 19?5 x
TSP Emissions
year
TSP Emissions
(Eq. 3.12-1)
1975
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.
Wood ConsumptionflrepJt
laces fireplaces
0.5cord 4m3 „ 0.028317./?3 v 35/6 v Iton
m~
ft3
2,000 Ib
-------
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-150-83. Bureau of the Census, U.S.
Department of Commerce, Washington DC. Biennial.
(a) Table 2-4, Selected Equipment and Plumbing - Occupied Units
4. Estimates ofU.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 H category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(03) FUEL COMBUSTION-
OTHER
Tier n Category
(06) Residential Other
Tier n Subcategory
Anthracite Coal
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 we're 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.
PM-10 Emissions,,anr = PM-10 Emissions,975 x
TSP Emissions
year
year
TSP Emissions
(Eq. 3.13-1)
1975
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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.
Anthracite Coal
'R, i
= Anthracite CoaL . , x
K, I -1
Dwelling Units.
Dwelling Units f _1
(Eq. 3.13-2)
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 Units . x 6.73 tons burned/dwelling/year) - Anthracite Coal Ri (Eq 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.
Residential Sales
LPG, i
= Residential Sales
LPG, 1982
X
Products SuppliedLpG .
Products SuppliedLpG 1982
(Eq. 3.13-4)
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
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emission 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 n 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 n 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-lo'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-150-83. 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 H category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(04) CHEMICAL AND ALLIED
PRODUCT
MANUFACTURING
3.14.1 Technical Approach
Tier H Category
(01) Organic Chemical
Manufacturing
Tier n Subcategory
Petrochemicals excluding
storage and handling and waste
disposal
Charcoal (NOX and VOC)
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.
TTO D T? * "
PM-10 Emissionsvear = PM-10 Emissions.^ x missionsyea.r
y 1975 TSP Emissions
1975
(Eq. 3.14-1)
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
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dimethyl 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 n 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.
= l(UE-AE)]
[ UE \
(Eq. 3.14-2)
where: CE =
UE =
AE =
control efficiency
emissions before control
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 n 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 f or 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
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.
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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
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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.
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3.15
CHEMICAL AND ALLIED PRODUCT MANUFACTURING - INORGANIC
CHEMICAL MANUFACTURING: 04-02
The emissions for this Tier H category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(04) CHEMICAL AND ALLIED
PRODUCT
MANUFACTURING
3.15.1 Technical Approach
Tier n Category
(02) Inorganic Chemical
Manufacturing
Tier n Subcategory
Ammonia
Titanium Dioxide
Nitric Acid
Calcium Carbide
Sulfuric Acid
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, I960, 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.
n*s m r- • • T,,, *~ TSP Emissions
PM-10 Emissionsyear = PM-10 Emissions 1975 x . year
TSP Emissions
1975
(Eq. 3.15-1)
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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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 13 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 VOC Emissions
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).
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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 n 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.
EF -
1
(Eq. 3.15-2)
where: EF =
i —
p =
SO2 emission factor
year under study
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.
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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 n 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.
CE -
UE
(Eq. 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, US. 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-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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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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3.16 CHEMICAL AND ALLIED PRODUCTS MANUFACTURING - POLYMER AND
RESIN MANUFACTURING: 04-03
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(04) CHEMICAL AND ALLIED
PRODUCT
MANUFACTURING
3.16.1 Technical Approach
Tier n Category
(03) Polymer and Resin
Manufacturing
Tier n Subcategory
Plastics Manufacturing
excluding fabrication
Synthetics Fibers and Rubber
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.
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2.
3.
4.
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.
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.
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.
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
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 n category.
3.16.5 References
1. Chemical and Engineering News, Facts and Figure's 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
Procedures Document/or 1900-1996
3-83
1940-1984 Methodology
Category: 04-03
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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.
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3.17 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - AGRICULTURAL
CHEMICAL MANUFACTURING: 04-04
The emissions for this Tier H category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
Tier n Category
Tier n Subcateorv
(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.
PM-10 EmissionSyear = PM-10 Emissions^ x TSP Emissionsyear
TSP Emissions,
1975
(Eq. 3.17-1)
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.
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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 n 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.
CE =
\(UE-AE)}
[ UE \
(Eq. 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.
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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.
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Table 3.17-1. Ammonium Nitrate Emission Factor SCCs and Weighting Factors
SCO
Weighting Factor
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 Granuiators (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
sec
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
Description
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
Weighting Factor
1.0
0.45
0.07
0.005
0.07
0.005
0.045
0.045
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3.18 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - PAINT, VARNISH,
LACQUER, AND ENAMEL MANUFACTURING: 04-05
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
Tier n 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.
CE -
I UE
(Eq. 3.18-1)
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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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Procedures Document for 1900-1996
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1940-1984 Methodology
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3.19 CHEMICAL AND ALLIED PRODUCT MANUFACTURING - PHARMACEUTICAL
MANUFACTURING: 04-06
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(04) CHEMICAL AND ALLIED
PRODUCT
MANUFACTURING
Tier n Category
(06) Pharmaceutical
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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Procedures Document for 1900-1996
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Category: 04-06
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3.20 CHEMICAL AND ALLIED PRODUCTS MANUFACTURING - OTHER CHEMICAL
MANUFACTURING: 04-07
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
Tier n Category
(04) CHEMICAL AND ALLffiD (07) Other Chemical
PRODUCT Manufacturing
MANUFACTURING
Tier n Subcategory
Carbon Black
Soap and Detergents
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 Emissions = PM-10 Emissions 1975 x . .
year y TSP Emissions
year
(Eq. 3.20-1)
1975
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
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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 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.
Activity Indicatort = Production figure, x
Production index.
Production index
j
(Eq. 3.20-2)
where: i
j
= year under study
= 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 n 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.
EFS02, carbon black = (CECO, carbon black / °-913) X EFFlared Furnace Exhaust (Eq. 3.20-3)
where: EF = emission factor
CE = control efficiency, expressed as a fraction
3.20.3.4 VOC Emissions
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.
CE =
= \(UE-AE)]
UE I
(Eq. 3.20-4)
where: CE =
UE =
AE =
control efficiency
emissions before control
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.
+ ( EFnrij
, ,
charcoal
Briquettins
0-9 x 0.95)
(EF
kiln
EF
BnqueUinS * 0.9)
(Eq. 3.20-5)
where: CE =
EF =
control efficiency
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 SO2 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 VOC Emissions
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
i. 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 n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(05) METALS PROCESSING
Tier n Category
(01) Nonferrous
Tier n Subcategorv
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.
PM-10 Emissions^ = PM-10 Emissions
TSP Emissions
year
1975
year
TSP Emissions
(Eq. 3.21-1)
1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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3.21.2 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.
3.27.2.2.3 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 5a. 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.
Emissions
S02 , lead proc.
(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.
Production
lead proc.
Emissionso^lead proc x 2000lb/ton
540 Ib SOJtons lead proc.
(Eq. 3.21-3)
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
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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.
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 11 a. 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 lib. 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 forPM-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 lOf for TSP and from Reference 12
for PM-10. The emission factors were summed according to Equation 3.21-4.
EF = EFC + (2 x EFt
RF->
[(EF
EA
2]
(Eq. 3.21-4)
where: EF =
C =
RF =
EA =
El =
emission factor
cupola for scrap copper
reverberatory furnace for scrap copper
electric arc for scrap copper
electric induction
The TSP emission factor for fugitive processes was obtained from Reference lid. The PM-rlO
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
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the 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.
CE =
_ \(UE-AE)]
L UE J
(Eq. 3.21-5)
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 n 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
sec
Description
3-03-002-01
3-03-001-02
3-03-001-09
3-03-001-03
3-03-001-10
3-03-001-01
3-03-001-08
3-03-001-05
3-03-001-04
Calcining of Hydroxide
HSS - Stack
HSS - Fugitive
VSS - Stack
VSS - Fugitive
Prebake - Stack
Prebake - Fugitive
Anode Baking
Materials Handling
Table 3.21-2. PM-10 and SO2 Emission Factors SCCs and Weighting Factors for the
Primary Metals Industry - Copper Roaster
SCC
Description
1981
Capacity
3-03-005-02
3-03-005-09
Multiple Hearth Roaster
Fluidized Bed Roaster
430
230
Table 3.21-3. PM-10 Emission Factors SCCs and Weighting Factors for the Primary
Metals Industry - Copper Smelting
SCC
Description
1981
Capacity
3-03-005-07 Reverb. Furnace w/o Roasting
3-03-005-31 Reverb. Furnace + Multi-Hearth Reverb.
3-03-005-32 Furnace + Fluid Bed Roaster
3-03-005-10 Electric Smelting Furnace
636
430
212
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 IE category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(05) METALS PROCESSING
Tier n Category
(02) Ferrous
Tier n 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.
TSP Emissions
PM-10 Emissions = PM-10 Emissions ,„_. x :—.
year 1975 TSP Emissions
year
(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
5a 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
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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 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.
EF.
controlled
- FF x
E'r uncontrolled
(1 - 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 I960,1950, 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
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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
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 11 a.
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 Id. 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 11 a. 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 If. 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.
CE =
(UE-AE)}
UE \
(Eq. 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 n 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
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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 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 n 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 n 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 E category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(05) METALS PROCESSING
Tier n Category
(03) Metals Processing not
elsewhere classified
(NEC)
Tier n Subcategory
Mining Operations (iron ore
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.
PM-10 Emissions Vf nr = PM-10 Emissions
year
TSP Emissions
year
. .
TSP Emissions
(Eq. 3.23-1)
1975
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.
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The activity indicator for copper ore crushing was the gross weight of copper ore produced on a dry
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.
CE =
L UE J
(Eq. 3.23-2)
where: CE =
UE =
AE =
control efficiency
emissions before control
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.
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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.
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
3-03-023-02
3-03-023-04
3-03-023-07
3-03-023-08
3-03-023-09
3-03-023-10
3-03-023-12
3-03-023-16
Primary Crushing
Fines Crushing
Ore Transfer
Bentonite Storage
Bentonite Blending
Traveling Grate Feed
Traveling Grate Discharge
Indurating Furnace
Pellet Transfer
Table 3.23-2. PM-10 and JSP 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 n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
Tier n Category
Tier n 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 n 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
(06) PETROLEUM AND
RELATED INDUSTRIES
Tier H Category
Tier n Subcategorv
(02) Petroleum Refineries and FCC, TCC, and Flares
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 95 x .
year y/ TSP Emissions
year
(Eq. 3.25-1)
1975
This calculation was used in place of estimating emissions based on activity indicators, emission factors,
and control efficiencies.
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3.25.2 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
« T^C 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.
CE =
\(UE-AE)
L UE
(Eq. 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 n 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.
EF.
Controlled
_ (Capacityold x EFgld) + (Capacitynew x EFnew
)
(Capacityold + CapacityneJ
(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
Controlled
EF
Uncontrolled
(Eq. 3.25-4)
where: CE =
EF =
control efficiency
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. arid 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
Process Drains
Vacuum Jets
178.84
205.2
108.75
5.26
57.0
0.0
263
570
145
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3.26 PETROLEUM AND RELATED INDUSTRIES - ASPHALT MANUFACTURING:
06-03
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(06) PETROLEUM AND
RELATED INDUSTRIES
Tier n Category
Tier n Subcategory
(03) Asphalt Manufacturing Batching - dryers and fugitives
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.
PM-10 Emissions,,^, = PM-10 Emissions.„- x
TSP Emissions
year
year
1975
TSP Emissions
(Eq. 3.26-1)
1975
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
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asphalt 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 dram 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 31 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 dram 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 dram and rotary dryer emission
factors.
CE =
UE
(Eq. 3.26-2)
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where: CE = control efficiency
UE = uncontrolled emissions
AE = controlled emissions
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
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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. 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 n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(07) OTHER INDUSTRIAL
PROCESSES
Tier n Category
(01) Agriculture, Food, and
Kindred Products
Tier n Subcategorv
Cotton ginning, cattle feedlots,
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 Emissionsvfar = PM-10 Emissions 1975 x . .
year 1975 TSP Emissions
year
(Eq. 3.27-1)
1975
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-10 and 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.
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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
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-10 and TSP Emissions
The emission factors for cotton ginning were the sum of the emission factors for the following four
processes: unloading 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.
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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 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 n 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
3.27.47 PM-10 and 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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CE -
UE
(Eq. 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. GPO 20-B-S/NOO1/028/80029/1. 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
Corn
Oats
Barley
Sorghum
60
56
32
48
56
Table 3.27-2. PM-10 and TSP Emission Factor SCCs for Country Elevators
SCC
Description
3-02-006-03
3-02-006-04
3-02-006-05
3-02-006-06
3-02-006-09
3-02-006-10
Cleaning
Drying
Unloading (receiving)
Loading (shipping)
Removal from bins
Headhouse (legs)
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Table 3.27-3. PM-10 and TSP Emission Factor SCCs for Terminal Elevators
see
Description
3-02-005-03
3-02-005-04
3-02-005-05
3-02-005-06
3-02-005-09
3-02-005-10
3-02-005-11
Cleaning
Drying
Unloading (receiving)
Loading (shipping)
Tripper (gallery belt)
Removal from bins
Headhouse (legs)
Table 3.27-4. PM-10 and TSP Emission Factor SCCs for Feed Mills
sec
Description
3-02-008-02
3-02-008-03
3-02-008-04
3-02-008-05
3-02-008-06
Receiving
Shipping
Handling
Grinding
Pellet Coolers
Table 3.27-5. PM-10 and TSP Emission Factor SCCs for Soybean Milling
SCC
Description
3-02-007-81
3-02-007-82
3-02-007-84
3-02-007-85
3-02-007-86
3-02-007-87
3-02-007-88
3-02-007-89
3-02-007-90
3-02-007-91
Receiving
Handling
Drying
Cracking/Dehulling
Hull Grinding
Bean Conditioning
Flaking
Meal Dryer
Meal Cooler
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 n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(07) OTHER INDUSTRIAL
PROCESSES
Tier n Category
(03) Wood, Pulp and Paper,
and Publishing Products
Tier n Subcategory
Pulp and Paper - kraft and sulfite
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.
n** irv T- • • r> TSP Emissions
PM-IQ Emissions• = PM-10 Emissions 1975 x
TSP Emissions
year
1975
(Eq. 3.28-1)
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
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production and sulfite was the combined production of sulfate and sulfite at kraft mills and sulfite mills
obtained from Reference 1.
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 X
plywood,i plywood,]
p
(p'me * •
(pine + fir),j
(Eq. 3.28-2)
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.
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The TSP emission factors for the two semi-chemical processes of recovery furnaces and fluid red
reactors were obtained from Reference 11. The PM-10 emission factor was obtained from Reference 8
or Table 3.1 -3 of this report.
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 paniculate 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 n 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.
CE =
UE
(Eq. 3.28-3)
where: CE =
UE =
AE =
control efficiency
uncontrolled emissions
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.
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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.
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 Syears)
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.
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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.
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 n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(07) OTHER INDUSTRIAL
PROCESSES
3.29.1 Technical Approach
Tier n Category
Tier n Subcategory
(04) Rubber and Miscellaneous Tires
Plastic Products
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
3-08-001-02
3-08-001-03
3-08-001-04
3-08-001-05
3-08-001-06
3-08-001-07
Undertread & Sidewall Cementing
Bead Dipping
Bead Swabbing
Tire Building
Tread End Cementing
Green Tire Spraying
Tire Curing
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3.30 OTHER INDUSTRIAL PROCESSES - MINERAL PRODUCTS: 07-05
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(07) OTHER INDUSTRIAL
PROCESSES
Tier n Category
(05) Mineral Products
Tier n 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 Emissions,., = PM-10 Emissions^ x
TSP Emissions
year
(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 NOr Emissions
The activity indicator for cement manufacturing was the total quantity of cement production
obtained from Reference 3.
as
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 3a. 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.
EF = 2.85 x
CE
TSP
0.956
I
0.22 x | 1 -
TSP
0.956
(Eq. 3.30-2)
where: CH^p = 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 21a. 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 n 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 21d, 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 n 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 n 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:
EFC
j, controlled
2, uncontrolled
cement
O2, kilns'
(Eq. 3.30-3)
where: EF =
E =
P =
CE =
emission factor
emissions
production
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* SO* 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 n category.
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330.4.2 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.
L HE
•
(Eq. 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.
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1940-1984 Methodology
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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/lQ). 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
Procedures Document for 1900-1996
3-166
1940-1984 Methodology
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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
sec
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
sec
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
Glass Furnace
Glass Furnace
Glass Furnace
Glass Furnace
Glass Furnace
Glass Furnace
Wool-
Wool-
Wool-
Wool-
Textile
Textile
Textile
Regenerative
Recuperative
Electric
Unit Melter
- Regenerative
- Recuperative
- Unit Melter
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Table 3.30-5. PM-10 and TSP Emission Factor SCCs
for Stone and Rock Crushing
SCO
Description
3-05-020-01
3-05-020-02
3-05-020-03
3-05-020-04
3-01-020-06
Primary Crushing
Secondary Crushing
Tertiary Crushing
Recrushing/Screening
Miscellaneous Operations
Table 3.30-6. Uncontrolled SO2 Emissions Factors for Cement Manufacturing
Fuel
Emission Factor
Mineral Source
Coal
Residual Oil
Distillate Oil
10.2 Ib/ton cement produced
30.45 Ib/ton coal consumed
124.5 lb/1,000 gal residual oil consumed
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 H category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(08) SOLVENT UTILIZATION
Tier H Category
(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 = ^ (si x
/=i
(Eq. 3.31-1)
where: Ss = total production/sales of solvent
Uj = fraction of Ss for end use as degreasing solvent (the "weighting factor" of Table 3.31-
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.
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3.31.5 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.
Table 3.31-1. Solvents and Weighting Factors for
Degreasing
Solvent
Special Naphtha
Perchioroethylene
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 H category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(08) SOLVENT UTILIZATION
Tier H Category
(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 = £ (St x Ut)
/ = !
(Eq. 3.32-1)
where: Ss = total production/sales of solvent
Uj = 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. US1TC 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
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3.33 SOLVENT UTILIZATION - DRY CLEANING: 08-03
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(08) SOLVENT UTILIZATION
Tier n Category
(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.
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Table 3.33-1. Solvents and Weighting Factors for Dry Cleaning
Solvent
Weighting
Factor i
Consumption
References
Special Naphtha
Perchloroethylene (93.4%)
2.0
58.9
1
2
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1940-1984 Methodology
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3.34 SOLVENT UTILIZATION - SURFACE COATINGS: 08-04
The emissions for this Tier H category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category Tier IT Category
(08) SOLVENT UTILIZATION (04) Surface Coatings
Tier n Subcategory
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 E 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 MffiK 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
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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.
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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/barrel 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 n 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 n category.
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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.
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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
Butyi 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
Reference 4 Category
Solvent
Content
(Ib/gal)
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
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
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 bv 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 Glycoi 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 E category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(08) SOLVENT UTILIZATION
Tier n Category
(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.
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Procedures Document for 1900-1996
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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 n 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
Weighting Factor
Solvent (%) Consumption References
Special Naphtha
Acetone (89.0%)
O-Dichloro-benzene
Ethanol
Ethylbenzene
Ethylene Ethyl (EE) Glycol Ether
Ethylene Butyl (EB) Glycol Ether
Methanol (95.3%)
1
0.5
25
5.8
0.075
12
12
4.7
1
2 or 3
2 or 3
2
2
3
3
2
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Procedures Document for 1900-1996
3-185
1940-1984 Methodology
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Table 3.35-2. Determination of Activity Indicator for Solvent
Extraction Processes: Solvents, Weighting Factors, and References
Solvent
Methyl Ethyl Ketone (MEK)
Methyl Isobutyl Ketone (MIBK)
Weighting
Factor (%)
12.5
8.9
Consumption References
2
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 (%) Consumption References
6.5
12
0.25
1
3
2
Table 3.35-4. VOC Emission Factor SCCs for Waste Solvent
Recovery Processes
SCC
Description
4-90-002-01
4-90-002-02
4-90-002-03
4-90-002-04
4-90-002-05
Storage Tank Vent
Condenser Vent
Incinerator Stack
Solvent Spillage
Solvent Loading
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Procedures Document for 1900-1996
3-186
1940-1984 Methodology
Category: 08-05
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3.36 SOLVENT UTILIZATION - NONINDUSTRIAL: 08-06
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(08) SOLVENT UTILIZATION
Tier n Category
(06) Nonindustrial
Tier n Subcategorv
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 n 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.
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Procedures Document for 1900-1996
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1940-1984 Methodology
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3.36.3 Emission Factor
For all sources included in this Tier n 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 n 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
Procedures Document for J900-1996
3-188
1940-1984 Methodology
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 H category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(09) STORAGE AND
TRANSPORT
Tier n Category
(01) Bulk Terminals and Plants
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
n 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-190
1940-1984 Methodology
Category: 09-01
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to 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
Procedures Document for 1900-1996
3-191
1940-1984 Methodology
Category: 09-01
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3.38 STORAGE AND TRANSPORT - PETROLEUM AND PETROLEUM PRODUCT
STORAGE: 09-02
The emissions for this Tier E category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(09) STORAGE AND
TRANSPORT
Tier n Category
Tier n Subcategory
(02) Petroleum and Petroleum Gasoline Storage at Refineries
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, I960, 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
Procedures Document for 1900-1996
3-192
1940-1984 Methodology
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 H 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
Procedures Document for 1900-1996
3-193
1940-1984 Methodology
Category: 09-02
-------
3.39 STORAGE AND TRANSPORT - PETROLEUM AND PETROLEUM PRODUCT
TRANSPORT: 09-03
The emissions for this Tier H category were determined by the 1940-1984 Methodology for the
following source category.
Tier T Category
(09) STORAGE AND
TRANSPORT
Tier n Category
Tier n Subcategory
(03) Petroleum and Petroleum Refinery Product Loading -
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 ffl to PAD I, from PAD H to
PAD II, from PAD ffl to PAD V, and from PAD V to PAD m. 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.
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Procedures Document for 1900-1996
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1940-1984 Methodology
Category: 09-03
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3.39.3 Emission Factor
The emission factors for all sources included in this Tier H 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 n 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.
2.
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."
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
Procedures Document for 1900-1996
3-195
1940-1984 Methodology
Category: 09-03
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3.40 STORAGE AND TRANSPORT - SERVICE STATIONS: STAGE I: 09-04
The emissions for this Tier H category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(09) STORAGE AND
TRANSPORT
3.40.1 Technical Approach
Tier n Category
(04) Service Stations:
Stage I
Tier n Subcategory
Gasoline Service Stations -
loading or stage I
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
Procedures Document for 1900-1996
3-196
1940-1984 Methodology
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
Procedures Document for 1900-1996
3-197
1940-1984 Methodology
Category: 09-04
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3.41 STORAGE AND TRANSPORT - SERVICE STATIONS: STAGE II: 09-05
The emissions for this Tier H category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(09) STORAGE AND
TRANSPORT
3.41.1 Technical Approach
Tier n Category
(05) Service Stations:
Stage E
Tier n Subcategorv
Gasoline Service Stations -
loading or stage n
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 n 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
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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
Procedures Document for 1900-1996
3-199
1940-1984 Methodology
Category: 09-05
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3.42 STORAGE AND TRANSPORT - ORGANIC CHEMICAL STORAGE: 09-07
The emissions for this Tier H category were determined by the 1940-1984 Methodology for the
following source category.
Tier n Category
Tier n Subcategorv
(07) Organic Chemical Storage Waste Solvent Recovery
Waste Disposal
Tier I Category
(09) STORAGE AND
TRANSPORT
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 n 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
Procedures Document for 1900-1996
3-200
1940-1984 Methodology
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
SCO
Description
4-90-002-01
4-90-002-02
4-90-002-03
4-90-002-04
4-90-002-04
Storage Tank Vent
Condenser Vent
Incinerator Stack
Solvent Spillage
Solvent Loading
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
3-201
1940-1984 Methodology
Category: 09-07
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3.43 WASTE DISPOSAL AND RECYCLING - INCINERATION: 10-01
The emissions for this Tier E category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(10) WASTE DISPOSAL AND
RECYCLING
Tier n Category
(01) Incineration
Tier n Subcategorv
Municipal
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.
PM-10 Emissions^ = PM-10 Emissions
TSP Emissions
year
year
1975
TSP Emissions
(Eq. 3.43-1)
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.
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1940-1984 Methodology
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.
AI. = A/._, x
ORt
~OR~l
(Eq. 3.43-2)
where: i =
AI =
OR =
year
activity indicator
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.
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Category: 10-01
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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.
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.
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Category: 10-01
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3.44 WASTE DISPOSAL AND RECYCLING - OPEN BURNING: 10-02
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
(10) WASTE DISPOSAL AND
RECYCLING
3.44.1 Technical Approach
Tier II Category
(02) Open Burning
Tier n Subcategory
Dumps
On-site
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:
PM-10 Emissionsvpnr = PM-10 Emissions 10_. x missionsyear
y 1975 TSP Emissions,
(Eq. 3.44-1)
1975
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.
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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.
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1940-1984 Methodology
Category: 10-02
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3.45 WASTE DISPOSAL AND RECYCLING - OTHER: 10-07
The emissions for this Tier E category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
Tier n Category
(10) WASTE DISPOSAL AND (07) Other
RECYCLING
3.45.1 Technical Approach
Tier n Subcategorv
Waste Disposal of
Petrochemicals
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.
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Procedures Document for 1900-1996
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1940-1984 Methodology
Category: 10-07
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3.46 ON-ROAD VEHICLES: 11
The emissions for all Tier H categories under this Tier I category were determined by the 1940-1984
Methodology for the following source category:
Tier I Category
(11) ON-ROAD VEHICLES
Tier n Category
(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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Category: 11
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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:
LDDVsurviving = {passenger car survival] \ LDDVoriginal 1
bymodelyear [ rate by age J [sales by modelyear \
(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 = RS
Qto6K
I- DFS
0to6K
(Eq. 3.46-2)
SaleSLDGT2=RS6toWK-VCC-M-0.05xCP-DFS6toWK-DTWtol4K
(Eq. 3.46-3)
SalesHDGT= VCC +M + 0.05xCP -HDDT + RS.
>WK
(Eq. 3.46-4)
0.1xDFS
6tom
(Eq. 3.46-5)
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Category: 11
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+ DFSl6tol9.5k+DFSl9.5,o26k
+DFS
+DFS,
(Eq. 3.46-6)
where: RS
I
DPS
VCC
M
CP
HDDT
retail sales of domestic trucks
retail sales of import trucks
factory sales of diesel trucks
retail sales of van cutaway chassis
retail sales of multistops
retail sales of conventional pickups
sales HDDT, also calculated above.
Step 3.
This next step converted the original sales of trucks into the number of tracks actually operating.
For each of the past 20 years, the ratio of the total number of trucks operating to the total number of sales
was calculated using the table entitled "Tracks in Operation by Model Year" from Reference 2. The
number of tracks in each category operating by model year was then calculated by multiplying the ratio
for the given year by the estimated retail sales for the year of interest. Equation 3.46-7 was used.
LDGTl=RSiLDGT1x
TTi
~TRS;
(Eq. 3.46-7)
where: LDGT1 = number of tracks in this category
= retail sales for year i and track type xxx
= total number of tracks operating for year i from Reference 2
= total retail sales of tracks for year i.
The same procedure was repeated for each vehicle classification.
Note: The MVMA report, Reference 2, may only give operating and sales statistics for the past 16
years. Yet, this must be completed for the past 20 years. This can be done by estimating the number of
trucks in operation for the i-16th through i-19th years as shown in Equation 3.46-8.
Modelyri-16
trucks in operation =•
in calendary ear i
1-
Modelyri-15
Modelyri-14 trucks in operation
trucks in operation Modelyri-14
trucks in operation,
x
Modelyri-15
trucks in operation
(E(l- 3
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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.
VMTLHDDx avg[DFSLHDD]
HDDT =
0.9xavg[DFSHDD_]
(Eq. 3.46-9)
+ avg[DFSMHDD] + avg[DFSHHDD]
where: VMT
avg (DPS)
vehicle miles traveled
"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 3.46-11.
OtherFreeways + Other Principal Arterial
77^ 77T
Other Urban
(Eq. 3.46-10)
OU.
19.6MPH
Minor Arterial + Collector + Local
Other Urban
(Eq. 3.46-11)
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
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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.
raction55MPH, = Interstate Rural. + OtherRural.t + lnterstateUrbani + OU55MPH x OtherUrba(Eq. 3.46-12)
Fraction
Other Rural.
•45MPH,i Total Rural and Urban,
(Eq. 3.46-13)
Fraction
19.6 MPH
OU196MPH x Other Urbant
Total Rural and Urban.
(Eq. 3.46-14)
where: i
OU
55MpH
= vehicle type (personal passenger vehicles, 2-axle 4-tire single unit trucks,
combination trucks)
= value calculated in Equation 3.46-10
= 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 A 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.
National Air Pollutant Emission Trends
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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
VMT (billion miles per year)
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
Limited
Access
Roads
147.0
17.1
4.3
16.8
0.6
0.0
0.0
1.6
187.4
3.46-3. 1960
Urban
Roads
127.2
11.9
2.9
9.5
0.6
0.0
0.0
0.6
152.7
VMT by Road
VMT (billion miles
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
Limited
Access
Roads
256.8
24.5
6.1
21.7
1.0
0.0
0.0
7.9
318.0
Urban
Roads
184.5
15.0
3.8
9.0
0.6
0.0
0.0
2.7
215.6
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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1940-1984 Methodology
Category: 11
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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
Vehicle Type
PM-10
(Ib/thousand VMT)
1940 1950 1960
TSP
(Ib/thousand VMT)
1940 1950 1960
SO2
(Ib/thousand VMT)
1940 1950 1960
Gasoline
Passenger Cars
Light duty Trucks 1
Light duty Trucks 2
Heavy duty Trucks
Motorcycles
Diesel
Passenger Cars
Light Trucks
Heavy duty Trucks
1.28
1.3
1.37
2.88
0
NA
NA
NA
1.21
1.24
1.27
2.69
0
NA
NA
6.51
1.42
1.46
1.35
3.15
0.77
NA
NA
2.39
1.36
1.38
1.53
2.88
0
NA
NA
NA
1.28
1.32
1.41
2.69
0
NA
NA
6.51
1.5
1.54
1.51
3.15
0.77
NA
NA
2.30
NA
NA
NA
0.1
NA
NA
NA
NA
NA
NA
NA
0.81
NA
NA
NA
NA
NA
NA
NA
0.54
NA
NA
NA
NA
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1940-1984 Methodology
Category: 11
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3.47 NON-ROAD ENGINES AND VEHICLES - NON-ROAD GASOLINE ENGINES: 12-01
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
Tier n Category
(12) NON-ROAD ENGINES AND (01) Non-road Gasoline
VEHICLES Engines
Tier IE Subcategory
Farm Tractors
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.
PM-10 Emissions = PM-10 Emissions
year
TSP Emissions
x
year
t
TSP Emissions
(Eq. 3.47-1)
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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Category: 12-01
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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.
GC
, 1973
X
Agriculture, i
Agriculture, 1973
(Eq. 3.47-2)
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.
GC
Snowmobiles, i
, = GC
R
Snowmobiles, i
Snowmobiles, 1973
R
(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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1940-1984 Methodology
Category: 12-01
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GC
, , \
. = 533 x 106 gal) x
' ' V '
Single Unit Dwellings.
- - - ^~
Single Unit Dwellingsl9SO
(Eq. 3.47-4)
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.
GC
Motorcycles
= Number of Motorcycles x
Off-Highway Mileage
MPG
(Eq. 3.47-5)
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 90-6021D 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 90-6021D 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 90-602ID from Reference 9.
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1940-1984 Methodology
Category: 12-01
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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 11. 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.
EF =
2-55) + (EFout x RoM x 1.55)]
[(*-„ x 2.55) + (R . x 1.55)]
(Eq. 3.47-6)
where: EF
R
in
out
emission factor
number of registrations
inboards
outboards
The VOC emission factor was multiplied by the reactive VOC fraction of 0.9172. This fraction was
based on data for profile 9-60-2IB 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 n 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 n, Table 2-20, Appendix L
b. Volume E, Table E-6-2
d. Volume H, Table E-8-1
e. Volume E, Table E-5-1
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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1940-1984 Methodology
Category: 12-01
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f. Volume I, Table 3.3-1
g. Volume H, Table H-3.5
h. Volume E, Table E-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
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Category: 12-01
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Table 3.47-1. Emission Factor Equipment Types and
Weighting Factors for Gasoline Construction Equipment
Equipment Type
Weighting Factor, based on
consumption in 1,000 gal/year
Wheel Tractor
Motor Grader
Wheel Loader
Roller
94,774
12,240
104,726
147,439
Table 3.47-2. Emission Factor Equipment Types and
Weighting Factors for Gasoline Small Utility Gasoline
Engines
Engine Type
Weighting Factor, based on
percentage consumption
Wheel Tractor (2-stroke)
Motor Grader (4-stroke)
0.065
0.935
Table 3.47-3. MOBILE 2 (1978 version) Parameters for Calculation of
Emission Factors for Motorcycles
Altitude
Speed
Ambient Temp.
Hot Start/Cold Start Percentages
All other variables
Low
19.6MPH
57°F
Zero
default values
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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 n category were determined by the 1940-1984
Methodology for the following source categories.
Tier I Category
Tier n Category
Tier n 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.
PM-10 Emissions,
year
PM-10 Emissions ,„_,. x
TSP Emissions
year
1975 Tsp Emissions
(Eq. 3.48-1)
1975
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 3a or 4a. It was
National Air Pollutant Emission Trends
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1940-1984 Methodology
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 n 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 E, Table 2-2, Appendix L,
b. Volume E, Table E-6-2
c. Volume E, Table E-7-1
d. Volume E, 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
Procedures Document for 1900-1996
3-225
1940-1984 Methodology
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
Equipment Type
Weighting Factor, based on
consumption in 1,000 gal/year
Tracklaying Tractor
Wheel Tractor
Wheeled Dozer
Scraper
Motor Grader
Wheeled Loader
Tracklaying Loader
Off-Highway Truck
Roller
912,279
846,035
47,077
621,523
164,368
753,511
229,680
470,550
30,180
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3.49 NON-ROAD ENGINES AND VEHICLES - AIRCRAFT: 12-03
The emissions for this Tier E category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
Tier n Category
(12) NON-ROAD ENGINES AND (03) Aircraft
VEHICLES
3.49.1 Technical Approach
Tier n Subcategory
FAA Facilities
Military Facilities
General Aviation
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 Emissions = PM-10 Emissions.„, x
y 1975 TSP Emissions
year
1975
(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 thi
number of LTO cycles.
i the
The activity indicator for general aviation aircraft using military facilities was assumed to be a
constant 1200 LTOs.
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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.
MLTO
MF<
MLTOMF< M) x
FH.
- MLTO
FAA,
(Eq. 3.49-2)
where: MLTO
MF
FAA
FH
i
military LTO
military facilities
FAA facilities
total flying hours
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.
GAnr = (AC x 250 cycles/year) - GAFAA - GA
(Eq. 3.49-3)
where: GA
AC
OF
FAA
MF
General Aviation LTOs
Number of U.S. registered civil aircraft, excluding gliders, blimps, and balloons
Other Facilities
FAA Facilities
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.
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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 n category.
3.49.4 Control Efficiency
No control efficiencies were applied to the activity data to estimate emissions from aircraft.
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3.49.5 References
1. FAA Air Traffic Activity FY19xx. 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, ME.
September 1985.
Table 3.49-1. Emission Factors for Commercial Aircraft using FAA Facilities
Commercial Aircraft
BAG 111
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
NOV
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).
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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**
NOV
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),
"Paniculate 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
NOV
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).
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3.50 NON-ROAD ENGINES AND VEHICLES - MARINE VESSELS: 12-04
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
Tier H Category
(12) NON-ROAD ENGINES AND (04) Marine Vessels
VEHICLES
Tier n Subcategory
Residual Fuel Oil
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 Emissions = PM-10 Emissions 1975 x . .
year TSP Emissions
year
(Eq. 3.50-1)
1975
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.
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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 3a. 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.
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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 n 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. Table A13 and A14
2. Fuel Oil and Kerosene Sales 19xx. DOE/EIA-0535(xx). Energy Information Administration, U.S.
Department of Energy, Washington, DC. Annual.
a. Table A13 and A14
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 E, Table E-3-2
b. Volume E, Table E-3-4
c. Volume E, Table 3.3-1
d. Volume H, Table H-3-1
e. Volume E, Table E-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.
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3.51 NON-ROAD ENGINES AND VEHICLES - RAILROADS: 12-05
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source category.
Tier I Category
Tier n Category
(12) NON-ROAD ENGINES AND (05) Railroads
VEHICLES
3.51.1 Technical Approach
Tier n Subcategory
Diesel
Residual Fuel Oil
Coal
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.
PM-10 Emissions^ = PM-10 Emissions^ x TSP Emissions^
y 1975 TSP Emissions^
(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
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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 W4.
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 n 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 H, Table H-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)
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3.52 MISCELLANEOUS - OTHER COMBUSTION: 14-02
The emissions for this Tier n category were determined by the 1940-1984 Methodology for the
following source categories.
Tier I Category
(14) MISCELLANEOUS
Tier IE Category
(02) Other Combustion
Tier n Subcategory
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 19?5 x
TSP Emissions
year
1975
(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.
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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.
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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 n 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 n 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
Procedures Document for 1900-1996
3-239
1940-1984 Methodology
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 J900-J996
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, 1900-1996' (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 Particulate Programs Implementation Evaluation System.3 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 (EHG).
Emissions and associated data for these two pollutants are available for the years 1990 through 1996.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-1
1985-1996 Methodology
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 n 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 E, respectively, are the same for
each of the six criteria pollutants and are listed in Table 4.1-2. The third level, Tier m, 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 H 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
Procedures Document for 1900-1996
4-2
1985-1996 Methodology
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 II
4.1 Introduction
4.2 Fuel Combustion - Electric
Utility
4.3 Industrial
4.4 Other Combustion
Fuel Combustion - Electric Utility
(01)
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)
Miscellaneous (14)
Other Combustion (03)
Miscellaneous (14)
Majority of Coal (01), Oil (02), and
Gas (03). The point level - steam
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
JJf^lttlsflYices (05)
All
_Other combustion (02)
._!-JLP_n.Lr.°.?.t' Vehicles
_4-7_Non-road Sources
4.8 Fugitive Dust
_AN_
All
_Non-road_Sources (12)
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!
Tier II
01 FUEL COMBUSTION-ELECTRIC UTILITIES
01
02
03
04
05
02 FUEL COMBUSTION-INDUSTRIAL
01
02
03
04
05
03 FUEL COMBUSTION-OTHER
01
02
03
04
05
06
04 CHEMICAL & ALLIED PRODUCT MFG.
01
02
03
04 .
05
06
07
05 METALS PROCESSING
01
02
03
06 PETROLEUM & RELATED INDUSTRIES
01
02
03
07 OTHER INDUSTRIAL PROCESSES
01
02
03
04
05
06
07
08
09
10
08 SOLVENT UTILIZATION
01
02
03
04
05
06
07
Coal
Oil
Gas
Other
Internal Combustion
Coal
Oil
Gas
Other
Internal Combustion
Commercial / Institutional Coal
Commercial / Institutional Oil
Commercial / Institutional Gas
Misc. Fuel Combustion (except residential)
Residential Wood
Residential Other
Organic Chemical Mfg.
Inorganic Chemical Mfg.
Polymer & Resin Mfg.
Agricultural Chemical Mfg.
Paint, Varnish, Lacquer, Enamel Mfg.
Pharmaceutical Mfg.
Other Chemical Mfg.
Nonferrous
Ferrous
Not elsewhere classified (NEC)
Oil & Gas Production
Petroleum Refineries & Related Industries
Asphalt Manufacturing
Agriculture, Food, & Kindred Products
Textiles, Leather, & Apparel Products
Wood, Pulp & Paper, & Publishing Products
Rubber & Miscellaneous Plastic Products
Mineral Products
Machinery Products
Electronic Equipment
Transportation Equipment
Construction
Miscellaneous Industrial Processes
Degreasing
Graphic Arts
Dry Cleaning
Surface Coating
Other Industrial
Nonindustrial
Solvent Utilization NEC
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
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 11:01 Coal
10100101 • 10100306
2101001000 - 2101003000
Tier II: 02 Oil
10100401 - 10100505
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
2010010] - 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 A11I.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
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-6
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30590002
30590011
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
Mineral Products Fuel Fired Equipment Residual Oil: Process Heaters
Mineral Products Fuel Fired Equipment Distillate Oil (No. 2): Incinerators
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 Bru 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-7
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30390024
30490003
30490004
30490013
30490014
30490023
30490024
30490033
30490034
30490035
30500206
30590003
30590013
30590023
30600102
30600104
30600103
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
Tierll: 04 Other
10200S01
10500110
2102007000
2390007000
30290005
30500209
30600107
30600199
30600905
30600999
30609905
30890004
- 10201302
- 10500114
- 2102009000
- 2390009000
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
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 Hares 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-8
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
39000801 -39001399 In-Process Fuel Use to-Process Fuel Use
40201004 Surface Coating Operations Coating Oven Heater Liquified Petroleum Gas (LPG)
50390010 Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Liquified Petroleum
Tier II: 05 Internal Combustion
20180001
20200101
2102006002
27501001
27501014
27501015
27502001
27502011
27505001
27505011
27601014
27601015
28000211
28000212
28000213
28000216
28000217
28000218
Electric Generation Equipment Leaks Equipment Leaks
- 20201002 Internal Combustion Engines Industrial
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 - 10300309 External Combustion Boilers Commercial/Institutional
10500202 Space Heaters Commercial/Institutional Coal **
2103001000 Stationary Source Fuel Combustion Commercial/Institutional Anthracite Coa
2103002000 Stationary Source Fuel Combustion Commercial/Institutional Bituminous/Sub
2199001000 - 2199003000 Stationary Source Fuel Combustion Total Area Source Fuel Combustion
Tier II: 02 Commercial/Institutional Oil
10300401
10500205
20300101
20300102
20300107
2103004000
2103005000
2199004000
50190005
50290005
- 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
Tier II: 03 Commercial/Institutional Gas
10300601
10500206
20300201
2103006000
2199006000
27300320
50190006
50290006
- 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
10500209
20190099
20301001
2103007000
2199007000
2199009000
28888801
50190010
50290010
10301303 External Combustion Boilers Commercial/Institutional
10500214 External Combustion Boilers Space Heaters Commercial-Institutional
Electric Generation Flares Heavy Water
20400402 Internal Combustion Engines
2103011010 Stationary Source Fuel Combustion Commercial/Institutional
Stationary Source Fuel Combustion Total Area Source Fuel Combustion Liqui
2199011000 Stationary Source Fuel Combustion Total Area Source Fuel Combustion
28888803 Internal Combustion Engines Fugitive Emissions Other Not ClassifiedSpecify in Co
Solid Waste Disposal - Government Auxiliary Fuel/No Emissions Liquified Petroleum
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 MFG
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
30121030 - 30130107 Chemical Manufacturing Chemical Manufacturing
30130110 - 30181001 Chemical Manufacturing Chemical Manufacturing
30184001 Chemical Manufacturing General Processes Distillation Units
2301010000
2301010010
30100801
30100802
30100805
30100S99
30101101
30101199
30101206
30101299
30102101
30102322
30102399
30103201
30103501
30103599
30107001
30111201
Tier II: 03
2301020000
30101801
30101809
30101812
30101817
30101822
30101842
30101870
30101885
30101899
30102401
30102426
30102499
30102613
64520011
" — ~
-------
Table 4.1-3 (continued)
64630001 Vinyl-based Resins Polyvinyl Chloride and Copolymers Production - Suspension Proce
64630052 Vinyl-based Resins Polyvinyl Chloride and Copolymers Production - Suspension Proce
64920030 Fibers Production Processes Rayon Fiber Production Fiber Finishing
Tier II: 04 Agricultural Chemicals
30100305
30101301
30101601
30101603
30102701
30102710
30102806
30102822
30102906
30102922
30103004
30103301
30104001
30104008
30104501
30113004
30113005
30100399
30101399
30101799
30102708
30102801
30102820
30102825
30102920
30103002
30103099
30103399
30104006
30104013
Tier II: 05 Paints, Varnishs, Lacquers, Enamels
Chemical Manufacturing Chemical Manufacturing Ammonia Production
Chemical Manufacturing Chemical Manufacturing Nitric Acid
Chemical Manufacturing Phosphoric Acid: Wet Process Reactor
Chemical Manufacturing Chemical Manufacturing
Chemical Manufacturing Chemical Manufacturing Ammonium Nitrate Production
Chemical Manufacturing Chemical Manufacturing
Chemical Manufacturing Chemical Manufacturing Normal Superphosphate
Chemical Manufacturing Chemical Manufacturing Normal Superphosphate
Chemical Manufacturing Chemical Manufacturing Triple Superphosphate
Chemical Manufacturing Chemical Manufacturing
Chemical Manufacturing Chemical Manufacturing Ammonium Phosphates
Chemical Manufacturing Chemical Manufacturing Pesticides
Chemical Manufacturing Chemical Manufacturing Urea Production
Chemical Manufacturing Chemical Manufacturing Urea Production
Chemical Manufacturing Organic Fertilizer General: Mixing/Handling
Chemical Manufacturing Ammonium Snlfate (Use 3-01-210 for Caprolactum Production).
Chemical Manufacturing Ammonium Sulfate (Use 3-01-210 for Caprolactum Production)
30101401
30101415
30101430
30101450
30101451
30101470
30101498
30101499
Tier II:
2301030000
30106001
30106011
Tier II:
30100501
30100509
30100599
30100701
30100901
30101021
30101022
30101099
30102001
30104101
30105001
30111103
30111199
30188801
30196099
30199998
30199999
- 30101403 Chemical Manufacturing Chemical Manufacturing Paint Manufacture
Chemical Manufacturing Paint Manufacture Premix/Preassembly
Chemical Manufacturing Paint Manufacture Pigment Grinding/Milling
Chemical Manufacturing Paint Manufacture Product Finishing
Chemical Manufacturing Paint Manufacture Product Finishing, Tinting: Mix Tank and
Chemical Manufacturing Paint Manufacture Equipment Cleaning
Chemical Manufacturing Paint Manufacture Other Not Classified
- 30101599 Chemical Manufacturing Chemical Manufacturing
06 Pharmaceuticals
Industrial Processes Chemical Manufacturing: SIC 28
- 30106009 Chemical Manufacturing Chemical Manufacturing Pharmaceutical Preparations
- 30106099 Chemical Manufacturing Chemical Manufacturing Pharmaceutical Preparations
07 Other Chemicals
- 30100507
30100799
30101014
30102099
30104199
30188805
Chemical Manufacturing Chemical Manufacturing Carbon Black Production
Chemical Manufacturing Carbon Black Production Furnace Process: Fugitive Emissions
Chemical Manufacturing Carbon Black Production Other Not Classified
Chemical Manufacturing Chemical Manufacturing
Chemical Manufacturing
Chemical Manufacturing Explosives (Trinitrotoluene) Continuous Process: Nitration
Chemical Manufacturing Explosives (Trinitrotoluene) Continuous Process: Nitration
Chemical Manufacturing Explosives (Trinitrotoluene) Other Not Classified
Chemical Manufacturing Chemical Manufacturing Printing Ink Manufacture
Chemical Manufacturing Chemical Manufacturing Nitrocellulose
Chemical Manufacturing Adhesives General/Compound Unknown **
Chemical Manufacturing Asbestos Chemical Brake Line/Grinding **
Chemical Manufacturing Asbestos Chemical Not Classified **
Chemical Manufacturing Chemical Manufacturing Fugitive Emissions Specify inComme
Chemical Manufacturing ;
Chemical Manufacturing Other Not Classified Specify in Comments Field
Chemical Manufacturing Other Not Classified Specify in Comments Field
Tier I: 05 METALS PROCESSING
Tier II: 01 Non-Ferrous Metals Processing
Industrial Processes Secondary Metal Production: SIC 33 Nonferrous Foundr
Primary Metal Production Aluminum Ore (Bauxite) Crushing/Handling
Primary Metal Production Aluminum Ore (Bauxite) Drying Oven
Primary Metal Production Primary Metal Production
Primary Metal Production Primary Metal Production Primary Copper Smelting
Primary Metal Production Primary Metal Production Primary Copper Smelting
Primary Metal Production Primary Metal Production Lead Production
Primary Metal Production Lead Production Sintering Charge Mixing
2304050000
30300001
30300002
30300101
30300502
30300521
30301001
30301014
30300201
30300518
30300599
30301010
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-11
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
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
30303010 Primary Metal Production Zinc Production Sinter Breaking and Cooling
30303011 Primary Metal Production Zinc Production Zinc Casting
30303014 - 30303099 Primary Metal Production Primary Metal Production Zinc Production
30400101 - 30400299 Secondary Metal Production
30400401 - 30400699 Secondary Metal Production Secondary Metal Production
30400801 - 30400899
30401001 - 30401099 Secondary Metal Production Secondary Metal Production Nickel Production
30404001 Secondary Metal Production Lead Cable Coating General
36000101 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
3030080S Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
30300313 - 30300819 Primary Metal Production Iron Production Sintering
30300824 - 30300826 Primary Metal Production Iron Production Blast Furnaces
30300S99 - 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 Tota
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-12
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
°U and GaS Production Natural Gas Processing Facilities Compressor Seals
Oil and Gas Production Natural Gas Processing Facilities Pump Seals
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
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
™
-------
Table 4.1-3 (continued)
Tier II: 04 Rubber & Miscellaneous Plastic Products
2308000000 Industrial Processes Rubber/Plastics: SIC 30 All Processes Total
30S00101 - 30800108 Rubber and Miscellaneous Plastics Products Rubber and Miscellaneous Plastics Prod
30300120 - 30800802 Rubber and Miscellaneous Plastics Products Rubber and Miscellaneous Plastics Prod
30800901 Rubber and Miscellaneous Plastics Products Plastic Miscellaneous Products Polystyr
30S99999 Rubber and Miscellaneous Plastics Products Other Not Specified Other Not Classifie
Tier II: 05 Mineral Products
2305000000 - 2305080000 Industrial Processes Mineral Processes: SIC 32
30500231 Mineral Products Asphalt Concrete Hot Bins and Screens: Continuous Process
30500301 Mineral Products Brick Manufacture Raw Material Drying
30500302 Mineral Products Brick Manufacture Raw Material Grinding
30500304 - 30500405 Mineral Products Mineral Products
30500499 - 30500606 Mineral Products Mineral Products
30500609 -30500611 Mineral Products Mineral Products Cement Manufacturing: Dry Process
30500613 Mineral Products Cement Manufacturing (Dry Process) Raw Material Grinding and Dryi
30500614 Mineral Products Cement Manufacturing (Dry Process) Clinker Cooler
30500617 Mineral Products Cement Manufacturing (Dry Process) Clinker Grinding
30500623 Mineral Products Cement Manufacturing (Dry Process) Preheater/Precalciner Kiln
30500624 Mineral Products Cement Manufacturing (Dry Process) Raw Mill Feed Belt
30500626 Mineral Products Cement Manufacturing (Dry Process) Raw Mill Air Separator
30500627 Mineral Products Cement Manufacturing (Dry Process) Finish Grinding Mill Feed Belt
30500629 Mineral Products Cement Manufacturing (Dry Process) Finish Grinding Mill Air Separ
30500699 Mineral Products Cement Manufacturing (Dry Process) Other Not Classified
30500706 Mineral Products Cement Manufacturing (Wet Process) Kilns
30500709 - 30500711 Mineral Products Mineral Products Cement Manufacturing: Wet Process
30500714 Mineral Products Cement Manufacturing (Wet Process) Clinker Cooler
30500717 Mineral Products Cement Manufacturing (Wet Process) Clinker Grinding
30500799 - 30500802 Mineral Products Mineral Products
30500806 Mineral Products Ceramic Clay/Tile Manufacture Raw Material Handling and Transfer
30500810 - 30500904 Mineral Products Mineral Products
30500907 - 30500909 Mineral Products Mineral Products Clay & Fly Ash Sintering
30500915 - 30501007 Mineral Products
30501010 Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Crushin
30501012 Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Screen!
30501013 Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Air Tab
30501017 Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Seconda
30501022 Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Drillin
30501034 Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Coal Se
30501035 Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Blastin
30501099 Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Other N
30501101 Mineral Products Concrete Batching General (Non-fugitive)
30501112 Mineral Products Concrete Batching Mixing: Wet
30501113 Mineral Products Concrete Batching Mixing: Dry
30501120 - 30501215 Mineral Products
30501223 - 30501503 Mineral Products
30501505 - 30501507 Mineral Products Mineral Products Gypsum Manufacture
30501511 - 30501513 Mineral Products Mineral Products Gypsum Manufacture
30501515 - 30501517 Mineral Products Mineral Products Gypsum Manufacture
30501519 - 30501606 Mineral Products Mineral Products
30501609 Mineral Products Lime Manufacture Hydrator: Atmospheric
30501611 Mineral Products Lime Manufacture Product Cooler
30501612 Mineral Products Lime Manufacture Pressure Hydrator
30501616 - 30501902 Mineral Products Mineral Products
30501905 - 30502006 Mineral Products Mineral Products
30502008 - 30502010 Mineral Products Mineral Products Stone Quarrying/Processing
30502012 - 30502105 Mineral Products Mineral Products
30502201 - 30502501 Mineral Products Mineral Products
30502508 - 30503103 Mineral Products Mineral Products
30503108 Mineral Products Asbestos Mining Overburden Stripping
30503109 Mineral Products Asbestos Mining Ventilation of Process Operations
30503199 - 30504010 Mineral Products Mineral Products
30504024 Mineral Products Mining and Quarrying of Nonmetallic Minerals Overburden Stripping
30504030 - 30504034 Mineral Products Mineral Products Mining & Quarrying of Nonmetallic Minerals
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-14
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30504099 - 30509101 Mineral Products Mineral Products
30515001 - 30588805 Mineral Products Mineral Products
30599999 Mineral Products Other Not Defined Specify in Comments Field
Tier II: 06 Machinery Products
2309000000 -2309100260 Industrial Processes Fabricated Metals: SIC 34
30900198 - 30988805 Fabricated Metal Products Fabricated Metal Products
30988806 Fabricated Metal Products Fugitive Emissions Other Not Classified
30999997 - 30999999 Fabricated Metal Products Fabricated Metal Products Other Not Classified
Tier II: 07 Electronic Equipment
31303502 Electrical Equipment Manufacturing - General Processes Cleaning
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 Transportation Equipment Automobiles/Truck Assembly Operations Solder Joint Grindi
31401101 - 31499999 Transportation Equipment Transportation Equipment
Tier II: 09 Construction
Industrial Processes Construction: SIC 15 - 17 All Processes Demolition
Industrial Processes Construction: SIC 15 -17 All Processes Blasting
Industrial Processes Construction: SIC 15-17 All Processes Welding Ope
Industrial Processes Construction: SIC 15 -17 General Building Construct
Industrial Processes Construction: SIC 15-17 General Building Construct
Industrial Processes Construction: SIC 15 -17 General Building Construct
Industrial Processes Construction: SIC 15 -17 Heavy Construction Demoli
Industrial Processes Construction: SIC 15 - 17 Heavy Construction Blasti
Industrial Processes Construction: SIC 15 - 17 Heavy Construction Weldin
Industrial Processes Construction: SIC 15 - 17 Road Construction Demolit
Industrial Processes Construction: SIC 15 -17 Road Construction Blastin
Industrial Processes Construction: SIC 15 - 17 Road Construction Welding
Industrial Processes Construction: SIC 15 - 17 Special Trade Construction
- 31100202 Building Construction Building Construction
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
Solvent Utilization Degreasing
Organic Solvent Evaporation Degreasing
Organic Solvent Evaporation Degreasing Fugitive Emissions Specify in Comments F
2311000020
2311000030
2311000080
2311010020
2311010030
2311010080
2311020020
2311020030
2311020080
2311030020
2311030030
2311030080
2311040080
31100199
31100299
2415000000 - 2415365999
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
2420020999 Solvent Utilization Dry Cleaning
40100199 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
Tier II: 04 Surface Coating
2401001000 - 2401990999 Solvent Utilization Surface Coating
2440020000 Solvent Utilization Miscellaneous Industrial Adhesive (Industrial) Applic
40200101 - 40200706 Surface Coating Operations Surface Coating Operations Surface Coating Applicatio
40200710 - 40200998 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)
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
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 Fugitive Emissions Coating
Surface Coating Operations Fugitive Emissions Cleartop Coat
Surface Coating Operations Fugitive Emissions Clean-up
Surface Coating Operations Surface Coating Operations Surface Coating - Miscella
40201101
40201103
40201105 - 40201303
40201305 • 40201403
40201405 - 40201503
40201505 - 40201603
40201605 - 40201703
40201705 - 40201803
40201805 - 40201903
40201999 - 40202003
40202005 - 40202103
40202105 - 40202203
40202205 - 40202303
40202305 - 40202403
40202405 - 40202503
40202505 - 40202603
40202605 - 40288805
40238822
40283823
40288824
40299995 - 40299999
Tier II: 05 Other Industrial
2430000000 - 2440000999 Solvent Utilization
40100401
40100499
49000101 - 49000199
49000202
49000206 - 49000599
49099998
49099999
Tier II: 06 Nonindustrial
2460000000 - 2465900000 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
ouivcul i_mu£uuuu
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
Tier II: 02 Petroleum & Petroleum Product Storage
2275900000 -2275900102 Mobile Sources Aircraft Refueling: All Fuels
2275900201 Mobile Sources Aircraft Refueling: All Fuels Underground Tank: Total
2501000000 -2501010900 Storage & Transport Petroleum & Petroleum Product Storage
2501060000 Storage & Transport Petroleum & Petroleum Product Storage Gasoline Servic
2501060200 Storage & Transport Petroleum & Petroleum Product Storage Gasoline Servic
2501070000 Storage & Transport Petroleum & Petroleum Product Storage Diesel Service
2501070200 Storage & Transport Petroleum & Petroleum Product Storage Diesel Service
2501995000 - 2501995180 Storage & Transport Petroleum & Petroleum Product Storage All Storage Types: Wor
31000104 Oil and Gas Production Crude Oil Production Crude Oil Sumps
31000105 Oil and Gas Production Crude Oil Production Crude Oil Pits
31000108 Oil and Gas Production Crude Oil Production Evaporation from Liquid Leaks into Oil
31000132 Oil and Gas Production Crude Oil Production Atmospheric Wash Tank (2nd Stage of Ga
40300101 - 40399999 Petroleum Product Storage (Refineries Oil and Gas Fie
40400301 - 40400305 Bulk Terminals/Plants Petroleum Storage Tanks Oil Field Storage of Crude Oil
40400306 Bulk Terminals/Plants Oil Field Storage of Crude External Floating Roof Tank: With
40400307 Bulk Terminals/Plants Oil Field Storage of Crude Internal Floating Roof Tank: With
Tier II: 03 Petroleum & Petroleum Product Transport
2505000000 -2505040180 Storage & Transport Petroleum & Petroleum Product Transport
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-16
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
40600101
40688801
Tier II: 04
2501060050
2501070050
40600301
40600503
40600706
Tier II: 05
2501060100
2501070100
40600401
40600501
40600601
Tier II: 06
2275900202
2501060201
2501070201
42500101
42500102
Tier II: 07
2510000000
30100102
30100106
30100508
30101404
30101602
30101808
30101810
30101811
30101815
30101816
30101821
30101840
30101864
30101865
30101883
30101893
30101894
30102425
30102427
30102612
30102709
30103003
30103105
30104007
30106010
30130108
30183001
30201920
30800109
30800110
30800803
31501001
40200707
40201104
40201304
40201404
40201504
40201604
40201704
40201804
- 40600299 Transportation and Marketing of Petroleum Products
- 40688805 Transportation and Marketing of Petroleum Products Fugitive Emissions Specify in
Service Stations: Stage I
- 2501060053 Storage & Transport Petroleum & Petroleum Product Storage Gasoline Service Stati
- 2501070053 Storage & Transport Petroleum & Petroleum Product Storage Diesel Service Station
- 40600399 Transportation and Marketing of Petroleum Products Gasoline Retail Operations St
Transportation and Marketing of Petroleum Products Pipeline Petroleum Transport -
Transportation and Marketing of Petroleum Products Consumer (Corporate) Fleet Refu
Service Stations: Stage II
- 2501060103 Storage & Transport Petroleum & Petroleum Product Storage Gasoline Service Stati
- 2501070103 Storage & Transport Petroleum & Petroleum Product Storage Diesel Service Station
- 40600499 Transportation and Marketing of Petroleum Products Filling Vehicle Gas Tanks Sta
Transportation and Marketing of Petroleum Products Pipeline Petroleum Transport -
Transportation and Marketing of Petroleum Products Consumer (Corporate) Fleet Refu
Service Stations: Breathing & Emptying
Mobile Sources Aircraft Refueling: All Fuels Underground Tank: Breathing
Storage & Transport Petroleum & Petroleum Product Storage Gasoline Servic
Storage & Transport Petroleum & Petroleum Product Storage Diesel Service
Fixed Roof Tanks (210 Bbl Size) Breathing Loss
Fixed Roof Tanks (210 Bbl Size) Working Loss
Organic Chemical Storage
- 2510995405 Storage & Transport Organic Chemical Storage
Chemical Manufacturing Adipic Acid Raw Material Storage
Chemical Manufacturing Adipic Acid Drying, Loading, and Storage
Chemical Manufacturing Carbon Black Production Bagging/Loading
Chemical Manufacturing Paint Manufacture Raw Material Storage
Chemical Manufacturing Phosphoric Acid: Wet Process Gypsum Pond
Chemical Manufacturing Plastics Production Monomer and Solvent Storage
Chemical Manufacturing Plastics Production Conveying
Chemical Manufacturing Plastics Production Storage
Chemical Manufacturing Plastics Production Pellet Silo
Chemical Manufacturing Plastics Production Transferring/Handling/Loading/Packing
Chemical Manufacturing Plastics Production Extruding/PeUetizing/Conveying/Storage
Chemical Manufacturing Plastics Production Resin Storage Tank ** (Use 6-45-200-23
Chemical Manufacturing Plastics Production Pellet Silo/Storage
Chemical Manufacturing Plastics Production Transferring/Conveying
Chemical Manufacturing Plastics Production Transferring/Conveying/Storage (Polyure
Chemical Manufacturing Plastics Production Raw Material Storage
Chemical Manufacturing Plastics Production Solvent Storage
Chemical Manufacturing Synthetic Organic Fiber Manufacturing Fiber Storage (Use 6-
Chemical Manufacturing Synthetic Organic Fiber Manufacturing Solvent Storage (Use
Chemical Manufacturing Synthetic Rubber (Manufacturing Only) Pre-storage Tank
Chemical Manufacturing Ammonium Nitrate Production Bulk Loading (General)
Chemical Manufacturing Ammonium Phosphates Screening/Transfer
Chemical Manufacturing Terephthalic Acid/Dimethyl Terephthalate Product Transfer V
Chemical Manufacturing Urea Production Bulk Loading
Chemical Manufacturing Pharmaceutical Preparations Storage/Transfer
Chemical Manufacturing Chlorobenzene DCB Crystal Handling/Loading
Chemical Manufacturing General Processes Storage/Transfer
Food and Agriculture Vegetable Oil Processing Solvent Storage (Use 4-07-016-15 & -
Rubber and Miscellaneous Plastics Products Tire Manufacture Solvent Storage ** (Us
Rubber and Miscellaneous Plastics Products Tire Manufacture Solvent Storage (Use 4
Rubber and Miscellaneous Plastics Products Plastic Foam Products Bead Storage
Photographic Equipment Photocopying Equipment Manufacturing Resin Transfer/Storage
Surface Coating Operations Surface Coating Application - General Adhesive: Solvent
Surface Coating Operations Fabric Coating/Printing Coating Storage (Also See Speci
Surface Coating Operations Paper Coating Coating Storage
Surface Coating Operations Large Appliances Coating Storage
Surface Coating Operations Magnet Wire Surface Coating Coating Storage
Surface Coating Operations Automobiles and Light Trucks Coating Storage
Surface Coating Operations Metal Can Coating Coating Storage
Surface Coating Operations Metal Coil Coating Solvent Storage (Use 4-07-004-01 thr
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-17
1985-1996 Methodology
Introduction.
-------
Table 4.1-3 (continued)
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
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
30100S04 Chemical Manufacturing Chloro-alkali Production Chlorine Loading: Storage Car Yen
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
30102S03 - 30102805 Chemical Manufacturing Chemical Manufacturing Normal Superphosphate
30102321 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-18
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30300827
30300841
30300842
30300915
30301011
30301016
30301026
30302304
30302305
30302307
30302309
30302310
30302316
30303009
30303012
30400356
30400357
30400721
30400723
30500203
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
- 30301013
- 30501016
- 30501038
- 30501043
- 30501111
- 30501510
Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
Primary Metal Production Iron Production (See 3-03-015 for Integrated Iron & Steel
Primary Metal Production Steel Manufacturing (See 3-03-015 for Integrated Iron & S
Primary Metal Production Primary Metal Production Lead Production
Primary Metal Production Lead Production Sinter Transfer
Primary Metal Production Lead Production Sinter Dump Area
Primary Metal Production Taconite Iron Ore Processing Ore Transfer
Primary Metal Production Taconite Iron Ore Processing Ore Storage
Primary Metal Production Taconite Iron Ore Processing Bentonite Storage
Primary Metal Production Taconite Iron Ore Processing Traveling Grate Feed
Primary Metal Production Taconite Iron Ore Processing Traveling Grate Discharge
Primary Metal Production Taconite Iron Ore Processing Pellet Transfer
Primary Metal Production Zinc Production Raw Material Handling and Transfer
Primary Metal Production Zinc Production Raw Material Unloading
Secondary Metal Production Grey Iron Foundries Sand Silo
Secondary Metal Production Grey Iron Foundries Conveyors/Elevators
Secondary Metal Production Steel Foundries Sand Silo
Secondary Metal Production Steel Foundries Conveyors/Elevators
Mineral Products Asphalt Concrete Storage Piles
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 Products Mineral Products Surface Mining Operations
Mineral Products Mineral Products Surface Mining Operations
Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Overbur
Mineral Products Mineral Products Concrete Batching
Mineral Products Concrete Batching Transferring: Conveyors/Elevators
Mineral Products Concrete Batching Storage: Bins/Hoppers
Mineral Products Fiberglass Manufacturing Raw Material: Unloading/Conveying
Mineral Products Fiberglass Manufacturing Raw Material: Storage Bins
Mineral Products Gypsum Manufacture Conveying
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-19
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
30501610
30501613
30501903
30501904
30502007
30502106
30502502
30502503
30502505
30503104
30503110
30503111
30504020
30504025
30504036
30510001
30510604
30703001
30703002
30501615
30502507
30503107
30504023
30510599
Mineral Products Lime Manufacture Raw Material Storage Piles
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
Mineral Products Mineral Products Sand/Gravel
Mineral Products Mineral Products Asbestos Mining
Mineral Products Asbestos Mining Stockpiling
Mineral Products Asbestos Mining Tailing Piles
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
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
Tier II: 12 Bulk Materials Transport
2535000000 - 2535030140 Storage & Transport Bulk Materials Transport
30200711 Food and Agriculture Grain Millings Durum Milling: Grain Receiving
30200721 Food and Agriculture Grain Millings Rye: Grain Receiving
30200731 Food and Agriculture Grain Millings Wheat: Grain Receiving
30200741 Food and Agriculture Grain Millings Dry Corn Milling: Grain Receiving
30501044 Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Train L
31100203 Building Construction Demolitions/Special Trade Contracts Debris Loading
31100204 Building Construction Demolitions/Special Trade Contracts Debris Loading
Tier I: 10 WASTE DISPOSAL & RECYCLING
Tier II: 01 Incineration
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 Incinerator/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 Bum 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
2601030000
2601000000
30101015
30101023
31307001
31307002
31401001
31401002
49000203
50100101
50100104
50100105
50100505
50200101
50200205
50200301
50300101
50300501
50300503
50300505
50300506
Tier II: 02 Open Burning
50100103
50100517
50200105
50200507
50300109
2610000000 - 2610030000
50100201
50100202
50200201
50200202
50300201 - 50300205
Tier II: 03 POTW
2630000000
2630020000
50100701 - 50100704
50100793
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-20
1985-1996 Methodology
Introduction
-------
Table 4.1-3 (continued)
Tier II: 04 Industrial Waste Water
- 50100604
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
50200901
50282599
50300701
50300901
50390002
50400101
50400102
50400103
50400104
50400150
50400151
50400301
50400320
50410310
50410311
50410312
50410313
50410405
50410408
50410420
50410530
50410562
50410610
50410622
50410645
50490004
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
Solid Waste Disposal - Commercial/Institutional Asbestos Removal General
Solid Waste Disposal - Commercial/Institutional Wastewater, Points of Generation S
Solid Waste Disposal - Industrial Liquid Waste General
Solid Waste Disposal - Industrial Asbestos Removal General
Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Coal
Site Remediation General Processes Fixed Roof Tanks: Breathing Loss
Site Remediation General Processes Fixed Roof Tanks: Working Loss
Site Remediation General Processes Float Roof Tanks: Standing Loss
Site Remediation General Processes Float Roof Tanks: Withdrawal Loss
Site Remediation General Processes Storage Bins
Site Remediation General Processes: Liquid Waste: General: Transfer
Site Remediation General Processes Open Refuse Stockpiles : General
Site Remediation General Processes Storage Bins - Solid Waste
Site Remediation In Situ Venting/Venting of Soils Active Aeration
Site Remediation In Situ Venting/Venting of Soils Active Aeration: Vacuum
Site Remediation In Situ Venting/Venting of Soils Active Aeration, Vacuum: Vapor
Site Remediation In Situ Venting/Venting of Soils Active Aeration, Vacuum: Vacuum
Site Remediation Air Stripping of Groundwater Oil/Water Separator
Site Remediation Air Stripping of Groundwater Treatment Tanks
Site Remediation Air Stripping of Groundwater Air Stripping Tower
Site Remediation Thermal Destruction Combustion Unit
Site Remediation Thermal Destruction Waste Disposal: Chemical Stabilization
Site Remediation Thermal Desorption Pretreatment
Site Remediation Thermal Desorption Thermal Desorber: Kiln
Site Remediation Thermal Desorption Wastes: Containers
Site Remediation General Processes Incinerators: Process Gas
Tier I: 11ON-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
Procedures Document for 1900-1996
4-21
1985-1996 Methodology
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
Tierll: 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
Tierll: 07 Fugitive Dust
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-22
1985-1996 Methodology
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 n categories:
Tier I Category
(01) FUEL COMBUSTION - ELECTRIC UTILITY
Tier n Category
(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
Report1). 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
National Air Pollutant Emission Trends
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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.
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, SO2i 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. LI 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.
National Air Pollutant Emission Trends
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• Flue- and stack-level: One page per flue-stack for design parameter data.
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 ail 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,.
National Air Pollutant Emission Trends
Procedures Document/or 1900-1996
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Emission factors from AP-424 were used in calculating emissions. The emission factor used
depends upon the SCC and pollutant, as explained below.
• 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 (APOD). 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
Procedures Document for 1900-1996
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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 IE) 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 (GEM) 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
(Eq. 4.2-1)
where: NOXCOAL
NOXRT
HTI
NOX emissions for the boiler coal SCC (in tons)
ARD's coal NOX rate for the given boiler (in Ibs/MMBtu)
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/CEM Data
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 forNOx 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
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• 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:
EOSD
HTIJUL
'SCC
SCC
31 x HTIANN,
xEANN,
see
(Eq. 4.2-2)
see
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
National Air Pollutant Emission Trends
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1985-1996 Methodology
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and their fuel data would be incorporated in the growth ratios and would be reflected in the 1996 data for
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:
SCO 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:
= coal tons * emission factor * sulfur content * (l-control efficiency)
" - ~
coal
calculation:
S02
coal
(1300000) (39) (3.1716) (1-.893)
2000
• result:
SO2coa[ = 8602 to nearest integer
But replace by 1995 ETS/CEM 9332.5590
Therefore EIAS02 = 8603 arid 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
Procedures Document for 1900-1996
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1985-1996 Methodology
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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. Tlie 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. TJie 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
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Table 4.2-1. Boiler Emissions Data Sources for NOX and SO2 by Year
Year
NOV
SO,
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
Overlaid ARD coal NOX rate calculations
when possible
Overlaid ARD coal NOX rate calculations
when possible
Overlaid ARD coal NOX rate calculations
when possible
Overlaid ARD coal NOX rate calculations
when possible
Overlaid ARD coal NOX rate calculations
when possible
Overlaid ARD coal NOX rate calculations
when possible
Overlaid ARD coal NOX rate calculations
when possible
NADBV311 data
Calculated from EIA-767 data
Calculated from EIA-767 data
Calculated from EIA-767 data
Calculated from EIA-767 data
Calculated from EIA-767 data
Calculated from EIA-767 data
Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
Overlaid ARD coal NOX rate calculations Calculated from EIA-767 data
when possible
Overlaid ARD coal NOX rate calculations
when possible; overlaid ETS/CEM data
when possible
Overlaid ETS/CEM data when possible
Grew from 1995 data using EIA-759 data
Calculated from EIA-767 data
Overlaid ETS/CEM data when possible
Grew from 1995 data using EIA-759 data
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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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
Lignite No data
Wall
Opposed
Tangential
Stoker
Cyclone
National Air Pollutant Emission Trends
Procedures Document for 1900-1996 4-32
*
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
All
All
All
All
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
10100301
10100301
10100301
10100302
10100306
10100303
1985-1996 Methodology
Electric Utilities
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Table 4.2-2. (continued)
Fossil-Fuel
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
Bottom Type
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
All
sec
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
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1985-1996 Methodology
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Table 4.2-3. Algorithms Used to Estimate Emissions from Electric Utility Boilers
,scc = FCscc *
x (1 - (RENOx * CENOz>b}} x UCF
E
pM-10orPM-2.S,SCC
= FCSCC X EFPM-WorPM-2.5,SCC X Af X
UCF
where: E
FC
EF
S
A
RE
CE
b
f
UCF
unitcoal
unitoil
unitgas
= estimated emission (in tons)
= fuel consumption (in unitf )
= emission factor (in Ibs/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
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Table 4.2-4. Algorithms Used to Disaggregate ETS/CEM Boiler Data to the Boiler-
SCC Level
CEMSO2
767SO2
sec
X CEMSO2,
CEMNOXt
sec
767NOXSCCA
767NOX
X CEMNOX,
CEMHTI,
sec
767HTIscc>b}
767HTIb J
X CEMHTL
where: b = boiler
CEMSO2, CEMNO,, CEMHTI = ETS/CEM annual boiler data for given parameter
767SO2, 767NO,, 767HTI = Form EIA-767-based calculated data for given parameter
National Mr Pollutant Emission Trends
Procedures Document for 1900-1996
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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
(01) FUEL COMBUSTION- ELECTRIC UTILITY
(02) FUEL COMBUSTION - INDUSTRIAL
(03) CHEMICAL & ALLIED PRODUCT MANUFACTURING
(05) METALS PROCESSING
(06) PETROLEUM & RELATED INDUSTRIES
(07) OTHER INDUSTRIAL PROCESSES
(09) STORAGE & TRANSPORT
(10) WASTE DISPOSAL & RECYCLING
(13) NATURAL SOURCES
(14) MISCELLANEOUS
Tier n Category
(05)
All
All
All
All
All
All
All
(01)
(05)
Gas Turbines and Internal
Combustion
Biogenic
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.
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1985-1996 Methodology
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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.
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 BE A 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.
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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
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 (ERGAM-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 n
vapor recovery systems are estimated to reduce emissions by 84 percent.10 Stage n controls are already
in place in the District of Columbia, St. Louis, Missouri, and parts of California. Stage n 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
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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.
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 n 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 H: 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
n emissions, plus spillage.
The Stage n emissions were also revised to reflect changes in emission factors. Stage n emission
factors are a function of gasoline RVP and temperature. Gasoline RVPs have decreased since 1985 in
response to the phase I and phase n RVP regulations. MOBILES was used to calculate Stage n 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 H, 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
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estimate emissions for each inventory year. Gasoline usage was back-calculated from the Stage n VOC
emissions and emission factor.
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):
CEt = CEBY + (CEBY x EG)
(Eq. 4.3-1)
where: CEj = controlled emissions for inventory year i
CEjjY = controlled emissions for base year
EG, = earnings growth for inventory year i
Earnings growth (EG) is calculated using Equation 4.3-2:
DAT,
EG, = 1 -
DAT,
(Eq. 4.3-2)
BY
where: DATS = 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):
UEt =
CE;
x _ CEFF}
100 J
(Eq. 4.3-3)
where: UE; = uncontrolled emissions for inventory year i
CEj = controlled emissions for inventory year I
CEEF = control efficiency (%)
Third, controlled emissions are recalculated incorporating rule effectiveness using the following
equation (Equation 4.3-4):
EF,
(Eq. 4.3-4)
BY)
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where: CERj
UC,
REEF
CEFF
EF
BY
controlled emissions incorporating rule effectiveness
uncontrolled emissions
rule effectiveness (%)
control efficiency (%)
emission factor for inventory year i
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 paniculate (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)llb 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.nc 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.
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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
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 S A-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:
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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
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 n 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.
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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.L1 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:
South:
47.00 °N
26.00 °N
East:
West:
67.00 °W
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
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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. 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 1S 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 EGOS) 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, S02, 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)
2)
3)
an Emissions Preprocessor System Version 2.0 (EPS2.0) Workfile
an ad hoc report from AIRS/FS
data files extracted from a state emission inventory database
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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.
4.3.3.L4. 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:
EMISSIONS^ = EMISSIONSANNUAL * SUMTHRU * 1/(13 * DPW) (Eq. 4.3-5)
where:
EMISSIONSASD
EMISSIONSANNUAL
SUMTHRU
DPW
= average summer day emissions
= annual emissions
= summer throughput percentage
= 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:
EMISSIONS^ = EMISSIONSANNUAL I (SUMFACSCC * WDFACSCC) (Eq. 4.3-6)
where:
EMISSIONSASD
SUMFACSCC
WDFACSCC
= average summer day emissions
= annual emissions
= default summer season temporal factor for SCC
= 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:
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EMISSIONS4,n = EMISSIONS
JASD
ANNUAL
I 365
(Eq. 4.3-7)
where:
EMISSIONS
EMISSIONS
ASD
= average summer day emissions
= 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.
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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
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 fire.s 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 SPECIATE1 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,
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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.
4.3.3.4.1 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
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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.
4.3.3.4.3 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.
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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:
Year
1990
1991
1992
1993
1994
1995
1996
1992 PCE Deflator
93.6
97.3
100.0
102.6
104.9
107.6
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
Colorado - Mastercraft
All VOC source emissions were re-extracted to obtain
emissions without rule effectiveness for the year 1994.
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
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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
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.
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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
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 =.(P*B) * EFe + (P,*B)
* EFf
(Eq. 4.3-8)
Where: E =
B =
P —
rc
EFC =
EFf =
annual county emissions (Ibs/year)
number of bales ginned in the county
fraction of total bales at gins with conventional controls
emission factor for gins with conventional controls (Ibs/bale)
fraction of total bales .at gins with full controls
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:
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I/ withheld to avoid disclosing individual gins
2/ 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
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. 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] + [(Pf*B)- * EF}
(Eq. 4.3-9)
Where: Pc =
Pf =
B =
EFC =
BF, =
Emissions =
0.8
0.2
40,550 bales
1.21b/balePM-10
0.82 Ib/bale PM-10
[(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
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4.3-15. 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 4.3.5.3 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:
GS
GS
1995
(Eq. 4.3-10)
where: CER
UC
GS
REEF
CEFF
RP
1996 —
1995 =
controlled emissions incorporating rule effectiveness
uncontrolled emissions
growth surrogate (either BEA or SEDS data)
rule effectiveness (percent)
control efficiency (percent)
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 m 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 H 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. 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.
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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 H rule will restrict emissions from tanks, containers, and surface impoundments.2 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 H 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.
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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 E vapor
recovery programs.
Stage E is required in serious and above nonattainment areas. Moderate areas must implement
Stage H if onboard is not promulgated, and are also encouraged to implement Stage H
(regardless of whether onboard is promulgated) in order to achieve early reductions. (Onboard
controls require fleet turnover to become fully effective.)
• Stage H 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 EL or comparable measures.28
States must prescribe the use of Stage H 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)31
Table 4.3-26 list the areas with Stage H 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.
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4.3.6.2.8 Title III—
The source categories affected by Title ffl maximum achievable control technology (MACI)
Standards were identified by using EPA's timetable for regulation development under Title HI.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 m 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
i
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. H.-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
Procedures Document for 1500-1996
4-60
1985-1996 Methodology
Industrial
-------
8. E.H. Pechan & Associates, Inc., National Assessment ofVOC, CO, andNOx 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. •
lib. 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
Procedures Document for 1900-1996
4-61
1985-1996 Methodology
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 of1990. April 16,1992.
30. Technical Guidance - Stage n 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
Praceehires Document for 1900-1996
4-62
1985-1996 Methodology
Industrial
-------
Table 4.3-1. SCCs With 100 Percent CO Rule Effectiveness
sec
Process
30300801
30300913
30300914
30500401
30600201
31000205
31000299
39000689
39000797
Primary Metals Production - Iron Production - Blast Furnaces
Primary Metals Production -Steel Production - Basic Oxygen Furnace: Open Hood-Stack
Primary Metals Production -Steel Production - Basic Oxygen Furnace: Closed Hood-Stack
Mineral Products - Calcium Carbide - Electric Furnace (Hoods and Main Stack)
Petroleum Industry - Fluid Catalytic Cracking Units
Oil and Gas Production - Natural Gas Production - Flares
Oil and Gas Production - Natural Gas Production - Other Not Classified
In-Process Fuel Use - Natural Gas - General
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
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
RI
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
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 MVMA
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
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
Fuel Volatility Surveys interpolated to
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-65
1985-1996 Methodology
Industrial
-------
Table 4.3-4. Seasonal Maximum and Minimum Temperatures (°F) by State
AL
AK
AZ
AR
CA
CO
CT
DE
DC
FL
GA
HI
ID
1L
IN
IA
KS
KY
LA
ME
MD
MA
MI
MN
MS
MO
MT
NE
NV
NH
NJ
NM
NY
NC
ND
OH
OK
OR
PA
Fit
SC
SD
TN
TX
UT
VT
VA
WA
WV
Wl
WY
Winter
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
Spring
Min Max
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
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
Fal
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
I
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", 198212.
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
071
005
073
047
051
079
039
129
County
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
Procedures Document for 1900-1996
4-67
1985-1996 Methodology
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
SCC 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
Bituminous Coal (thousand short tons)
Industrial 115,854 . 111,119 111,695
Distillate Fuel (thousand barrels)
Industrial 203,659 206,108 210,699
Liquefied Petroleum Gases (thousand barrels)
Industrial 437,964 411,451 . 447,120
Motor Gasoline (thousand barrels)
Transportation 2,433,592 2,507,936 2,570,047
All Sectors 2,493,361 2,567,436 2,630,089
Natural Gas (million cubic feet)
Industrial 6,867 6,502 7,103
Residual Fuel (thousand barrels)
Industrial 120,002 132,249 107,116
434
392
117,729 117,112
2,627,331 2,617,450
2,685,145 2,674,669
7,479 7,887
387
118,322
209,553 197,035 205,856
453,599 441,784 457,013
2,703,666
2,760,414
8,120
105,448 95,646 118,122
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-70
1985-1996 Methodology
Industrial
-------
Table 4.3-10. AMS to NAPAP Source Category Correspondence
AMS
NAPAP
sec
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
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)
13 Industrial Fuel
14 Industrial Fuel
16 Industrial Fuel
17 Industrial Fuel •
18 Industrial Fuel •
19 Industrial Fuel •
15 Industrial Fuel -
20 Industrial Fuel -
• Anthracite Coal
• Bituminous Coal
• Distillate Oil
Residual Oil
Natural Gas
Wood
Coke
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
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
SCO
Category
sec
Category
Waste Disposal, Treatment, & Recovery
2601010000 On-Site Incineration - Industrial (Total)
2601020000 On-Site Incineration -
Commercial/Institutional (Total)
2601030000 On-Site Incineration - Residential (Total)
2610010000 Open Burning - Industrial (Total)
2610020000 Open Burning - Commercial/Institutional
(Total)
2610030000 Open Burning - Residential (Total)
2630020000 Wastewater Treatment - Public Owned
(Total)
2640000000 TSDFs - All TSDF Types (Total: All
Processes)
22 On-Site Incineration - Industrial
23 On-Site Incineration -
Commercial/Institutional
21 On-Site Incineration - Residential
25 Open Burning - Industrial
26 Open Burning - Commercial/Institutional
24 Open Burning - Residential
100 Publicly-Owned Treatment Works
(POTWs)
109 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
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 Workf iles
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
Kentucky - Jefferson Jefferson County - EPS Workfile
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
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
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
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
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 1 990 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-73
1985-1996 Methodology
Industrial
-------
r
Table 4.3-11 (continued)
Dats
ie/Format
Temporal
Resolution
Year of
Data
Adjustments to Data
South Carolina
South Dakota
Tennessee
Texas
Vermont
Virginia
West Virginia
Wisconsin
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State Format
State - EPS Workfile
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State Format
Annual 1991 Average Summer Day estimated using default
temporal factors.
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
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
Data Source/Format
State - EPS Workfile
State - EPS Workfile
State - Hard copy
AIRS-AMS - 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
AIRS-AMS- Ad hoc retrievals
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 - State Format
State - EPS Workfile
State - EPS Workfile
AIRS-AMS - Ad hoc retrievals
State - State Format
Temporal
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Annual
Daily
Daily
Daily
Daily
Annual
Daily
Daily
Daily
Daily
Entire State
Entire State
Entire State
Jacksonville, Miami/
Ft. Lauderdale, Tampa
Atlanta Urban Airshed
(47 Counties)
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. Inventorv
Kentucky Ozone Nonattainment None
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
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
-------
o
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gment Output
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egment Output
General
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Q.
•*•*
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Q.
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STATE FIPS CODE
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FIPS CODE
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12.
STATE FIPS CODE
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U.
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55
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H
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COUNTY FIPS CODE
£
HI
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COUNTY FIPS CO
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POINT NUMBER
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Q.
POINT NUMBER
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-5
—
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Q
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CO
CO
13
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HEIGHT
v^
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^^
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.
X
CO
WINTER
THROUGHPUT
g
a.
PLANT NAME
HI
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t
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POLLUTANT CODE
g
HEAT CONTENT
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DEFAULT
ESTIMATED
EMISSIONS
11
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P
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't>
-------
Table 4.3-14. SEDS National Fuel Consumption, 1990-1996 (trillion Btu)
FuelTvoe End-User
Anthracite Coal
Commercial
Electric utility
Industrial
Residential
Bituminous Coal
Commercial
Electric utility
Industrial
Residential
Distillate Fuel
Commercial
Industrial
Residential
Total
Code
ACCCB
ACEUB
ACICB
ACRCB
BCCCB
BCEUB
BCICB
BCRCB
DFCCB
DFICB
DFRCB
DFTCB
1990
12
17
10
19
80
16,071
2,744
43
487
1,181
837
6,422
1991
11
16
8
17
72
15,997
2,592
39
482
1,139
832
6,210
1992
11
17
7
17
75
16,175
2,505
40
464
1,144
865
6,351
11
16
11
16
72
16,825
2,489
40
464
1,100
913
6,466
11
15
10
16
70
16,995
2,434
40
450
1,090
887
6,417
11
15
10
16
69
17,164
2,379
39
435
1,080
862
6,368
11
15
10
16
68
17,333
2,333
39
422
1,071
836
6,319
Distillate Fuel including Kerosene jet fuel
Electric utility
Kerosene
Commercial
Industrial
Residential
Total
Liquid Petroleum Gas
Commercial
Industrial
Residential
Total
Natural Gas
Commercial
Electric utility
Industrial
Residential
Total
Residual Fuel
Commercial
Electric utility
Industrial
Total
Population
DKEUB
KSCCB
KSICB
KSRCB
KSTCB
LGCCB
LGICB
LGRCB
LGTCB
NGCCB
NGEUB
NGICB
NGRCB
NGTCB
RFCCB
RFEUB
RFICB
RFTCB
TPOPP
86
12
12
64
88
64
1,608
365
2,059
2,698
2,861
8,520
4,519
19,280
233
1,139
417
2,820
248,709
80
12
11
72
96
69
1,749
389
2,227
2,808
2,854
8,637
4,685
19,605
213
1,076
336
2,657
252,131
67
11
10
65
86
67
1 ,860
382
2,328
2,884
2,829
8,996
4,821
20,139
191
854
391
2,518
255,025
77
14
13
76
103
70
1,794
399
2,282
2,996
2,744
9,387
5,097
20,868
175
939
452
2,479
257,785
64
13
10
67
89
70
1,804
398
2,290
3,035
2,720
9,635
5,132
21,164
170
823
459
2,346
259,693
58
12
9
59
76
70
1,813
397
2,298
3,074
2,698
9,883
5,166
21,461
168
726
469
2,213
261,602
54
11
9
51
65
70
1,823
397
2,306
3,114
2,675
10,131
5,201
21,757
167
650
481
2,080
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 $)
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)
Faron
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
Oit and gas extraction
Nonmotallte 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
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
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
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
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
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
1993
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
1994
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
1995
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
1996
1
4,086
280
3,805
981
994
3,231
408
447
16
432
29
4,058
3,423
27
25
3
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
on
29
59
OQ
DO
9
31
2
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 1QQ9 1QQ1 1QQ/1 1QQi;
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
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
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
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
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
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
3O5'
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
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
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
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
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Procedures Document for 1900-1996
4-81
1985-1996 Methodology
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Procedures Document for 1900-1996
4-82
1985-1996 Methodology
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-84
1985-1996 Methodology
Industrial
-------
Table 4.3-20. Cotton Ginning Emission Factors22
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
"Average 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 10
Blount 1/
Cherokee 1/
District 20
Chilton 1/
Fayette 1/
Pickens 1/
Shelby 1/
Tallapoosa 1/
Tuscaloosa 1/
District 30 21
Autauga 1/
Dallas 1/
Elmore
Greene 1/
Hale 1/
Lowndes 1/
Macon 1/
Marengo 1/
District 40
Running Bales
Ginned
17,498,800
12,000
12,000
35,200
59,300
25,750
144,250
4,538
4,538
4,538
4,538
4,538
4,538
4,538
4,538
4,070
4,070
6,100
4,070
4,070
4,070
4,070
4,070
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 21
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
•The data in and format of this table were taken from the 03/25/96 Cotton Ginnings report.
M Withheld to avoW disclosing individual gins.
2/ 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
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Procedures Document for 1900-1996
4-87
1985-1996 Methodology
Industrial
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Procedures Document for 1900-1996
4-88
1985-1996 Methodology
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4-89
1985-1996 Methodology
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Procedures Document for 1900-1996
4-91
1985-1996 Methodology
Industrial
-------
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Table 4.3-25. Area Source VOC Controls by SCC and Pod
sec
SOURCE
MEASURE
PCTRD96
211 2420010055 Dry Cleaning - perchioroethylene
211 2420000055 Dry Cleaning -perchioroethylene
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 - underground1 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 Dry Cleaning -perchioroethylene
217 Bulk Terminals
241 Cold cleaning
250 Aircraft surface coating
251 marine surface coating
259 SOCMI batch reactor processes
270 Treatment, stroage and disposal facilities
272 Cutback Asphalt
274 SOCMI fugitives
276 Petroleum refinery fugitives
277 Pharmaceutical manufacture
278 Synthetic fiber manufacture
279 Oil and natural gas production fields
280 Service stations - stage 1-truck unloading
284 Municipal solid waste landfills
National
National
National
National
National
Moderate+
National
Marginal+
National
National
National
National
Moderate-t-
National
National
NOTE: A pod Is a group of SCCs with similar emissions and process characteristics for which common control measures
emission reductions) can be applied.
(i.e., cost and
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
Countv
State
Countv
State
Countv
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
BullittCo
Campbell Co
Jefferson Co
Kenton Co
Oldham Co
Androscoggin Co
Cumberland Co
Kennebec Co
KNO.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
. BarnstableCo
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
MerrimackCo
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
Bn'stol 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
TarrantCo
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
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4-97
1985-1996 Methodology
Industrial
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Table 4.3-27. VOC Area Source RACT
sec
POD PODNAME
ATTAINMENT RULPEN96 CONEFF96
2102001000
2102001000
2102001000
2102001000
2102002000
2102002000
2102002000
2102002000
2102004000
2102004000
2102004000
2102004000
2102005000
2102005000
2102005000
2102005000
2102006000
2102006000
2102006000
2102006000
22
22
22
22
22
22
22
22
23
23
23
23
23
23
23
23
24
24
24
24
Industrial Bituminous Coal Combustion
Industrial Bituminous Coal Combustion
Industrial Bituminous Coal Combustion
Industrial Bituminous Coal Combustion
Industrial Anthracite Coal Combustion
Industrial Anthracite Coal Combustion
Industrial Anthracite Coal Combustion
Industrial Anthracite Coal Combustion
Industrial Distillate Oil Combustion
Industrial Distillate Oil Combustion
Industrial Distillate Oil Combustion
Industrial Distillate Oil Combustion
Industrial Residual Oil Combustion
Industrial Residual Oil Combustion
Industrial Residual Oil Combustion
Industrial Residual Oil Combustion
Industrial Natural Gas Combustion
Industrial Natural Gas Combustion
Industrial Natural Gas Combustion
Industrial Natural Gas Combustion
Moderate
Serious
Severe
Extreme
Moderate
Serious
Severe
Extreme
Moderate
Serious
Severe
Extreme
Moderate
Serious
Severe
Extreme
Moderate
Serious
Severe
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 far 1900-1996
4-98
1985-1996 Methodology
Industrial
-------
0
o
O
CO
«J
o
I
o
CO
to
+••
(0
Q
I
o
o
CO
I
CD
National Air Pollutant Emission Trends
Procedures Document for ] 900-1996
4-99
1985-1996 Methodology
Industrial
-------
r
0)
u
I
Q.
I
-------
4.4 OTHER COMBUSTION
The source categories falling under "Other Combustion" include the following Tier I and Tier E
categories:
Tier I Category
OTHER COMBUSTION
MISCELLANEOUS
Tier n Category
All
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
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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 HT
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 Document 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 Report10 and the Preliminary Data Analysis.11 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
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statistics 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
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were 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.
CEt = CEBY
(CEBY x
(Eq. 4.4-1)
where: CE{ = controlled emissions for inventory year I
= controlled emissions for base year
= earnings growth for inventory year I
Earnings growth is calculated using Equation 4.4-2:
DAT,.
EG,. = 1-
DAT,
(Eq. 4.4-2)
BY
where: EG = earnings growth
DATS = 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.
UE,. =
CE:
1_ CEFF]
. " 100 J
(Eq. 4.4-3)
where: UE,
CES
CEFF
uncontrolled emissions for inventory year I
controlled emissions for inventory year I
control efficiency (percent)
Third, controlled emissions are recalculated incorporating rule effectiveness using Equation 4.4-4:
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CER.-UC. x
1-
100
100
EF
(Eq. 4.4-4)
BY I
where: CER;
UQ
REFF
CEFF
EF,
FF
JUi i
BY
controlled emissions incorporating rule effectiveness
uncontrolled emissions
rule effectiveness (percent)
control efficiency (percent)
emission factor for inventory year I
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
National Air Pollutant Emission Trends
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1985-1996 Methodology
Other Combustion
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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 4.4-1 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 fu6l
use. State-level sales volumes of residual fuel to the commercial sector were obtained from Fuel Oil and
Kerosene Sales J99016 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,
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the GCVTC inventory, and AIRS/FS. Sections 4.4.3.1, 4.4.3.2, and 4.4.3.3 give brief descriptions of
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:
South:
47.00 °N
26.00 °N
East:
West:
67.00°W
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
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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.)
4.4.3.1.2 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 Inventory17> 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 SEPs. 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 EGOS) 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-
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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 Equation 4.4-5
EMISSIONSASD = EMISSIONSANNUAL * SUMTHRU * 1/(13 * DPW)
(Eq. 4.4-5)
where:
EMISSIONS
EMISSIONS
SUMTHRU
DPW
ASD = average summer day emissions
ANNUAL = annual emissions
= summer throughput percentage
= 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.
EMISSIONS,Qn = EMISSIONS
JASD
ANNUAL
I (SUMFAC~cr * WDFAC«rr)
SCCJ
(Eq. 4.4-6)
where:
EMISSIONS
EMISSIONS
SUMFAC
WDFAC
ASD
ANNUAL
•sec
•sec
= average summer day emissions
= annual emissions
= default summer season temporal factor for SCC
= 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.
EMISSIONS
ASD
I 365
(Eq. 4.4-7)
where:
EMISSIONS
EMISSIONS
ASD
ANNUAL
= average summer day emissions
= 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 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.
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 PIPS 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:
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Year
1990
1991
1992
1993
1994
1995
1996
1992 PCE Deflator
93.6
97.3
100.0
102.6
104.9
107.6
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
Colorado - Mastercraft
Wisconsin - Briggs and Stratton
All VOC source emissions were re-extracted to obtain
emissions without rule effectiveness for the year 1994.
The VOC emissions were reported as ton/year in the initial
download from AIRS. The units were changed to
pounds/year in AIRS.
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.
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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
NOX RACT
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
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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:
CER1996~UC1995 X
GS
1996
GS
1995
100 J I 100 J UooJJ
(Eq. 4.4-8)
where:
CER1996
UC1995
GS
REEF
CEFF
RP
controlled emissions incorporating rule effectiveness
uncontrolled emissions
growth surrogate (either BEA or SEDS data)
rule effectiveness (percent)
control efficiency (percent)
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 (USDA) 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'u 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.
E = Activity x Fuel Loading x EF x UCF
(Eq. 4.4-9)
where: Esutc =
Activity =
Fuel Loading =
EF
UCF
annual state emissions (tons)
sum of DOI, USFS, and state and private land acres burned (acres)
average fuel loading for state (tons/acre)
emission factor (Ibs/ton)
unit conversion factor (1 ton 72,000 Ibs)
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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 Canvon States (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.
™ ^
SO Emissions =
x NO Emissions
NO. EF
(Eq. 4.4-10)
where: SO2 Emissions
S02EF
NOXEF
NOX Emissions
= annual county SO2 emissions (tons)
= AP-42 emission factor for SOX (Ibs/ton)
= AP-42 emission factor for NOX (Ibs/ton)
= annual NOX emissions (tons)
4.4.7.1.1.2 Grand Canvon 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.
County Emissions,
year
State Activity
year
State Activity 1990
x County Emissions
1990
(Eq. 4.4-11)
where: County Emissions^
State Activity
County Emissions1990
annual county emissions (tons)
DOI, state and private, and National Forest Lands burned (acres)
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-u Data from these three sources were summed to get the total acres burned for each state.
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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
POL
( NAPAPVOC}
(Eq. 4.4-12)
where: FSpoL = prescribed burning (NOX, CO, or SO2) emissions from Forest Service
FSVOC = prescribed burning VOC emissions from Forest Service
NAPAPpQL = 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:
I CF
Eyear = Activity x EF x 1 - _
(Eq. 4.4-13)
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where: Eyear
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
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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.
Adjusted Model
State hdd Total
year
year State hdd Total
x County Model
1990
(Eq. 4.4-14)
1990
where: Adjusted Model
State hdd Total
County Model
= county wood consumption (cords)
= total heating degree days (degrees Fahrenheit)
= 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.
Activity = Adjusted Model x
DOE
year
^Adjusted Model
year
(Eq. 4.4-15)
where: Activity
Adjusted Model
DOE
normalized county consumption (cords)
county wood consumption (cords)
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.
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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.
EmiSSi°nS
(county,SCCjear)
(county, SCC year) X Emission^county,SCC,^0) (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.
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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. AEROS Manual 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. 196S 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. n-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 II Emission 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
Procedures Document for 1900-1996
4-122
1985-1996 Methodology
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
Procedures Document for 1900-1996
4-123
1985-1996 Methodology
Other Combustion
-------
Table 4.4-1. Bureau of Economic Analysis's SA-5 National Changes in
Earnings by Industry
Percent Growth from:
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
-------
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
Res - Anthracite
Res - Bituminous
Res - Distillate oil
Zero growth
Res - Natural gas
Population
Comm - Anthracite
Comm - Bituminous
Gomm - 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
Residential 786
494
740
478
717
430
646
422
633
410
615
Bituminous Coal (thousand short tons)
Commercial 4,205
Residential 2,264
Distillate Fuel (thousand barrels)
Commercial 107,233
Residential 171,339
4,182
2,252
102,246
173,736
3,717
2,002
101,891
176,822
3,935
2,119
98,479
182,475
3,323
1,789
91,891
178,629
3,470
1,869
95,385
184,501
Motor Gasoline (thousand barrels)
All Sectors 2,493,361
Natural Gas (million cubic feet)
Commercial 2,432
Residential 4,433
Residual Fuel (thousand barrels)
Commercial 30,956
2,567,436 2,630,089 2,685,145 2,674,669 2,760,414
2,318
4,314
39,480
2,430
4,315
41,667
2,670
4,630
42,256
2,719
4,777
35,406
2,810
4,805
27,776
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-126
1985-1996 Methodology
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
StQtQ
Alabama
Arkansas
Connecticut
Delaware
District of Columbia
FlorWa
Goorgia - Atlanta
Urban Airshed (47
counties) domain
Georgia - Rest of
State
Illinois
Indiana
Kansas
Kentucky - Jefferson
County
Kentucky - Rest of
Slato
Louisiana
Maine
Maryland
Massachusetts
Michigan
Minnesota
Missouri
Nebraska
New Hampshire
Now Jersey
New York
North Carolina
North Dakota
Onto
Oklahoma
Pennsylvania -
Allegheny County
Pennsylvania -
Philadelphia County
Pennsylvania - Rest
of Slate
Rhode Island
Dst3 Sourcc/Formst
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 Workfiies
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
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
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
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
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 Year of
Resolution
bouth Carolina
South Dakota
Tennessee
Texas
Vermont
Virginia
West Virginia
Wisconsin
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State Format
State - EPS Workfile
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State Format
Annual
Annual
Annual
Daily
Daily
Annual
Annual
Daily
1991
1990
1990
1992
1990
1990
1990
1990
Average Summer Day estimated using default
temporal factors.
Average Summer Day estimated using
methodology described above.
Average Summer Day estimated using default
temporal factors.
Backcast to 1990 using BEA.
None
Average Summer Day estimated using
methodology described above.
Average Summer Day estimated using
methodology described above.
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
Cfnln
Connecticut
Delaware
District of Columbia
Florida
Georgia
Illinois
Indiana
Kentucky
Louisiana
Matne
Maryland
Michigan
Missouri
Now Hampshire
New Jersey
New York
North Carolina
Ddtd SourcG/Formst
State - EPS Workfiie
State - EPS Workfiie
State - Hard copy
AIRS-AMS - Ad hoc retrievals
State - State format
State - State format
State - State format
State - State Format
State - State Format
State - EPS Workfiie
State - EPS Workfiie
State - State Format
AIRS-AMS- Ad hoc retrievals
State - EPS Workfiie
State - EPS Workfiie
State - EPS Workfiie
State - EPS Workfiles
Temporal
Resolution
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Annual
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
St. Louis area (25 counties)
Entire State
Entire State
Entire State
Entire State
Adjustments to Data
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
Ohio
Pennsylvania
State - Hard copy
State - EPS Workfiie
Daily Canton, Cleveland Columbus,
Dayton, Toledo, and
Youngstown
Daily Entire State
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
Rhode Island
Tennessee
Texas
Vermont
Virginia
West Virginia
Wisconsin
State - EPS Workfiie
State - State format
State - State Format
State - EPS Workfiie
State - EPS Workfiie
AIRS-AMS - Ad hoc retrievals
State - State Format
Daily
Daily
Annual
Daily
Daily
Daily
Daily
Entire State
42 Counties in Middle
Tennessee
Entire State
Entire State
Entire State
Charleston, Huntington/
Ashland, and Parkersburg
(5 counties total)
Entire State
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
4-130
1985-1996 Methodology
Other Combustion
-------
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EMISSIONS
HI
Q
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O
CO
LU
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NUMBER HOUR,
Q
X
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Q
DEFAULT ESTIMATE
EMISSIONS UNITS
a
Q
PEAK OZONE
SEASON DAILY
PROCESS RATE
Q_
Q
o
Q.
X
CD
HI
X
LU
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JJ
LU
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NUMBER DAYS/1
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co
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u
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CO Z
co
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EFFICIENCY
LU
HI
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NUMBER
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PRIMARY CONTROL
DEVICE CODE
p
o
SECONDARY
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CODE
(M
o
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HI
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Emission factor
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in
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-131
1985-1996 Methodology
Other Combustion
-------
Table 4.4-8. SEDS National Fuel Consumption, 1990-1996 (trillion Btu)
FuelTvoe 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
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
LNUM
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
SIC
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
1990
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
1991
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
1992
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
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
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
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
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-133
1985-1996 Methodology
Other Combustion
-------
Table 4.4-9 (continued)
LNUM
SIC
1990 1991 1992 1993 1994 1995 1996
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
Eleclric, gas, and sanitary services
Wholesale trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Retail trade
Rota!! 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
Fedora!, civilian
Federal, military-
State and local
State and local
State and local
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
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
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
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
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
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
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
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
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
4-134
1985-1996 Methodology
Other Combustion
-------
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
21 99006000
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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-135
1985-1996 Methodology
Other Combustion
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-136
1985-1996 Methodology
Other Combustion
-------
Table 4.4-12. NOX and VOC Major Stationary Source Definition
Ozone Nonattainment Status Maior Stationary Source (tons)
Marginal/Moderate
Serious
Severe
Extreme
Ozone Transport Region
100
50
25
10
50
Pod
ID
Table 4.4-13. Summary of Revised NOX Control Efficiencies
Pod Name
Estimated
Efficiency
Control
58 Commercial/Institutional - Coal
59 Commercial/Institutional - Oil
60 Commercial/Institutional - Gas
50
50
50
LNB
LNB
LNB
Controls: LNB - Low NOX Burner
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-137
1985-1996 Methodology
Other Combustion
-------
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-138
1985-1996 Methodology
Other Combustion
-------
Table 4.4-15. Emission Factors for Residential Wood Combustion by Pollutant
Pollutant
CO
NOX
VOC
SO2
PM-10a
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 .628 E-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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-139
1985-1996 Methodology
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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 n categories:
Tier I Category
(08) SOLVENT UTILIZATION
Tier n Category
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 AJDRS/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
emissions (by end-use =
category)
National solvent
consumption
Solvents destroyed by
air pollution controls
Solvents conveyed to
waste management
operations
(Eq. 4.5-1)
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:
County emissions
(by end-use
category)
National
emissions
County employment
National
employment
Estimated control efficiency for
county
Nationwide average control
efficiency for category
(Eq. 4.5-2)
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
emissions (by end-use =
category)
Total county-level
emissions (equation 2)
County-level point source
emissions
(Eq. 4.5-3)
The AJDRS/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.
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All County National
^2 Area Source = Total
Emissions Emissions
National
- Point Source
Emissions
(Eq. 4.5-4)
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 = CE + (CEBY x
BY
(Eq. 4.5-5)
where: CES
= controlled emissions for inventory year i
= controlled emissions for base year
= earnings growth for inventory year i
Earnings growth is calculated using Equation 4.5-6.
DAT.
EG; = 1-
DAT,
(Eq. 4.5-6)
BY
where: EGj = earnings growth for year i
DATj = 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:
UE, =
CE,
j _ CEFF]
100 J
(Eq. 4.5-7)
where:
CEFF =
uncontrolled emissions for inventory year i
controlled emissions for inventory year i
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. x
_ ( REFF} (CEFF\
I I ^ I 1
I 100 100
(Eq. 4.5-8)
where: CER; = controlled emissions incorporating rule effectiveness
UC; = 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 S A-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
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
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:
South:
47.00 °N
26.00 °N
East:
West:
67.00°W
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 (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 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 EGOS) 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.
EMISSIONS,«„ = EMISSIONS
JASD
ANNUAL
* SUMTHRU * 1/(13 * DPW)
(Eq. 4.5-10)
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where: EMISSIONS
EMISSIONS
SUMTHRU
DPW
'ASD
ANNUAL
= average summer day emissions
= annual emissions
= summer throughput percentage
= 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.
EMISSIONS
ASD
(SUMFACSCC * WDFAC8CC)
(Eq. 4.5-11)
where: EMISSIONS
EMISSIONS
SUMFAC
WDFAC
'ASD
ANNUAL
•sec
•sec
average summer day emissions
annual emissions
default summer season temporal factor for SCC
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.
EMISSIONS^ = EMISSIONS^^ I 365
(eq. 4.5-12)
where: EMISSIONS
EMISSIONS
ASD
ANNUAL
= average summer day emissions
= 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. L4.S 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 SO^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
National Air Pollutant Emission Trends
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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
1990
1991
1992
1993
1994
1995
1996
1992 PCE Deflator
93.6
97.3
100.0
102.6
104.9
107.6
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.
Emissi°nS(county,SCCjear) = Gr°Wth(county,SCCjear) X Emissi°nS(county,SCC,W90) (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
Colorado - Mastercraft
All VOC source emissions were re-extracted to obtain
emissions without rule effectiveness for the year 1994.
The VOC emissions were reported as ton/year in the initial
download from AIRS. The units were changed to
pounds/year in AIRS.
National Air Pollutant Emission Trends
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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.
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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.
UC19S5 X
GS.
1996
GS
1995
- ( REFF} (CEFF] J RP'
( 100 J ( 100 J ( 100;
(Eq. 4.5-14)
where: CER
1996
GS
REFF
CEFF
RP
controlled emissions incorporating rule effectiveness
uncontrolled emissions
growth surrogate (either BEA or SEDS data)
rule effectiveness (percent)
control efficiency (percent)
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 El 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 4,5-11 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
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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 in maximum achievable control technology (MACT)
standards were identified by using EPA's timetable for regulation development under Title EL23
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 ffl 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
Procedures Document for 1900-1996
4-156
1985-1996 Methodology
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-600/8-8 8-106, 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. H-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, and NOx 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 (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.
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
Procedures Document for 1900-1996
4-157
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
(DHDEC), 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.
Hatlonal Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-158
1985-1996 Methodology
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Table 4.5-1. National Material Balance for Solvent Emissions
Category Description
Surface Coating
2401001 Architectural
2401005 Auto refinishing
2401008 Traffic markings
2401 015 Flat wood coating
2401 020 Wood furniture
2401025 Metal furniture
240 1 030 Paper coating
2401040 Can coating
2401045 Coil coating
2401055 Electrical insulation
2401060 Appliances
2401 065 Machinery
240 1 070 Motor vehicles (new)
2401075 Aircraft coating
2401080 Marine paints
2401085 Rail equip, coating
2401090 Misc. manufacturing
2401100 Industrial maintenance
2401200 Aerosols, spec, purpose
Vapor Degreasing (Conveyorized and
2415105 Furniture
241 51 1 0 Metallurgical proc.
2415120 Fabricated metals
2415125 Industrial machinery
2415130 Electrical equipment
2415135 Transportation equip.
241 51 40 Instrument mfg.
2415145 Misc. manufacturing
Cold Cleaner Degreasing
2415305 Furniture
2415310 Metallurgical proc.
2415320 Fabricated metals
2415325 Industrial machinery
2415330 Electrical equipment
2415335 Transportation equip.
2415340 Instruments
2415345 ' Misc. manufacturing
2415355 Automobile dealers
241 5360 Automobile repair
2415365 Other
Other Categories
2420010 Drycleaning (perc.)
2420010 Drycleaning (petroleum)
2420020 Coin-op drycleaning
2425000 Graphic arts
2430000 Rubber/plastics
2440020 Adhesives - industrial
2461021 Cutback asphalt
2461 800 Pesticides - farm
2465100 Personal products
2465200 Household products
2465400 Automotive products
2465600 Adhesives - Comml.
'Based on the 1985 NEDS methodology.
Solvent
Usage
d.OOOtpy)
503
133
106
5
221
70
33
156
58
48
34
130
134
11
29
6
210
99
173
Open-Top)
9
29
97
100
98
36
48
17
12
8
38
52
16
12
8
19
191
70
5
135
134
2
276
48
460
200
260
228
186
650
350
Percent
Destroyed by
Air Pollution
Controls1
0
0
0
16
16
16
16
16
16
16
16
16
16
16
16
16
16
0
0
0
0
0
0
0
o •
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
16
16
0
0
0
0
0
0
0
Percent Sent
to TSDFs2
0
0
0
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
0
0
0
0
0
0
Estimated
Emissions
(1,000 tpy)
503
133
106
3
139
44
21
99
37
30
21
82
85
7
18
4
132
78
137
7
23
76
79
77
28
38
13
9
7
30
41
12
9
6
15
151
55
4
107
105
1
174
30
363
200
260
228
186
650
350
Source
SRI International/
National Paint and
Coatings Institute
Total category
number from Frost
& Sullivan.
Industry
breakdowns from
EPA BOAT Report
for spent solvents.
Total category
number from Frost
& Sullivan.
Industry
breakdowns from
EPA BOAT Report
for spent solvents.
Frost & Sullivan
Frost & Sullivan
Frost & Sullivan
Frost & Sullivan
Frost & Sullivan
Freedonia Group
Asphalt Institute
Freedonia Group
Frost & Sullivan
Frost & Sullivan
Freedonia Group
Frost & Sullivan
Does not include solvents that are captured and recycled.
2CalculateB 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
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Table 4.5-2. Data Bases Used for County Allocation
AMS
Category
Surface Coating
2401 OO1
2401005
2401008
2401015
2401020
2401025
2401030
2401040
2401045
2401055
2401060
2401065
2401070
2401075
2401080
2401085
2401090
2401100
24O1 200
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
241 51 45
Cold Cleaner Degreasing
241 5305
2415310
2415320
2415325
241 5330
241 5335
2415340
2415345
2415355
241 5360
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.)
On/cleaning (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 7216
Employment in SIC 7216
Employment in SIC 7215
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
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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 Data Source/Format
Alabama AIRS-AFS - Ad hoc retrievals
Arkansas AIRS-AFS - Ad hoc retrievals
Connecticut State - EPS Workfile
Delaware State - EPS Workfile
District of Columbia AIRS-AFS - Ad hoc retrievals
Florida AIRS-AFS - Ad hoc retrievals
Georgia - Atlanta State - State format
Urban Airshed (47
counties} domain
Georgia • Rest of AIRS-AFS - Ad hoc retrievals
State
Illinois State- EPS Workfiies
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
Mafne 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 Workfiies
North Dakota AIRS-AFS - Ad hoc retrievals
Onto State - State Format
Oklahoma State - State Format
Pennsylvania - _ Allegheny County - County Format
Allegheny County
Pennsylvania - Philadelphia County - County Format
Philadelphia County
Pennsylvania - Rest State - EPS Workfile
of State
Rhode Island State - EPS Workfile
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
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
Adjustments to Data
Backcastto 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-162
1985-1996 Methodology
Solvent Utilization
-------
State
Table 4.5-4 (continued)
Data Source/Format
Temporal Year of
Resolution
Afiil letmpnfc tn nota
South Carolina
South Dakota
Tennessee
Texas
Vermont
Virginia
West Virginia
Wisconsin
AiRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State Format
State - EPS Workfiie
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State Format
Annual 1991 Average Summer Day estimated using default
temporal factors.
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
Clatf*
Connecticut
Delaware
District cl Columbia
Florida
Georgia
Illinois
Indiana
Kentucky
Louisiana
Malna
Maryland
Michigan
Missouri
Now Hampshire
Now Jersey
Now York
North Carolina
Ohio
Pennsylvania
Rhode Island
Tennessee
Texas
Vermont
Virginia
West Virginia
Wisconsin
Ddts SourcG/Formst
State - EPS Workfile
State - EPS Workfile
Stale - Hard copy
AIRS-AMS - 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
AIRS-AMS- Ad hoc retrievals
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 - State Format
State - EPS Workfile
State - EPS Workfile
AIRS-AMS - Ad hoc retrievals
State - State Format
Temporal
Resolution
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Annual
Daily
Daily
Daily
Daily
Annual
Daily
Daily
Daily
Daily
Geoaraohic Coveraae
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
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
Adiustments 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
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
-------
O
Q.
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Segment Output
General
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DESIGN CAPA
UNITS
L.
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8
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WINTER
THROUGHPUT
l
^
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HI
^
Z
J
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_
Q_
HI
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POLLUTANT CODE
3
a.
HEAT CONTENT
j—
LU
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r
n
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v^
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cc
J-
o
NUMBER
HOURS/DAY
Q
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DEFAULT
ESTIMATED
EMISSIONS UNITS
HI
Q
PEAK OZONE
SEASON DAILY
PROCESS RATE
a.
Q
O
3_
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0
HI
X
LU
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1.
^
NUMBER
DAYS/WEEK
^
D
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r^
CO
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: DC
i! DQ
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CO
CO
CONTROL
EFFICIENCY
HI
HI
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NUMBER
HOURS/YEAR
r
o
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PRIMARY CONTRO
DEVICE CODE
F
o
SECONDARY
CONTROL DEVICE
CODE
h-
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RULE
EFFECTIVENESS
METHOD CODE
2 3
HI 2
DC Q
HI
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-165
1985-1996 Methodology
Solvent Utilization
-------
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
Procedures Document for 1900-1996
4-166
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-8. BEA SA-5 National Earnings by Industry, 1990-1996 (million $)
Industrv
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
Railroad transportation
LNUM
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
510
SIC
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
40
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
12
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
12
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
13
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
12
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
12
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
12
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
12
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-167
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-8 (continued)
LNUM
SIC
1990 1991 1992 1993 1994 1995 1996
Trucking and warehousing
Water transportation
Water transportation
Local and inlorurban 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
Rota!) trade
Retail trade
Retail trade
RotaH trade
Retail trade
Retai 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
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
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
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
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
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
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
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
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
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
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-169
1985-1996 Methodology
Solvent Utilization
-------
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Table 4.5-12. Point Source SCC to Pod Match-up
pon
POD sec
POD sec
POD SCCL
POD
40100101
40100102
40100103
40100104
40100105
40100198
40100201
40100202
40100203
40100204
40100205
40100206
40100207
40100221
40100222
40100223
401CJ0224
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
91
92
91
92
93
93
61
65
65
65
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
63
63
40188898
40199999
40200101
40200110
40200301
40200310
40200401
40200410
40200501
40200510
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
40201404
40201405
63
63
33
33
34
34
33
40
33
33
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
37
37
40201505
40201531
40201599
40201601
40201602
40201603
40201604
40201605
40201606
40201607
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
40201803
40201805
37
37
37
33
33
33
33
33
33
33
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
37
37
40202031
40202033
40202099
40202101
40202103
40202104
40202105
40202106
40202107
40202108
40202109
40202131
40202132
40202133
40202199
40202201
40202202
40202203
40202205
40202299
40202301
40202302
40202305
40202306
40202399
40202401
40202402
40202403
40202405
40202406
40202499
40202501
40202502
40202503
40202504
40202505
40202531
40202532
40202533
40202534
40202537
40202598
40202599
40202601
40202605
37
37
37
40
40
40
40
40
40
40
40
40
40
40
40
38
38
38
38
38
132
132
132
132
132
52
52
52
52
52
52
37
37
37
37
37
37
37
37
37
37
37
37
37
37
4050021 1
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
40500510
4050051 1
40500512
40500513
40500514
40500598
40500599
40500601
40500701
40500801
4050081 1
40500812
40588801
40588802
40588803
40588804
40588805
49000101
49000103
49000105
49000199
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
J>OD SCC
POD SCC
POD
pnn
40100335
40100336
40100398
40100399
40100499
40100550
40188801
40188802
40188805
49000499
49000501
6340201406
6340201431
6340201432
6340201433
6340201435
6340201499
63 40201.501
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 85
37 49000202 85
37 49000203 85
88 49000204 85
18949000205 85
18949000206 85
18049000299 85
18649000399 85
18649000401 85
85 49099999 85
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-173
1985-1996 Methodology
Solvent Utilization
-------
Table 4.5-13. Area Source VOC Controls by SCC and Pod
POD
211
211
241
241
241
241
241
241
241
241
241
241
241
250
251
272
272
POD VOC
211
241
250
251
272
SCC SOURCE
2420010055 Dry Cleaning - perchloroethylene
2420000055 Dry Cleaning - perchloroethylene
2415305000 Cold cleaning
241 531 0000 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
2461 021 000 Cutback Asphalt
2461 020000 Cutback Asphalt
PODNAME
Dry Cleaning - perchloroethylene
Cold cleaning
Aircraft surface coating
marine surface coating
Cutback Asohalt
MEASURE
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
Marainal+
PCTRD96
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: 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 n categories:
Tier I Category Tier n 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 MOBILE5a for the years 1970 to
1994 andMOBILESb 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-175
1985-1996 Methodology
On-road Vehicles
-------
road systems. The data that make up HPMS are submitted to FHWA annually by each state highway
program.
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-176
1985-1996 Methodology
On-road Vehicles
-------
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
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.
POP
R,S
X
R,C
POP
R,S
(Eq. 4.6-1)
where: VMTRC =
VMTp' .=
POP,
POP
R,S
R,C
'R,S
Rural VMT in county C (calculated)
Rural VMT, state total (HPMS)
Rural population in county C (CNOI)
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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-177
1985-1996 Methodology
On-road Vehicles
-------
VMT,
su.c
= VMT,
POP.
su,c
su,s
POP,
(Eq. 4.6-2)
su,s
where: VMT,
VMT,
su,c
lsu,s
POPSU>C
POPSU.S
= Small urban VMT in county C (calculated)
= Small urban VMT, state total (HPMS)
= Small urban population in county C (CNOI)
= Small urban population, state total (CNOI)
4.6.1.23 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.
VMTUA>C = VMTUA>S x
POP
UA.C
POP
(Eq. 4.6-3)
UA,S
where: VMTUAtC
VMTUA,S
POP,
POP,
UA.C
UA.S
= Urban area's VMT in county C (calculated)
= Urban area's VMT, state total (HPMS)
= Urban area's population in county C (CNOI)
= 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
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vehicles types: passenger cars, motorcycles, buses, two-axle/four-tire single-unit trucks, other single-unit
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.
TRVMT96
= TRVMT95
(Eq. 4.6-4)
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where: TRVMT96
'S,C,RT,VT
TRVMT95SiCRTiVT
FHVMT96S>RT
TRVMT95S,RT
Trends 1996 VMT for State S, county C, roadway type RT, and
vehicle type VT (millions of miles per year);
Trends 1995 VMT for State S, county C, roadway type RT, and
vehicle type VT (millions of miles per year);
Federal Highway Administration preliminary 1996 VMT for State S
and roadway type RT (millions of miles per year); and
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(R1/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.L4 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 MOBUJESa 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 MOBELESa for the years 1970 through 1994 and MOBILESb 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 YMT 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. Jjn
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 (QMS)
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 (MS As) 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
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summer 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 MOBJJLE4
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 MOBTJLE4 User's Guide also lists RVP limits that correspond to each ASTM class. These RVP
limits are as follows:
ASTM class A
ASTM class B
ASTM class C
ASTM class D
ASTM class E
9.0
10.0
11.5
13.5
15.0
psi
psi
psi
psi
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 = [CM - SA) x (WM - SM) I (WA - SA)] + SM
(Eq. 4.6-5)
where: IM
WM
SM
IA
WA
SA
Intermediate month's (not January or July) RVP value
Winter (January) RVP value
Summer (July) RVP value
Intermediate month's (not-January or July) ASTM RVP limit
Winter (January) ASTM RVP limit
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 E 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 H (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, QMS 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 RVP 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.! 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 (JJDGVs), 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 [tracks
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 MOBILESb.
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
MOBILESb 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 199611 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.
Model YearN Cars in Operation in Year1996= A x —
B
(Eq. 4.6-6)
where: A
B
C
Year
N
AAMA number of Model YearN Cars Operating in YearY
Survival rate for ageY.N
Survival rate for age1996.N
Last calendar year for which an estimate is available for this particular model
year (as of July 1)
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 Tallinn wm 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 MOBILESb 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
MOBILESb. 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 MOBILESb 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\0_6000lbs)- Diesel Factory Sales (0-6)0oo/6s) (Eq. 4.6-7)
LDGT2 =
Sales
Diesel \
- VCC - M - (0.05 x CP) - Factory
Sales ) (6)0oo-io,ooo#>s)
(Eq. 4.6-8)
where: VCC
M
CP-
= Retail sales of van cutaway chassis
= Retail sales of multi-stops
= Retail sales of conventional pickups
HDGT =
M + [0.05 x CP])(6,000,0>OOOZ6s) -
(>10,mbs)
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LDDT = DieselFactorySales(Q_6flmlbs) + (O.lOx Diesel Factory Sales\ei000_w>QQQlbs) (Eq. 4.6-10)
HDDT = [0.9 x (DieselFactorySales}^^^^ + 2 (Diesel Factory Sales\>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 MOBUJBSb 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.
)90 Model Year LDGTls
Operating in 1995
Total Model Year 1990
Trucks Operating in 1995
1990 Model Year LDGTls Sold
Total 1990 Model Year Trucks So,(Eq'
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
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the 1995 model year trucks would not have been sold by the end of the 1995 calendar year. Therefore,
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 PARTS 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 by PARTS.
Truck Class
Data Used to Calculate Truck Sales
2B HDDVs
Light HDDVs
Medium HDDVs
Heavy HDDVs
Buses
0.90 *U.S. Factory Sales of Diesel Trucks 6,001 to 10,000 Ib GVWR
U.S. Factory Sales of Diesel Trucks 10,001 to 19,500 Ib GVWR
U.S. Factory Sales of Diesel Trucks 19,501 to 33,000 Ib GVWR
U.S. Factory Sales of Diesel Trucks.33,001 Ib GVWR - Factory Bus Sales
Factory Bus Sales
Registration distributions input to MOBILESa 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 MOBJJLESa 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 MOBTJJBSb 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 MSAs. 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, sinee they were all created for use with MOBILE. To use the state-supplied distributions in
PARTS, the HDDV distributions were replicated for each of the PARTS HDDV subcategories.
Figure 4.6-1 shows each state-supplied registration distribution used in the Trends modeling, in
MOBELESb 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 MOBILESb 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 QMS showing
the basic characteristics of I/M programs planned by the states,17 past QMS 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 JVM 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
QMS. 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. J7M 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
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MOBILE5 inputs varied by state based on the characteristics of representative I/M programs in that state.
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 QMS 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 MOBHESb 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 MOBILESb 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 1
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
NO,
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
QMS. 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
JNEWFLG 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
NOV
DR
ZML (g/bhp-hr/10k
(g/bhp-hr) mi)
3.19 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
MOBEJESa, 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 reformulaterf-gasoline program in California.
Using CALI5, this was modeled in the summer months for 1995 by setting the reformulated gasoline
flag to "4". Phase n 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
CALK 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 CALK
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 CALK.
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 PARTS 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 PARTS emission factors are generated, the PARTS 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 Survey*1 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 PARTS. 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. PARTS 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 PARTS. These emission factors calculated within PARTS 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 PARTS 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.21 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 PART5. 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 MOBHJE5a 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 MOBILE5a 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.
= SULFCONTy>z x 0.98 x FUELDENSZ x 453.59 x FUELECQN (Eq. 4.6-13)
where: SO,EFY
SULFCONT,
FUELDENS;
FUELECON.
y.z
x,y
= SO2 emission factor for vehicle type x in year y (grams per mile)
= Sulfur content in year y for fuel type z (fractional value)
= Fuel density of fuel type z (pounds per gallon)
= 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
SOj25 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(HS\
(Eq. 4.6-14)
where: FEr
FE(HS)x>y
FE(FCM)X,1982
FE(HS)
'x.1982
Fuel economy value for vehicle type x in year y used SO2 emission
factor calculations (mpg)
Highway Statistics fuel economy for vehicle type x in year y (mpg)
MOBILE4.1 Fuel Consumption Model fuel economy for vehicle type
x in 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 MOBEJE4.1
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
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Using the NH3 emission factors listed above, emission factors by vehicle type and model year were
calculated using MOBILE5b 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 MOBILE5b 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
MOBILESb pollutants (VOC, NOX, and CO) were calculated with emission factors and VMT at the
month, county, roadway type, and vehicle type (for the eight MOBILESb vehicle types) level of detail.
The emission factors for the PARTS 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 PARTS 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-
Naiional Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-198
1985-1996 Methodology
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," ASCH 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
Procedures Document for 1900-1996
4-199
1985-1996 Methodology
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
Procedures Document for 1900-1996
4-200
1985-1996 Methodology
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. "MOBDLE4.1 Fuel Consumption Model (Draft)," U.S. Environmental Protection Agency, Office of
Mobile Sources, Ann Arbor, MI, August 1991.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-201
1985-1996 Methodology
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
Areawide - Sta^Sjjmmarjes
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 far 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
Motorcycle
Passenger Car
Other 2-Axle, 4-tire
Buses
Other Single Unit Trucks
Combination Trucks
MOBILESa
MC
LDGV
LDDV
LDGT1
LDGT2
LDDT
HDGV
HDDV
HDGV
HDDV
HDDV
Vehicle Type Category and Apportionment Percentages
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
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-204
1985-1996 Methodology
Solvent Utilization
-------
Table 4.6-4. 1995 to 1996 VMT Growth Factors by State and Roadway Type
State
Rural Roadway Type
Growth
Factoi
Urban Roadway Type
Growth
Factor
Alabama INTERSTATE 1.02
Alabama OTHER PRINCIPAL ARTERIAL 0.986
Alabama MINOR ARTERIAL 1.005
Alabama MAJOR COLLECTOR 1.03;
Alabama MINOR COLLECTOR 0.999
Alabama LOCAL 1.005
Alaska INTERSTATE 0.993
Alaska OTHER PRINCIPAL ARTERIAL 0.991
Alaska MINOR ARTERIAL 1.026
Alaska MAJOR COLLECTOR 1.02;
Alaska MINOR COLLECTOR 1.001
Alaska LOCAL 1.007
Arizona INTERSTATE 1.023
Arizona OTHER PRINCIPAL ARTERIAL 0.981
Arizona MINOR ARTERIAL 1.006
Arizona MAJOR COLLECTOR 1.011
Arizona MINOR COLLECTOR 1.017
Arizona LOCAL 1.013
Arkansas INTERSTATE 1.033
Arkansas OTHER PRINCIPAL ARTERIAL 1.028
Arkansas MINOR ARTERIAL 1.011
Arkansas MAJOR COLLECTOR 1.009
Arkansas MINOR COLLECTOR 0.970
"Arkansas LOCAL 1.012
California INTERSTATE 1.041
California OTHER PRINCIPAL ARTERIAL 1.009
California MINOR ARTERIAL 1.028
California MAJOR COLLECTOR 1.028
California MINOR COLLECTOR 1.028
California LOCAL 1.028
Colorado INTERSTATE 1.034
Colorado OTHER PRINCIPAL ARTERIAL 1.010
Colorado MINOR ARTERIAL 1.025
Colorado MAJOR COLLECTOR 0.977
Colorado MINOR COLLECTOR 1.020
Colorado LOCAL 1.013
Connecticut INTERSTATE 1.029
Connecticut OTHER PRINCIPAL ARTERIAL 1.026
Connecticut MINOR ARTERIAL 1.014
Connecticut MAJOR COLLECTOR 0.986
Connecticut MINOR COLLECTOR 1.016
Connecticut LOCAL 1.016
DC - INTERSTATE NA
DC OTHER PRINCIPAL ARTERIAL NA
DC MINOR ARTERIAL NA
DC MAJOR COLLECTOR NA
DC MINOR COLLECTOR NA
DC LOCAL NA
INTERSTATE . 1.000
OTH FREEWAYS & EXPRESSWAYS 1.006
OTHER PRINCIPAL ARTERIAL 0.999
MINOR ARTERIAL 0.989
COLLECTOR 0.983
LOCAL 1.005
INTERSTATE 1.018
OTH FREEWAYS & EXPRESSWAYS NA
OTHER PRINCIPAL ARTERIAL 1.010
MINOR ARTERIAL 0.993
COLLECTOR . 1.046
LOCAL 1.008
INTERSTATE 1.013
OTH FREEWAYS & EXPRESSWAYS 1.031
OTHER PRINCIPAL ARTERIAL 1.015
MINOR ARTERIAL 1.014
OLLECTOR . 1.015
LOCAL 1.015
INTERSTATE 1.009
OTH FREEWAYS & EXPRESSWAYS 1.031
OTHER PRINCIPAL ARTERIAL 1.005
MINOR ARTERIAL 1.024
OLLECTOR 1.028
LOCAL 1.017
NTERSTATE 1.023
OTH FREEWAYS-& EXPRESSWAYS 1.033
OTHER PRINCIPAL ARTERIAL 1.028
MINOR ARTERIAL 1.028
OLLECTOR 1.028
LOCAL 1.028
NTERSTATE 1.032
OTH FREEWAYS & EXPRESSWAYS 1.063
OTHER PRINCIPAL ARTERIAL 1.006
MINOR ARTERIAL 1.015
OLLECTOR 1.001
LOCAL 1.003
NTERSTATE 1.012
OTH FREEWAYS & EXPRESSWAYS 1.001
OTHER PRINCIPAL ARTERIAL 1.036
MINOR ARTERIAL 1.015
OLLECTOR 1.016
LOCAL 1.016
NTERSTATE 1.041
OTH FREEWAYS & EXPRESSWAYS 0.956
OTHER PRiNGIEAL ARTERIAL 0.969
MINOR ARTERIAL 0.983
OLLECTOR 0.985
LOCAL 0.987
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-205
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Rural Roadway Type
Growth
Factor
Urban Roadway Type
Growth
Factor
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
Iowa
Iowa
Iowa
INTERSTATE NA
OTHER PRINCIPAL ARTERIAL 1.015
MINOR ARTERIAL 1.001
MAJOR COLLECTOR 1.007
MINOR COLLECTOR 1.036
LOCAL 1.011
INTERSTATE 1.041
OTHER PRINCIPAL ARTERIAL 1.010
MINOR ARTERIAL 1.030
MAJOR COLLECTOR 1.009
MINOR COLLECTOR 1.031
LOCAL 1.028
INTERSTATE 1.041
OTHER PRINCIPAL ARTERIAL 1.044
MINOR ARTERIAL 1.047
MAJOR COLLECTOR 1.029
MINOR COLLECTOR 1.010
LOCAL 1.057
INTERSTATE NA
OTHER PRINCIPAL ARTERIAL 0.971
MINOR ARTERIAL 1.018
MAJOR COLLECTOR 0.980
MINOR COLLECTOR 0.984
LOCAL 0.981
INTERSTATE 1.022
OTHER PRINCIPAL ARTERIAL 0.999
MINOR ARTERIAL 1.015
MAJOR COLLECTOR 1.025
MINOR COLLECTOR 1.012
LOCAL 1.013
INTERSTATE 1.021
OTHER PRINCIPAL ARTERIAL 1.042
MINOR ARTERIAL 1.014
MAJOR COLLECTOR 0.997
MINOR COLLECTOR 1.018
LOCAL 1.019
INTERSTATE 1.001
OTHER PRINCIPAL ARTERIAL 1.004
MINOR ARTERIAL 1.006
MAJOR COLLECTOR 0.998
MINOR COLLECTOR 1.001
LOCAL 1.001
INTERSTATE 1.020
OTHER PRINCIPAL ARTERIAL 1.024
MINOR ARTERIAL 1.009
MAJOR COLLECTOR 1.009
MINOR COLLECTOR 1.036
LOCAL 0.913
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
LOCAL
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
0.991
1.090
1.001
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-206
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Rural Roadway Type
Growtl
Facto
Urban Roadway Type
Growth
Factor
Kansas INTERSTATE 1.03.
Kansas OTHER PRINCIPAL ARTERIAL 1.02:
Kansas MINOR ARTERIAL 1.00!
Kansas MAJOR COLLECTOR 0.98!
Kansas MINOR COLLECTOR - 1.012
Kansas LOCAL 1.01
Kentucky INTERSTATE 1.03(
Kentucky OTHER PRINCIPAL ARTERIAL 1.012
Kentucky MINOR ARTERIAL 1.005
Kentucky MAJOR COLLECTOR 1.013
Kentucky MINOR COLLECTOR 1.018
Kentucky LOCAL 1.015
Louisiana INTERSTATE 1.043
Louisiana OTHER PRINCIPAL ARTERIAL 1.050
Louisiana MINOR ARTERIAL 1.03
Louisiana MAJOR COLLECTOR 1.01
Louisiana MINOR COLLECTOR 1.046
Louisiana LOCAL 1.022
Maine INTERSTATE 1.035
Maine OTHER PRINCIPAL ARTERIAL 1.01
Maine MINOR ARTERIAL 1.011
Maine MAJOR COLLECTOR 1.01
Maine MINOR COLLECTOR 1.028
• Maine LOCAL 1.034
Maryland INTERSTATE 1.01
Maryland OTHER PRINCIPAL ARTERIAL 1.018
Maryland MINOR ARTERIAL 1.007
Maryland MAJOR COLLECTOR 1.021
Maryland MINOR COLLECTOR 1.061
Maryland LOCAL 1.016
Massachusetts INTERSTATE 1.028
Massachusetts OTHER PRINCIPAL ARTERIAL 1.012
Massachusetts MINOR ARTERIAL 0.992
Massachusetts MAJOR COLLECTOR 1.015
Massachusetts MINOR COLLECTOR 1.013
Massachusetts LOCAL 1.014
Michigan INTERSTATE 1.013
Michigan OTHER PRINCIPAL ARTERIAL 1.013
Michigan MINOR ARTERIAL 1.015
Michigan MAJOR COLLECTOR 1.014
Michigan MINOR COLLECTOR 1.001
Michigan LOCAL 1.001
Minnesota . INTERSTATE 1.012
Minnesota OTHER PRINCIPAL ARTERIAL 1.022
Minnesota MINOR ARTERIAL 1.016
Minnesota MAJOR COLLECTOR 1.002
Minnesota MINOR COLLECTOR 1.015
Minnesota LOCAL 0.988
INTERSTATE 1.041
OTH FREEWAYS & EXPRESSWAYS 1.091
OTHER PRINCIPAL ARTERIAL 0.996
MINOR ARTERIAL 0.991
COLLECTOR 0.947
LOCAL 0.956
INTERSTATE 1.016
OTH FREEWAYS .& EXPRESSWAYS 0.991
OTHER PRINCIPAL ARTERIAL 1.025
MINOR ARTERIAL 1.006
SOLLECTOR 0.992
LOCAL . 1.009
NTERSTATE ' 1.023
OTH FREEWAYS & EXPRESSWAYS 1.029
OTHER PRINCIPAL ARTERIAL 1.013
MINOR ARTERIAL 1.043
IOLLECTOR 1.007
LOCAL -.- 1.029
NTERSTATE ' 1.039
OTH FREEWAYS & EXPRESSWAYS 0.998
OTHER PRINCIPAL ARTERIAL 1.000
MINOR ARTERIAL 1.000
OLLECTOR 1.062
LOCAL 1.021
NTERSTATE 1.016
OTH FREEWAYS & EXPRESSWAYS 1.021
OTHER PRINCIPAL ARTERIAL 1.009
MINOR ARTERIAL 1.016
COLLECTOR 0.998
LOCAL 1.016
NTERSTATE 1.015
OTH FREEWAYS & EXPRESSWAYS 1.020
OTHER PRINCIPAL ARTERIAL 1.022
MINOR ARTERIAL 1.000
'OLLECTOR 1.015
LOCAL 1.014
NTERSTATE 1.010
OTH FREEWAYS & EXPRESSWAYS 1.001
OTHER PRINCIPAL ARTERIAL 0.965
rflNOR ARTERIAL 1.021
COLLECTOR 1.001
OCAL . 0.960
NTERSTATE 1.025
OTH FREEWAYS & EXPRESSWAYS 1.010
DTHER PRINCIPAL ARTERIAL 1.013
i/llNOR ARTERIAL 1.014
:OLLECTOR 1.026
OCAL 1.018
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-207
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Rural Roadway Type
Growth
Factor
Urban Roadway Type
Growth
Factor
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
Now Hampshire
Now Hampshire
Now Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Jersey
New Mexico .
New Mexico
New Mexico
New Mexico
New Mexico
New Mexico
INTERSTATE 1.042
OTHER PRINCIPAL ARTERIAL 1.044
MINOR ARTERIAL 0.999
MAJOR COLLECTOR 0.983
MINOR COLLECTOR 1.018
LOCAL 1.021
INTERSTATE 1.042
OTHER PRINCIPAL ARTERIAL 1.029
MINOR ARTERIAL 1.004
MAJOR COLLECTOR 1.022
MINOR COLLECTOR 1.016
LOCAL 1.016
INTERSTATE 0.981
OTHER PRINCIPAL ARTERIAL 0.998
MINOR ARTERIAL 0.997
MAJOR COLLECTOR 1.013
MINOR COLLECTOR 1.000
LOCAL 1.044
INTERSTATE 1.042
OTHER PRINCIPAL ARTERIAL 0.998
MINOR ARTERIAL 1.040
MAJOR COLLECTOR 0.958
MINOR COLLECTOR 0.969
LOCAL 1.022
INTERSTATE 1.022
OTHER PRINCIPAL ARTERIAL 0.981
MINOR ARTERIAL 1.071
MAJOR COLLECTOR 1.076
MINOR COLLECTOR 1.014
LOCAL 1.014
INTERSTATE 1.031
OTHER PRINCIPAL ARTERIAL 1.027
MINOR ARTERIAL 0.997
MAJOR COLLECTOR 0.994
MINOR COLLECTOR 1.021
LOCAL 1.018
INTERSTATE 1.076
OTHER PRINCIPAL ARTERIAL 1.004
MINOR ARTERIAL 0.962
MAJOR COLLECTOR 0.985
MINOR COLLECTOR 1.010
LOCAL 1.001
INTERSTATE 1.031
OTHER PRINCIPALARTERIAL 0.988
MINOR ARTERIAL 1.006
MAJOR COLLECTOR 0.994
MINOR COLLECTOR 1.040
LOCAL 1.014
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 PRINCIPALARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
COLLECTOR
LOCAL
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
0.694
1.002
1.023
1.014
1.014
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-208
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Rural Roadway Type
Growth
Factor
Urban Roadway Type
Growth
Factor
New York INTERSTATE 1.019
New York OTHER PRINCIPAL ARTERIAL 1.020
New York MINOR ARTERIAL 1.004
New York MAJOR COLLECTOR 0.977
New York MINOR COLLECTOR 1.013
New York LOCAL 1.012
North Carolina INTERSTATE 1.043
North Carolina OTHER PRINCIPAL ARTERIAL 1.031
North Carolina MINOR ARTERIAL 1.011
North Carolina MAJOR COLLECTOR 1.039
North Carolina MINOR COLLECTOR 1.01*
North Carolina LOCAL 1.040
North Dakota INTERSTATE 1.016
North Dakota OTHER PRINCIPAL ARTERIAL 1.007
North Dakota MINOR ARTERIAL 0.996
North Dakota MAJOR COLLECTOR 0.977
North Dakota MINOR COLLECTOR NA
North Dakota LOCAL 1.017
Ohio INTERSTATE 1.043
Ohio OTHER PRINCIPAL ARTERIAL 1.017
Ohio MINOR ARTERIAL 1.032
Ohio MAJOR COLLECTOR 1.044
Ohio MINOR COLLECTOR 0.985
Ohio LOCAL 1.010
Oklahoma INTERSTATE 1.047
Oklahoma OTHER PRINCIPAL ARTERIAL 1.044
Oklahoma MINOR ARTERIAL 1.044
Oklahoma MAJOR COLLECTOR 1.023
Oklahoma MINOR COLLECTOR 1.050
Oklahoma LOCAL 1.024
Oregon INTERSTATE 0.997
Oregon OTHER PRINCIPAL ARTERIAL 0.995
Oregon MINOR ARTERIAL 1.017
Oregon MAJOR COLLECTOR 0.988
Oregon MINOR COLLECTOR 1.011
Oregon LOCAL 1.010
Pennsylvania INTERSTATE 1.021
Pennsylvania OTHER PRINCIPAL ARTERIAL 1.007
Pennsylvania MINOR ARTERIAL 1.012
Pennsylvania MAJOR COLLECTOR 1.018
Pennsylvania MINOR COLLECTOR 1.077
Pennsylvania LOCAL 1.010
Rhode Island . INTERSTATE 1.021
Rhode Island OTHER PRINCIPAL ARTERIAL 1.018
Rhode Island MINOR ARTERIAL 1.047
Rhode Island MAJOR COLLECTOR 1.051
Rhode Island MINOR COLLECTOR 1.013
Rhode Island LOCAL 1.026
INTERSTATE 1.018
OTH FREEWAYS & EXPRESSWAYS 1.015
OTHER PRINCIPAL ARTERIAL 1.011
MINOR ARTERIAL 1.011
COLLECTOR 1.010
LOCAL 1.011
INTERSTATE 1.037
OTH FREEWAYS & EXPRESSWAYS 1.033
OTHER PRINCIPAL ARTERIAL 1.004
MINOR ARTERIAL 1.026
COLLECTOR 1.038
LOCAL 1.025
INTERSTATE 1.001
OTH FREEWAYS & EXPRESSWAYS NA
OTHER PRINCIPAL ARTERIAL 1.062
MINOR ARTERIAL 1.013
COLLECTOR 1.010
LOCAL 1.010
INTERSTATE 1.029
OTH FREEWAYS & EXPRESSWAYS 1.034
OTHER PRINCIPAL ARTERIAL , 1.018
MINOR ARTERIAL 0.979
OLLECTOR 0.976
LOCAL 1.019
NTERSTATE 1.018
OTH FREEWAYS & EXPRESSWAYS 1.029
OTHER PRINCIPAL ARTERIAL 1.016
MINOR ARTERIAL 1.045
OLLECTOR 0.996
LOCAL 1.016
NTERSTATE 1.028
OTH FREEWAYS & EXPRESSWAYS 1.037
OTHER PRINCIPAL ARTERIAL 1.039
MINOR ARTERIAL 0.998
OLLECTOR 1.010
LOCAL 1.010
NTERSTATE 1.011
OTH FREEWAYS & EXPRESSWAYS 0.998
OTHER PRINCIPAL ARTERIAL 0.991
MINOR ARTERIAL 1.015
OLLECTOR 0.987
LOCAL 1.010
NTERSTATE 1.037
OTH FREEWAYS & EXPRESSWAYS 1.002
OTHER PRINCIPAL ARTERIAL 0.985
MINOR ARTERIAL 0.999
OLLECTOR 1.013
LOCAL .1.014
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-209
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Rural Roadway Type
Growth
Factor
Urban Roadway Type
Growth
Factor
South Carolina INTERSTATE 1.036
South Carolina OTHER PRINCIPAL ARTERIAL 1.057
South Carolina MINOR ARTERIAL 1.038
South Carolina MAJOR COLLECTOR 1.058
South Carolina MINOR COLLECTOR 1.042
South Carolina LOCAL 1.042
South Dakota INTERSTATE 1.035
South Dakota OTHER PRINCIPAL ARTERIAL 1.019
South Dakota MINOR ARTERIAL 1.005
South Dakota MAJOR COLLECTOR 0.970
South Dakota MINOR COLLECTOR 0.954
South Dakota LOCAL 1.009
Tennessee INTERSTATE 1.043
Tennessee OTHER PRINCIPAL ARTERIAL 1.021
Tennessee MINOR ARTERIAL 0.984
Tennessee MAJOR COLLECTOR 1.049
Tennessee MINOR COLLECTOR 0.893
Tennessee LOCAL 1.017
Texas INTERSTATE 1.042
Texas OTHER PRINCIPAL ARTERIAL 1.052
Texas MINOR ARTERIAL 1.044
Texas MAJOR COLLECTOR 1.030
Texas MINOR COLLECTOR 1.059
-Texas LOCAL 1.030
Utah INTERSTATE 1.041
Utah OTHER PRINCIPAL ARTERIAL 1.035
Utah MINOR ARTERIAL 1.032
Utah MAJOR COLLECTOR 0.994
Utah MINOR COLLECTOR 1.029
Utah LOCAL 1.030
Vermont INTERSTATE 1.024
Vermont OTHER PRINCIPAL ARTERIAL 1.008
Vermont MINOR ARTERIAL 1.009
Vermont MAJOR COLLECTOR 1.006
Vermont MINOR COLLECTOR 1.012
Vermont LOCAL 1.012
Virginia INTERSTATE 1.006
Virginia OTHER PRINCIPAL ARTERIAL 1.004
Virginia MINOR ARTERIAL 0.988
Virginia MAJOR COLLECTOR 1.000
Virginia MINOR COLLECTOR 0.993
Virginia LOCAL 0.998
Washington . INTERSTATE 1.000
Washington OTHER PRINCIPAL ARTERIAL 1.000
Washington MINOR ARTERIAL 0.984
Washington MAJOR COLLECTOR 0.980
Washington MINOR COLLECTOR 1.008
Washington LOCAL 1.008
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
OLLECTOR
LOCAL
INTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
OLLECTOR
LOCAL
NTERSTATE
OTH FREEWAYS & EXPRESSWAYS
OTHER PRINCIPAL ARTERIAL
MINOR ARTERIAL
OLLECTOR
LOCAL
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
1.002
1.017
1.013
1.024
1.008
1.008
1.008
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-210
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-4 (continued)
State
Rural Roadway Type
Growth
Factor
Urban Roadway Type
Growth
Factor
West Virginia INTERSTATE 1.024
West Virginia OTHER PRINCIPAL ARTERIAL 1.011
West Virginia MINOR ARTERIAL 1.01
West Virginia MAJOR COLLECTOR 1.024
West Virginia MINOR COLLECTOR 1.031
West Virginia LOCAL 1.009
Wisconsin INTERSTATE 1.012
Wisconsin OTHER PRINCIPAL ARTERIAL 1.030
Wisconsin MINOR ARTERIAL 1.035
Wisconsin MAJOR COLLECTOR 1.015
Wisconsin MINOR COLLECTOR 1.029
Wisconsin LOCAL 1.028
Wyoming INTERSTATE 1.018
Wyoming OTHER PRINCIPAL ARTERIAL 1.011
Wyoming MINOR ARTERIAL 1.014
Wyoming MAJOR COLLECTOR 1.006
Wyoming MINOR COLLECTOR 1.048
Wyoming LOCAL 1.015
INTERSTATE 1.018
OTH FREEWAYS & EXPRESSWAYS 1.005
OTHER PRINCIPAL ARTERIAL 1.006
MINOR ARTERIAL 0.999
COLLECTOR 0.986
LOCAL 1.013
INTERSTATE 1.047
OTH FREEWAYS & EXPRESSWAYS 1.018
OTHER PRINCIPAL ARTERIAL 1.020
MINOR ARTERIAL 1.042
lOLLECTOR 1.028
LOCAL 1.027
INTERSTATE 1.032
OTH FREEWAYS & EXPRESSWAYS 0.968
OTHER PRINCIPAL ARTERIAL 1.003
MINOR ARTERIAL 0.999
COLLECTOR 0.976
-OCAL 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
STATE
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/SUMMER 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 (1 974-1 993)
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-R. 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
Greenbrier Co., 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., WI
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
South Bend-Mishawaka, IN MSA
Southeast Desert Modified AQMA, CA
Spokane, WA MSA
Springfield, MA MSA
St. Louis, MO-IL MSA
Steubenvilie-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
State
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
Survey City
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
Greenbrier Co., WV
State
NY
PA-NJ
PA
Wl
TX
VT
KY
NY
WV
Wl
KY
NY
IN-KY
NY
Ml
WV
Harrisburg-Lebanon-Carlisle, PA MSA PA
Huntington-Ashland, WV-KY-OH MSA WV-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 Month lyRVP(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
12.1
14.1
7.9
13.8
11.5
11.3
12.4
12.4
12.3
10.5
11.7
12.0
10.0
12.5
13.9
13.9
14.3
15.0
11.5
11.8
11.8
12.4
12.5
12.6
12.1
14.0
14.0
15.0
15.0
13.8
11.7
11.7
13.6
14.1
9.4
12.1
13.0
11.3
14.1
12.0
15.0
Mar
9.3
14.1
7.2
10.0
11.5
11.3
11.1
10.5
10.5
10.5
7.5
9.2
10.0
12.5
11.5
11.5
12.2
13.4
9.3
11.8
11.8
9.7
10.6
10.5
10.3
11.8
11.8
12.6
12.6
10.0
11.7
11.7
12.1
12.5
8.4
10.3
11.1
10.0
12.0
12.0
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 Oct
7.8 9.3
13.0 14.1
6.8 6.8
7.1 10.0
7.5 7.4
7.5 7.4
7.8 10.1
8.6 10.5
8.5 8.1
7.5 7.2
7.4 7.5
7.6 9.2
10.0 10.0
8.7 8.7
7.1 8.2
8.4 8.2
9.0 9.3
9.0 11.2
7.4 7.6
9.3 8.9
8.6 8.9
7.3 9.7
8.6 10.6
7.8 7.7
8.6 10.3
8.7 11.8
8.9 11.8
9.3 9.5
9.0 9.5
7.1 10.0
7.1 9.2
7.3 9.2
8.6 10.1
8.4 8.6
7.8 7.8
8.6 10.3
8.6 11.1
7.8 9.0
8.7 12.0
7.6 9.2
9.0 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
1.2.5
14.5
14.4
14.5
13.5
Feb
14.4
14.4
13.5
11.0
14.1
14.1
12.1
12.0
15.0
12.4
11.6
11.6
11.6
12.4
15.0
10.2
14.5
14.4
14.5
13.5
Mar
12.3
12.3
10.0
11.0
12.0
12.0
10.3
12.0
13.4
12.4
9.4
9.4
9.4
12.4
12.6
10.2
12.0
12.3
12.1
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 Oct
9.3 9.4
9.0 9.4
7.4 7.4
7.8 8.1
9.3 12.0
8.5 12.0
8.6 10.3
7.6 9.2
9.0 9.5
7.5 9.4
8.2 7.8
7.4 7.8
7.7 7.8
7.8 10.1
8.6 12.6
7.5 7.2
8.7 8.7
8.5 9.5
9.0 9.0
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
MOBILESb and are not reflected here.
National Air Pollutant Emission Trends
Procedures Document for ] 900-1996
4-220
1985-1996 Methodology
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
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
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
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
1 1 .8 7.4
12.4 9.4
10.0 10.0
12.3 12.3
14.1 11.4
14.1 11.4
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
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
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
8.4
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
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
8.4
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
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
8.4
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
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
8.4
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
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
8.4
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
Oct Nov
9.5 9.5
14.1 14.1
6.8 7.2
9.8 13.7
6.9 9.0
7.0 9.0
9.6 10.7
10.8 10.8
7.9 11.1
7.0 10.3
7.4 7.4
9.4 9.4
10.0 10.0
8.6 10.2
7.8 11.4
7.8 11.4
8.7 12.0
11.2 13.3
7.6 9.5
8.4 11.7
8.4 11.7
9.6 9.6
11.0 11.0
7.5 10.8
10.7 10.7
11.2 11.2
9.6 12.6
9.6 12.6
9.8 9.8
9.2 11.9
9.2 11.9.
10.2 12.3
8.6 10.4
7.6 8.2
10.7 10.7
11.3 11.3
9.1 10.2
11.9 11.9
9.4 12.4
11.2 13.3
Dec
12.4
14.1
7.9
13.7
11.9
11.7
12.1
13.0
13.5
12.8
11.8
12.4
10.0
12.3
14.1
14.1
14.5
14.9
12.1
14.2
14.2
12.4
13.2
13.2
12.9
14.1
14.9
14.9
13.7
11.9
11.9
13.8
12.7
9.2
12.9
13.7
11.7
14.3
12.4
14.9
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
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
1996 Monthly RVP (psi)
Jan
14.6
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
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
12.2 10.0
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
12.1
10.1
10.8
12.0
12.0
10.7
9.4
11.2
9.5
10.0
10.0
10.0
10.7
12.6
• 7.1
11.6
12.1
12.2
10.2
May
9.3
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
9.0
9.0
7.5
8.5
8.8
9.0
8.8
Jun
9.3
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
7.8
9.0
7.5
8.5
8.8
9.0
8.8
Jul
9.3
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
7.8
9.0
7.5
8.5
8.8
9.0
8.8
Aug
9.3
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
7.8
9.0
7.5
8.5
8.8
9.0
8.8
Sep
9.3
9.0
7.4
7.7
9.3
8.5
8.6
7.6
9.0
7.5
8.2
7.4
7.7
7.8
9.0
7.5
8.5
8.8
9.0
8.8
Oct
8.7
8.7
7.2
7.7
12.0
12.0
10.7
9.4
9.6
9.5
8.3
8.3
8.3
9.6
12.6
7.1
8.5
8.8
9.0
8.8
Nov Dec
12.1 14.6
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
10.0 12.2
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
MOBILESb and are not reflected here.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-222
1985-1996 Methodology
On-road Vehicles
-------
c
CO
2
O
O)
0)
T—
V.
O
M—
CO
T3
CL
CO
"55
CO
1-
_
CO
o£
Q) ^H
^3J *""
CO
1
5
Q. 2
13
DC
CO
o
^
*~
-
C
T
.5
"o
o
ol
.E fl
15 r=
a n
H
*• ** S
£ i g
O 8 £
u.
^-i
(C
1
(U
""
^
»- 2
0-5
C 0)
i o
o
,_ 0
•2-g
i^
o
i. [n
1|
Principal
Arterial
10
CO
•>—
CO
2
CO
•^~
CM
CO
CD
"*
CO
CD
CO
•tf
U5
CO
i—
CD
LO
CD
TJ-
8
(A
(0
O
(0
£
"to
E
to
iq
O>
CO
CO
CO
**
CM'
CO
CD
"*
CO
CD
CO
•st
LO
CO
t—
CD
LO
CD
^
00
LO
w
CO
o
CO
at
o>
O)
CO
CD
CM
0
OJ
LO
oi
0>
5
LO
"*
LO
CD
00
CO
%
t~~
O)
CO
CD
LO
|^>
CD
LO
U)
1
08
in
Q.
3
U
E
o
co
CM
CO
t —
CO
co_
^
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"*
^-
cti
CD
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CO
CO
CO
iq
t^
LO
LO
_ffl
~>! O
-------
Table 4.6-12. Average Speeds by Road Type and Vehicle Type
(MPH)
Rural
LDV
LOT
HDV
Interstate
60
55
40
Principal
Arterial
45
45
35
Minor
Arterial
40
40
30
Major
Collector
35
35
25
Minor
Collector
30
30
25
Local
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
Procedures Document for 1900-1996
4-224
1985-1996 Methodology
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 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 Outpoints
Effectiveness Rates (% HC/CO/NOx)
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 Outpoints
Effectiveness Rates (% HC/CO/NOx)
Anil-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
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
YES
NO
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
1 975-2020
YES
YES
YES
NO
TRC
0.85
Biennial
95
YES
YES
NO
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
YES
NO
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
YES
NO
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-226
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-14 (continued)
l/M Program Name
Tailpipe Lead Deposit Test
EGR System
Evaporative Emission Control System
PCV System
Gas Cap
AK1IMATP
NO
YES
YES
YES
YES
AKIMATP AZPIMATP AZTIMATP
NO
YES
YES .
YES
YES
NO
NO
YES
YES
YES
NO
NO
NO
NO
NO
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
95,96
95,96
1995
1983-2020
1.00
YES
YES
YES
YES
TO
Biennial
96
1995
1986-2020
1.00
YES
YES
YES
YES
TO
Biennial
96
95,96
1995
1967-2020
0.40
YES
YES
YES
YES
TRC
Biennial
96
95,96
Notes:
TO=Test Only
TRC=Test And Repair (Computerized)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-227
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-15. Counties Included in 1995 and 1996 I/M Programs
l/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 Ei 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
MDIMATP
MIIM95
MNIMATP
MOIMATP1
MOIMATP2
NCIM931
NCIM932
NCIMATP3
NHIM95
NJIMATP
NMIMATP
N VIM ATP
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 Go
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)
UtA 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
Sheboygan 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
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
MTBE
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
Alcohol Blends
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
MTBE
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
Content (%)
Alcohol Blends
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
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/MDA/A
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 RFG
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
.009.017.006r000.001.000.002.000.004.019
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
Procedures Document for 1900-1996
4-233
1985-1996 Methodology
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
Procedures Document for 1900-1996
4-234
1985-1996 Methodology
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
Virginia (B)
Richmond-Petersburg
Washington DC
Orange Co
Queens Co
Richmond Co
Rockland Co
Suffolk Co
Westchester Co
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
Norfolk
Poquoson
Portsmouth
Suffolk
Virginia Beach
Williamsburg
York Co
Kenosha Co
Milwaukee Co
Ozaukee Co
Racine Co
Washington Co
Waukesha Co
PhSll
Phoenix was
°n!y m.°deled ln Ph°eniX be9innin9 with the Projection years, as the opt-in date for
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 Class
LDGV
LDGT1
LDGT2
HDGV
MC
LODV
LDDT
2BHDDV
LHDDV
MHDDV
HHDDV
BUSES
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
class 2B heavy-duty diesel vehicles
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 fibs)
<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
TVDB
LDV
LOT
HDV
Vehicle
TVD6
LDV
LOT
HDV
Intsrstats
60
55
40
Interstate
45
45
35
Principal
Arterial
45
45
35
Urban
Other Freeways
& Expressways
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
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.070
.066
.063
.060
.057
.054
.051
.048
.045
.042
.039
.036
.033
.030
.026
LDGT1
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
069
066
063
060
057
054
051
049
046
043
040
037
034
032
029
LDGT2
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
2.367
2.367
2.367
2.367
2.351
2.335
2.319
2.
2.
2.
2.
2.
2.
2.
2.
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
Table 4.6-24. 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,
50,
50.
50.
50.
50.
50.
50.
50.
50.
50.
50.
50.
50.
50.
.00
.00
.00
,00
,00
00
00
00
00
00
00
00
00
00
00
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-239
1985-1996 Methodology
On-road Vehicles
-------
Table 4.6-25. SO, 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
1 990 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
-------
r
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.
0.
0.
0.
0.
0.
0.
11845
12135
12513
12816
12925
12959
13019
Ammonia Emission Factor
LDGT2 HDGV LDDV
0
0
0
0
0
0
0
.10175
.10505
.10967
.11352
.11497
.11575
.11660
0.02425
0.02579
0.02881
0.03216
0.03356
0.0341 1
0.03486
0.00188
0.00188
0.00188
0.00188
0.00188
0.00188
0.00188
(g/mi)
LDDT
0.00188
0.00188
0.00188
0.00188
0.00188
0.00188
0.00188
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
Procedures Document for 1900-1996
4-242
1985-1996 Methodology
On-road Vehicles
-------
Figure 4.6-1. State-Provided Registration Distributions
State: Delaware
Counties: Kent Co
.0020.0630
.0680.0440
.0050.0050
.0010.0550
.0540.0370
.0080.0070
.0070.0360
.0430.0380
.0170.0150
.0020.0480
.0490.0320
.0320.0300
.0020.0630
.0680.0440
.0050.0050,
.0010.0550,
.0540.0370,
.0080.0070,
.0030.0260.
.0570.0310.
.0210.0270.
.0060.0490.
.0370.4400.
.0000.0000.
.0690.0720
.0320.0280
.0050.0040
.0720.0730
.0260.0210
.0070.0060
.0560.0620
.0330.0280
.0110.0090
.0430.0440
.0250.0370
.0200.0150
,0690.0720
,0320.0280
,0050.0040
,0720.0730,
0260.0210,
0070.0060,
0320.0400.
0400.0270.
0130.0070.
0580.0590.
0000.0000.
0000.0000.
.0750
.0240
.0240
.0710
.0210
.0330
.0790
.0220
.0420
.0590
.0230
.0760
,0750,
,0240,
,0240
,0710.
0210.
0330
0370.
0520.
0630
0470.
0000.
0000.
.0810.0860.0840.0820.0750
.0250.0190.0140.0090.0050
.0900.0900.0870.0810.0600
.0310.0260.0200.0140.0090
.0820.0820.0540.0770.0590
.0470.0330.0310.0220.0150
.0590.0600.0560.0720.0590
.0420.0300.0340.0240.0290
.0810.0860.0840.0820.0750
.0250.0190.0140.0090.0050
,0900.0900.0870.0810.0600
,0310.0260.0200.0140.0090
,0660.0710.0560.0610.0580
0780.0590.0260.0140.0350
0770.0350.0530.0820.0570
0000.0000.0000.0000.0000
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-243
1985-1996 Methodology
On-road Vehicles
-------
Figure 4.6-2. OTAG Inventory Source of Data - VMT
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-244
1985-1996 Methodology
On-road Vehicles
-------
4.7 NON-ROAD ENGINES AND VEHICLES
The "Non-road Engines and Vehicles" heading includes the following Tier I and Tier n categories:
Tier 1 Category
(11) Non-road Engines and Vehicles
Tier IE Category
All
The Tier n 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 (QMS) 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 QMS. The QMS 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
Procedures Document for 1900-1996
4-245
1985-1996 Methodology
Non-road Sources
-------
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 QMS 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 QMS
inventories; the 27 SCCs used are listed in Table 4.7-2
(b) for each of the 27 QMS 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.L2 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,
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and (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 paniculate 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
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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
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
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
1989.11 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).
CEt = CE
BY
(CE
BY
x
(Eq. 4.7-1)
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where: CEj = 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.
EG; = 1- '
DAT
BY
(Eq. 4.7-2)
where:
DAT; =
DAT
BY
Earnings growth for year I
Earnings data for inventory year I
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.
UEt =
CE:
_ CEFF]
100 j
(Eq. 4.7-3)
where: UE;
CE,
CEFF
Uncontrolled Emissions for inventory year I
Controlled Emissions for inventory year I
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, = CES
(Eq. 4.7-4)
Third, controlled emissions are recalculated incorporating revised emission factors using the following
equation (Equation 4.7-5).
CER, = UC; x ' EFi
EF,
BY
(Eq. 4.7-5)
where: CER; = Controlled Emissions Incorporating Rule Effectiveness
= Uncontrolled Emissions
= 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(county>scc.year) =
x Emissions (county,SCc,i99oy
(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 QMS 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:
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1985-1996 Methodology
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FinalNationall995Estimates
PreliminaryNationall995Estimates
(Eq. 4.7-7)
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
1990
1991
1992
1993
1994
1995
1992 PCE Deflator
93.6
97.3
100.0
102.6
104.9
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:
. 1996Earnings = 1995Earnings
- IWOEarnings
(Eq. 4.7-8)
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
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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^
EmissionsS5 or 96 = Emissions,
90
Earnings^ or 96
(Eq. 4.7-9)
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 1996.7Wc
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 QMS 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
(Eq. 4.7-10)
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.
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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 4.7-11 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.
CER1996 = UC 1995 X
GS
1996
GS
1995
( REFF} ( CEFF\
( 100 J ( 100 J *
(Eq. 4.7-11)
where: CER
UC
1996
1995 —
GS
REFF =
CEFF =
RP
controlled emissions incorporating rule effectiveness
uncontrolled emissions
growth surrogate (either BEA or SEDS data)
rule effectiveness (percent)
control efficiency (percent)
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-Spark-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.
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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, QMS 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 QMS
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 TV: 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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1985-1996 Methodology
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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 1 A, IB, and 1C," (CD-ROM), Bureau of the
Census, U.S. Department of Commerce, 1995.
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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
tarffbrd
ST. Louis
Chiclgo 1 Cteveland
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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
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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 1 981 -1 990," Assoc
Switch
255
258
:iation of
American Railroads, Washington, DC, 1991.
Table 4.7-4. Railroad Emission Factors
(lbs/1,000 gallons)
Wtg. Factor
NOV
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
Procedures Document for 1900-1996
4-259
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-5. Civil Aircraft SO, Emission Factors
Engine
Tvne
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) Engine 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 O-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 S02
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
Area Sources," AP-42, U.S. Environmental Protection Agency, Research
September 1991.
I: Stationary Point and
Triangle Park, NC,
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
NAPAP
SCC Cateaorv
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
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-AMS - 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-AMS - 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 Nonattainmen
Areas
Baton Rouge Nonattainment
Area (20 Parishes)
Entire State
Entire State
49 Southern Michigan
Counties
Entire State
Entire State
entire State
-ntire State
Canton, Cleveland Columbus,
)ayton, Toledo, and
Youngstown
Entire State
Entire State
Entire State
Entire State
:ntire State
Charleston, Huntington/
Ashland, and Parkersburg
5 counties total)
:ntire State
Adjustments to Data
None
Added Nonroad emission estimates
from Int. Inventory to Jacksonville
(Duval County)
Mone
Mone
Nonroad emissions submitted were
county totals. Nonroad emissions
distributed to specific SCCs based
on Int. Inventory
None
vJone
None
^lone
None
None
Assigned SCCs and converted
from kgs to tons. NOX and CO from
nt. Inventory added to Canton,
Dayton, and Toledo counties.
Nonroad emissions submitted were
county totals. Nonroad emissions
distributed to specific SCCs based
Average Summer Day estimated
sing default temporal factors.
\lone
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-263
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-10. Area Source Listing by SCC and Growth Basis
FM F HODF
SCC
FILE CODE
SCC
FILE CODE
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
2260008000
2260008010
2265000000
2265001000
2265001010
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
BEA
BEA
SEDS
SEDS
SEDS
2265001 030- SEDS
2265001040
2265001050
2265001060
2265002000
SEDS
SEDS
SEDS
BEA
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
081
400
400
400
400
400
100
100
542
542
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
300
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
2265004030
2265004035
2265004040
2265004045
2265004050
2265004055
2265004060
2265004065
2265004070
2265004075
2265005000
2265005010
2265005015
2265005020
2265005030
2265005035
2265005040
2265005045
2265005050
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
SEDS
SEDS
SEDS
SEDS
SEDS
SEDS
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
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
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
TPOPP
081
081
081
081
081
081
081
081
081
2265006015
2265006025
2265006030
2265007000
2265007010
2265008000
2265008005
2265008010
2270000000
2270001000
2270001010
2270001050
2270001060
2270002000
2270002003
2270002009
2270002012
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
BEA
BEA
BEA
BEA
BEA
BEA
BEA
BEA
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
BEA
BEA
BEA
BEA
BEA
400
400
400
100
100
542
542
542
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
300
300
300
300
300
300
400
400
400
400
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,
FuelTvoe End-User Code 1990 1991 1992
Population
TPOPP
Table 4.7-1 2. BEA SA-5
Industry
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
248,709 252,131 255,025 257,785 259,693 261,602 263,510
National Earnings by Industry, 1990-1996 (million $)
LNUM SIC 1990 1991 1992 1993 1994 1995 1996
Farm 81 1,2 48
Agricultural services, forestry, fisheries, and other 100 7-9 24
Construction " 300 15-17 218
Manufacturing 400 998 710
Railroad transportation 510 40 12
Water transportation 530 44 7
Transportation by air 542 45 30
Federal, military 920 992 50
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
Stale
Cc-untv
State
Countv
State
Countv
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
Caiomia
Caiomia
Caiomia
Caiomia
Caiomia
Catania
Caiomia
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Connecticut
Delaware
Delaware
Delaware
Dfet Columbia
IBincis
•note
Iftoois
matiH
HSnols
IMnois
Illinois
Mnote
Indiana
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Mains
Maine
Maine
Mains
Mara
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
FairfteldCo
Hartford Co
LiichfieWCo
Middlesex Co
New Haven Co
New London Co
Tofland Co
Windham Co
Kent Co
New Castle Co
Sussex Co
Washington
Cook Co
Du Page Co
GrundyCo
Kane Co
Kendall Co
Lake Co
McHenry Co
WMCo
Lake Co
Porter Co
Boone Co
BullittCo
Campbell Co
Jefferson Co
Kenton Co
OWham Co
Androscoggin Co
Cumberland Co
KennebecCo
KNO.Co
Lincoln Co
SagadahocCo
York Co
Anne Arundel Co
Baltimore Co
CarVertCo
Carroll Co
Cecil Co
Charles Co
Frederick Co
Harford Co
Howard Co
KerrtCo
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
Mem'mack Co
Rockingham Co
Stratford 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
Walter 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
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-267
1985-1996 Methodology
Non-road Sources
-------
Table 4.7-15. National Nonroad Diesel Emissions
(tons)
Pnolns °T*VD6
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
N°«
CO
PM-10
PM-2.5
VOC
NOX
CO
PM-10
PM-2.5
VOC
NOX
CO
PM-10
PM-2.5
1995
NET OMS
1
547
7
0
0
98,658
794,859
477,757
145,900
1 34,228
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
1 6,534
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
1 1 ,893
10,941
12,002
74,186
29,365
7,727
7,109
1 0,273
90,835
39,318
10,381
9,550
NET
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
1 64,323
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
1 01 ,350
46,959
18,316
16,851
1996
OMS
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
1 1 ,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
Procedures Document for 1900-1996
4-269
1985-1996 Methodology
Non-road Sources
-------
4.8 FUGITIVE DUST
The "Fugitive Dust" grouping includes the estimated emissions for several Tier n source categories.
These Tier n 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 n 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
(13) Natural Sources
(14) Miscellaneous
Tier H Category
(02) Geogenic (agricultural wind erosion)
(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.
.4 "\
/ = k x c, x c; x
u
0.8864
x r(3,x)
(Eq. 4.8-1)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-270
1985-1996 Methodology
Fugitive Dust
-------
where:
I
k
C
cd
u
T(3,x)
dust flux (gm/cm2/sec)
PM-10 particle size multiplier (= 0.9)
PM-2.5 particle size multiplier (= 0.135)
constant (= 4 x 10"14 gm/cm2/sec)
drag coefficient
mean wind speed (cm/sec)
incomplete gamma function
To evaluate F(3,x), x must be determined from Equation 4.8-2.
x = \u( x
0.886
u J,
(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.
ut =
C.
0.5
(Eq. 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.
0.23
(Eq. 4.8-4)
where:
—
p "*•
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 (un) 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 value of u*t determined and Cd. Once ut was determined, then x could be calculated and the
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-271
1985-1996 Methodology
Fugitive Dust
-------
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.
_ „ . . ( County Rural Land] ^ . ,-, . .
County Emissions = x State Emissions
\ State Rural Land )
(Eq. 4.8-5)
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.
_ _ . . | County Cropland Tilled] c. „ . . ^ „
County Emissions = x State Emissions (Eq. 4.8-6)
I State Croplant Tilled
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-272
1985-1996 Methodology
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 paniculate 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 um 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 USD A5 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 ofTillinss 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
Procedures Document for 1900-1996
4-273
1985-1996 Methodology
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.
_ T-. • • I County Cropland Harvested] p „ . .
County Emissions = x State Emissions
\ State Croplant Harvested )
(Eq. 4.8-8)
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 paniculate 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 s0-6 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 jam 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 Deterinination of Correction Parameters —
4.8.2.2.1.1 Silt content (s). By comparing the USD A5 surface soil map with the USD A11 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 values were assumed constant for the 6-year period examined. This differs from the
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-274
1985-1996 Methodology
Fugitive Dust
-------
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
Procedures Document for 1900-1996
4-275
1985-1996 Methodology
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.
County Emissions =
_ ( County Head of Cattle} .„
" I I " JL /
( 1,000 }
(Eq. 4.8-10)
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 TVA 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
Aqua ammonia
Nitrogen solutions
Ammonium sulfate
Ammonium thiosulfate
Other straight nitrogen
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-276
1985-1996 Methodology
Fugitive Dust
-------
Urea
Ammonium nitrate
Ammonium phosphates
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?-5 *
(365 -1PDA75)7365 * 453.392
(Eq. 4.8-11)
where: UNPVD =
SILT
SPD
WEIGHT
WHEELS
IPDAYS
493.592
= unpaved road dust emission factor for all vehicle classes combined (grams per
mile)
fraction of particles less than 10 or 2.5 microns from unpaved road dust (0.36
for PM-10 and ? For PM-2.5)
percentage silt content of the surface material
average speed of all vehicle types combined (miles per hour [mph])
average weight of all vehicle types combined (tons)
average number of wheels per vehicle for all vehicle types combined
number of precipitation days per year with greater than 0.01 inches of rain
number of grams per pound
The above equation is based on roadside measurements of ambient paniculate matter, and is
therefore representative of a fleet average emission factor rather than a vehicle-specific emission factor.
In addition, because this equation is based on ambient measurements, it includes paniculate matter from
tailpipe exhaust, brake wear, tire wear, and ambient background paniculate concentrations. Therefore,
the PARTS fleet average PM emission factors for the tailpipe, tire wear, and brake wear components
were subtracted from the unpaved road fugitive dust emission factors before calculating emissions from
Reentrained road dust on unpaved roads.
4.8.2.4.1.1 Silt Content Inputs. Average state-level, unpaved road silt content values developed as
part of the 1985 NAPAP Inventory, were obtained from the Illinois State Water Survey.24 Silt contents
of over 200 unpaved roads from over 30 states were obtained. Average silt contents of unpaved roads
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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 '91,25 and the 1991
Market Data Book.27 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 =
ADTV =
FSRM =
DPY
VMT on unpaved roads (miles/year)
average daily traffic volume (vehicles/day/mile)
functional system roadway mileage (miles)
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 Statistics™ 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.
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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
VMT
MILEAGE
average daily traffic volume for state and federally maintained roadways
VMT on county-maintained roadways (miles/year)
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 =
ADTV =
RM
VMT at the state level for federally and state-maintained unpaved roadways
(miles/year)
average daily traffic volume derived from local roadway data
state-level federally and state-maintained roadway mileage (mi)
4.8.2.4.2.3 Unvaved 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
Mileage
= road type specific unpaved Vehicle Miles Traveled (miles/year)
= total number of miles of unpaved roads by functional class (miles)
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ADTV
DPY
= Average daily traffic volume (vehicle/day)
= 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 = (CNTYLANDURBjlSTATLANDURB)
+ (CNTYLANDRURj/STATLANDRUR) *
(Eq. 4.8-16)
where: PMX y
CNfYLAND
URBiX
CNTYLAND
RUR,X
unpaved road PM emissions (tons) for county x and road type y
urban land area in county x
urban land area in entire state
unpaved road PM emissions in entire state for urban road type y
rural land area in county x
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STATLAND
PM
RUR
•ST,RUR,Y
rural land area in entire state
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. PARTS 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 PARTS 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 * (PVSILTI2T65 * (WEIGHT/3)
\1.5
(Eq. 4.8-17)
where: PAVED
PSDPVD
PVSILT
WEIGHT
paved road dust emission factor for all vehicle classes combined (grams per
mile)
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)
road surface silt loading (g/m2)
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.
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As with the PART5 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 PART5 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.
PVDEMIS
XY
* VMTXJVMTSTJ
(Eq. 4.8-18)
where: PVDEMISXy
PVDEM
VMTX,Y
= paved road PM emissions (tons) for county x and road type y
= paved road PM emissions (tons) for the entire state for road type y
= total VMT (million miles) in county x and road type 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).
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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 paniculate 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
T
$
f .
m
P
PM-10 emissions
TSP emission factor (1.2 ton/acre of construction/month of activity)
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)
dimensionless PM-10/TSP ratio (0.22).
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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 paniculate 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.
( CE\
x$x/xmxl -
J ( lOOJ
(Eq. 4.8-20)
where: E = PM emissions
P = PM emission factor (ton/acre of construction/month of activity)
(PM-10 = 0.11; PM-2.5 = 0.022)
$ = 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)
CE = 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
19STJfation,Dodge
(Eq. 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
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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 and PM-2.5 Ratio (P) (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.
^ , j-, . . County Construction Payroll „ . , „ . .
County Emissions = ^- x Regional Emissions
Regional Construction Payroll
(Eq. 4.8-22)
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.
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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 = E + E + E
(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.
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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.
= A
EF + B
EF
(Eq. 4.8-24)
where: Am =
ER =
B =
EFb =
EF, =
EF, =
metallic crude ore handled at surface mines (1000 short tons)
PM-10 open pit overburden removal emission factor for copper ore processing
(Ibs/ton)
fraction of total ore production that is obtained by blasting at metallic mines
PM-10 drilling/blasting emission factor for copper ore processing (Ibs/ton)
PM-10 loading emission factor for copper ore processing (Ibs/ton)
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.
= An x
(EFv
DxEF
(EFg + EF))
(Eq. 4.8-25)
where:
* n
EF
D
EFr
EFa
EFe
EFt
non-metallic crude ore handled at surface mines (1000 short tons)
PM-10 open pit overburden removal emission factor at western surface coal
mining operations (Ibs/ton)
fraction of total ore production that is obtained by blasting at non-metallic
mines
PM-10 drilling/blasting emission factor at western surface coal mining
operations (Ibs/ton)
PM-10 loading emission factor at western surface coal mining operations
(Ibs/ton)
PM-10 truck unloading: end dump-coal emission factor at western surface
coal mining operations (Ibs/ton)
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 (I0x (EFto + EFor + EFd) + EFv + EFf + EFa + V4x (EF£ + EF)) (Eq. 4.8-26)
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Ac
Ef,
to
where: Af = coal production at surface mines (1000 short tons)
= PM-10 emission factor for truck loading overburden at western surface coal
mining operations (Ibs/ton of overburden)
= PM-10 emission factor for overburden replacement at western surface coal
mining operations (Ibs/ton of overburden)
= PM-10 emission factors for truck unloading: bottom dump-overburden at
western surface coal mining operations (Ibs/ton of overburden)
= PM-10 open pit overburden removal emission factor at western surface coal
mining operations (Ibs/ton)
= PM-10 drilling/blasting emission factor at western surface coal mining
operations (Ibs/ton)
= PM-10 loading emission factor at western surface coal mining operations
(Ibs/ton)
= PM-10 truck unloading: end dump-coal emission factor at western surface
coal mining operations (Ibs/ton)
= PM-10 truck unloading: bottom dump-coal emission factor at western
surface coal mining operations (Ibs/ton)
4,8,2,7,2,3 1996Emissions 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).
Efor
Efdl
EFV
EFr
EFa
EFC
County Emissions =
1
Number of Counties in Region
x Regional Emissions
(Eq. 4.8-27)
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. = CEBY + (CEBY x EG:)
(Eq. 4.8-28)
where: CE;
CEjjy
= Controlled Emissions for inventory year I
= Controlled Emissions for base year
= Earnings Growth for inventory year I
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Earnings growth (EG) is calculated as shown in Equation 4.8-29.
EG. = 1-
DAT.
DAT,
(Eq. 4.8-29)
BY
where: DATS = 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:
South:
47.00 °N
26.00 °N
East:
West:
67.00°W
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.
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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
Inventory44 was used for default inventory data.
i
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
SEPs. 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 AJRS/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 =. EMISSIONS
ANNUAL
* SUMTHRU * II(13 * DPW)
(Eq. 4.8-30)
where:
EMISSIONS
EMISSIONS
SUMTHRU
DPW
ASD
ANNUAL
= average summer day emissions
= annual emissions
= summer throughput percentage
= 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 = EMISSIONS
/ (SUMFACSCC * WDFACSCC)
(Eq. 4.8-31)
where:
EMISSIONS
EMISSIONS
SUMFAC
WDFAC
'ASD
'ANNUAL
•sec
sec
= average summer day emissions
= annual emissions
= default summer season temporal factor for SCC
= 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:
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EMISSIONSASD
EMSSIONSANNUAL
= average summer day emissions
= 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
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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.
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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 EGPS 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:
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Year
1985
1987
1988
1989
1990
1982 PCE Deflator
111.6
114.8
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
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/PS.) 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
1990
1991
1992
1993
1994
1995
1996
1992 PCE Deflator
93.6
97.3
100.0
102.6
104.9
107.6
109.7
4.8.2.8.4.2 AJRS/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.
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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.
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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 PARTS: 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, B ACM 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 EPRIEA-6070, November 1988.
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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 Particulate
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
Procedures Document for 1900-1996
4-299
1985-1996 Methodology
Fugitive Dust
-------
Table 4.8-1. Particle Size Ratios
Source Category
Ratio of PM-2.5 to PM-10
Wind Erosion - Agricultural Land
Agricultural Crops
Agricultural Livestock
Wind Erosion - Non-Agricultural Land
Paved Roads
Unpaved Roads
Construction Activities
Mining and Quarrying
0.15
0.20
0.15
0.15
0.25
0.15
0.20
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 Content (%
Silt Loam
Sandy Loam
Sand
Loamy Sand
Clay
Clay Loam
Organic Material
Loam
52
33
12
12
29
29
10-82
40
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-300
1985-1996 Methodology
Fugitive Dust
-------
Table 4.8-4. Number of fillings by Crop Type
Crop
Number of Tillings
Conservational Use Conventional Use
Corn
Spring Wheat
Rice
Fall-Seeded Small Grain
Soybeans
Cotton
Sorghum
Forage
Permanent Pasture
Other Crops
Fallow
Annual Conservation Use
2
1
5
3
1
5
1
3
1
3
1
6
4
5
5
6
8
6
3
1
3
1
(No method, not used after 1995; number of tillings = 1)
Table 4.8-5. Livestock Operations Ammonia Emission Factors
Category
Cattle and Calves
Pigs and Hogs
Poultry
Sheep
Horses
Goats
Mink
AMS SCC
2805020000
2805025000
2805030000
2805040000
2710020030
2805045001
2205045002
Emission Factor
(Ib NryHead)
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
Major Collector
Minor Collector
Local
39
34
30
30
Other Principal Arterial
Minor Arterial
Collector
Local
20
20
20
20
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-301
1985-1996 Methodology
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
Assumed ADTV Value for Rural
Roads
Volume Category for Urban Roads
Assumed ADTV Value for Urban
Roads
Less than 50
5"
Less than 200
20'
50-199
125"
200 - 499
350"
200 - 499
350"
500-1999
1250"
500 and over
550""
2000 and over
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
sr.r.
TIPP1 TIPD9
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 & 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
Stale
Alabama
Arkansas
Connecticut
Delaware
District of Columbia
Florida
Georgia - Atlanta
Urban Airshed (47
counties) domain
Georgia - Rest of
Stato
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
Onto
Oklahoma
Pennsylvania -
Allegheny County
Pennsylvania -
Philadelphia County
Pennsylvania - Rest
of State
Rhode Island
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
Stale - 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
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
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
Adjustments to Data
Backcast to 1 990 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 1 990 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 1 990 using BEA. Average Summer
Day estimated using methodology described
above.
None
None
None
None
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 Year of
Resolution Data Adjustments to Data
South Carolina
South Dakota
Tennessee
Texas
Vermont
Virginia
West Virginia
Wisconsin
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State Format
State - EPS Workfile
AIRS-AFS - Ad hoc retrievals
AIRS-AFS - Ad hoc retrievals
State - State Format
Annual 1991 Average Summer Day estimated using default
temporal factors.
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
Slato
Connecticut
Delaware
District of Columbia
Florida
Georgia
Illinois
Indiana
Kentucky
Louisiana
Maine
Maryland
Michigan
Missouri
New Hampshire
New Jersey
New York
North Carolina
Data Source/Format
State - EPS Workfile
State - EPS Workfile
State - Hard copy
AIRS-AMS - 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
AIRS-AMS- Ad hoc retrievals
State - EPS Workfile
State - EPS Workfile
State - EPS Workfile
State - EPS Workfiles
Temporal
Resolution
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Daily
Annual
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
St. Louis area (25 counties)
Entire State
Entire State
Entire State
Entire State
Adjustments to Data
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
Onto
Pennsylvania
State - Hard copy
State - EPS Workfile
Daily Canton, Cleveland Columbus,
Dayton, Toledo, and
Youngstown
Daily Entire State
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
Rhode Island
Tennessee
Texas
Vermont
Virginia
West Virginia
Wisconsin
State - EPS Workfile
State - State format
State - State Format
State - EPS Workfile
State - EPS Workfile
AIRS-AMS - Ad hoc retrievals
State - State Format
Daily
Daily
Annual
Daily
Daily
Daily
Daily
Entire State
42 Counties in Middle
Tennessee
Entire State
Entire State
Entire State
Charleston, Huntington/
Ashland, and Parkersburg
(5 counties total)
Entire State
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
-------
O
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EMISSIONS
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-307
1985-1996 Methodology
Fugitive Dust
-------
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
Agricultu
iral 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
Metal mining 10 -3.03 18.01
Nonmetallic minerals, except fuels 14 2.33 3.74
Construction 15,16,17 7.27 4.81
-4.16
8.94
-2.79
-1.36
4.73
4.56
-0.45
-3.80
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
4-308
1985-1996 Methodology
Fugitive Dust
-------
Table 4.8-14. Emission Estimates Available from AIRS/FS by State, Year, and Pollutant
State
1990
C N S P T V
1991
N S P T V
1992
N S P
1993
C N
S P T
1994
S P T
1995
; N
S P T V
Alabama
/
Alaska
S
Arizona
Y
California
Colorado
S
S
Connecticut
V
Hawaii
S
S
S
S
llinois
S
Lousiana
Michigan
Y
Minnesota
S
Montana
S
V
S
Y
Nebraska
S
S
Nevada
S
New
Hampshire
S
S
New Mexico
S
S
North Dakota
Oregon
S
ennsylvani
S
S
South
arolina
South
Dakota
S
Texas
Utah
S
Vermont
S
Virginia
Washington
S
S
isconsin
S
S
yoming
Notes:
C = CO
= NO,
= SO,
= 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)
FuelTvoe End-User Code 1990 1991 1992 1993 1994 1995
Population
TPOPP 248,709
1996
252,131 255,025 257,785 259,693 261,602 263,510
Table 4.8-16. BEA SA-5 National Earnings by Industry, 1990-1996 (million $)
fnHtmtrv
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
Nonmotallic minerals, except fuels
Construction
Construction
Construction
Construction
Primary metal Industries
Transportation by air
Table 4.8-17 Area Source
SCC FILE CODE
2275000000 BEA 542
2275001000 BEA 920
2275020000 BEA 542
2275020021 BEA 542
2275050000 BEA 542
2275060000 BEA 542
2275070000 BEA 542
2275085000 BEA 542
2275900000 BEA 542
2275900101 BEA 542
2275900102 BEA 542
2301000000 BEA 471
2301010000 BEA 471
2301020000 BEA 471
2301030000 BEA 471
2301040000 BEA 471
2710020030 BEA 081
2801000003 BEA 081
LNUM SIC 1990 1991 1992 1993 1994
81 1,2 • 48 41 46 45 42
82 1,2 3,586 3,552 3,686 3,740 3,849
90 1,2 3,001 2,957 3,079 3,126 3,228
100 7-9 24 24 24 24 26
110 7-9 20 20 21 22 23
120 7-9 43333
121 7-9 11101
122 7-9 22222
123 7-9 11111
200 7-9 36 37 36 34 35
240 14 44444
300 15-17 218 197 195 199 216
310 15-17 54 47 46 47 51
320 15-17 29 28 28 27 29
330 15-17 135 123 121 125 136
423 33 33 30 31 30 32
542 45 30 30 31 31 31
Listing by SCC and Growth Basis
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
1995
31
3,980
3,353
27
24
3
1
2
1
35
4
219
51
29
138
33
31
1996
29
4,058
3,423
27
25
3
1
1
1
35
4
219
50
29
139
32
31
National Air Pollutant Emission Trends
Procedures Document far 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 n category. The correspondence between the
Tier H categories and the lead emissions methodology source categories is presented in Table 5.1-1.
Within the description of the procedures for each Tier n category, the correlation between the categories
is reiterated.
5.1.2 General Procedure
Lead emissions were calculated according to Equation 5.1-1.
Lead Emissions. . = A. . x EFi . x [1 -CE. .]
(Eq. 5.1-1)
where: A = activity
EF = emission factor
CE = control efficiency
I - = year
j = source category
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-1
Lead Emissions Methodology
Introduction
-------
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 theTRENDSxx.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 n 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 ton (long)
1 ton (short)
Ibbl
1.1023 tons (short)
1.1016 tons (short)
0.9072 tons (metric)
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 H category except for the On-
road vehicles category which is described at the Tier I level. For each category, the procedure is divided
into four sections, reflecting the data required to generate the estimates: (1) technical approach, (2)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-2
Lead Emissions Methodology
Introduction
-------
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 n 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 n category.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-3
Lead Emissions Methodology
Introduction
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-4
Lead Emissions Methodology
Introduction
-------
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National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-5
Lead Emissions Methodology
Introduction
-------
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
-------
5.2 FUEL COMBUSTION ELECTRIC UTILITY - COAL: 01-01
The emissions for this Tier n category were determined by the Lead Emissions Methodology for the
following source categories (See Table 5.1-1 for Tier correspondence):
Category:
Bituminous Coal and Lignite
Anthracite Coal
Subcategory:
Electric Utility
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 n category.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-7
Lead Emissions Methodology
Category: 01-01
-------
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/lQ). 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
Procedures Document for 1900-1996
5-8
Lead Emissions Methodology
Category: 01-01
-------
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:
Residual Oil
Distillate Oil
Subcategory:
Electric Utility
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 n category.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-9
Lead Emissions Methodology
Category: 01-02
-------
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
Procedures Document for 1900-1996
5-10
Lead Emissions Methodology
Category: 01-02
-------
5.4 FUEL COMBUSTION INDUSTRIAL -COAL: 02-01
The emissions for this Tier n category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Anthracite Coal
Bituminous Coal and Lignite
Subcategory:
Industrial
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
Procedures Document for 1900-1996
5-11
Lead Emissions Methodology
Category. 02-01
-------
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/lQ). 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
Procedures Document far 1900-1996
5-12
Lead Emissions Methodology
Category: 02-01
-------
5.5 FUEL COMBUSTION INDUSTRIAL - OIL: 02-02
The emissions for this Tier n category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Residual Oil
Distillate Oil
Subcategory:
Industrial
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 5a 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 n 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
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Lead Emissions Methodology
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5.6 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL COAL: 03-01
The emissions for this Tier n category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Anthracite Coal
Bituminous Coal and Lignite
Subcategory:
Commercial / Institutional
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 Coalcn = Anthracite CoalR and cn - 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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Lead Emissions Methodology
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Anthracite Coal
R, i
= Anthracite Coal
Dwelling Units.
Dwelling Units ._j
(Eq. 5.6-2)
where: R
I
residential consumption
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 Coalcn = (All CoalR and Cll - Anthracite CoalR md c/1~) - Bituminous CoalR (Eq. 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 bumedldwelling/year) - Anthracite CoalR (Eq. 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 3a.
5.6.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from the sources
included in this Tier n 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-150-83. 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
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5.7 FUEL COMBUSTION OTHER - COMMERCIAL/INSTITUTIONAL OIL: 03-02
The emissions for this Tier n category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Residual Oil
Distillate Oil
Subcategory:
Commercial / Institutional
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 3a.
5.7.4 Control Efficiency
No control efficiencies were applied to activity data to estimate emissions from the sources
included in this Tier n 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
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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:
Residual Oil
Subcategory:
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
Year
Percent
Lead
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
0.5333
0.4702
0.407
0.3439
0.2807
0.2176
0.1545
0.0913
0.0282
0.0213
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5.9 FUEL COMBUSTION OTHER - RESIDENTIAL OTHER: 03-06
The emissions for this. Tier n category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Anthracite Coal
Bituminous Coal and Lignite
Residual Oil
Distillate Oil
Subcategory:
Residential
Residential
Residential
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.
Anthracite CoalR> . = Anthracite CoalR^ ._l x
Dwelling Unitsi
Dwelling Units._t
(Eq. 5.9-1)
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
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 5a.
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 H category.
5.9.5 References
1. American Housing Survey, Current Housing Reports, Series H-150-83. 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 ofHATREMS Data Base and Emission Inventory Evaluation. EPA-450/3-77-011.
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-27S525. 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 n 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:
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 n 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 n 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.
Number of Batteries =
Weightpb x 1.10231 x 2,000 Ib/ton
1,000 x 26 Ib/battery
(Eq. 5.11-1)
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
5J1.3.1 Nonferrous 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.
CE -
UE J
(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 n 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:
Iron and Steel Industry (coke, blast furnace, sintering,
open hearth, EOF (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 J 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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Lead Emissions Methodology
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5.12.2.2 Nonferrous Metals
The activity indicator for ferrosilicon production was tfte 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.
National Air Pollutant Emission Trends
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Lead Emissions Methodology
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5.12.4 Control Efficiency
The control efficiencies for all processes included in this Tier n 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.
CE =
(UE-AE)]
UE \
(Eq. 5.12-1)
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"
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Lead Emissions Methodology
Category: 05-02
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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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Lead Emissions Methodology
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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(x) - 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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Procedures Document for 1900-1996
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Lead Emissions Methodology
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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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Lead Emissions Methodology
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5.14 OTHER INDUSTRIAL PROCESSES - MINERAL PRODUCTS: 07-05
The emissions for this Tier n 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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Lead Emissions Methodology
Category: 07-05
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CE =
UE
(Eq. 5.14-1)
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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Lead Emissions Methodology
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5.15 OTHER INDUSTRIAL PROCESSES - MISCELLANEOUS INDUSTRIAL
PRODUCTS: 07-10
The emissions for this Tier n 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Lead Emissions Methodology
Category: 07-10
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products, (3) 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 n 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-39
Lead Emissions Methodology
Category: 07-10
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5.16
WASTE DISPOSAL AND RECYCLING : 10-01
The emissions for this Tier n category were determined by the Lead Emissions Methodology for the
following source categories (see table 5.1-1 for Tier correspondence):
Category:
Solid Waste Disposal
Subcategory:
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 Trends 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.
A: = A:_, x
,._,
SCCs
OR.
(Eq. 5.16-1)
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-40
Lead Emissions Methodology
Category: 10-01
-------
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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Lead Emissions Methodology
Category: 10-01
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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 IH-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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Lead Emissions Methodology
Category: 10-01
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5.17 ON-ROAD VEHICLES: 11
The emissions for all Tier n 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:
On-road vehicles
Subcategory:
Gasoline (leaded, unleaded)
5.17.1 Technical Approach
The lead emissions included in these Tier n 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 Trends, 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 n 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 n 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:
GC. = GC.
~
VMT.
(Eq. 5.17-1)
where: GC
I
VMT
total gasoline consumption by all On-road vehicles
year of interest
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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Procedures Document for 1900-1996
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Lead Emissions Methodology
Category: 11
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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 n 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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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Category: 11
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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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-45
Lead Emissions Methodology
Category: 11
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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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-46
Lead Emissions Methodology
Category: 11
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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
Tractor, 1973
X
Agriculture, i
Agriculture, 1973
(Eq. 5.18-1)
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
National Air Pollutant Emission Trends
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Lead Emissions Methodology
Category: 12-01
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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.
Snowmobiles, i ^^Snowmobiles, 1973 X »r
N
Snowmobiles, i
(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.
GC
Small Engines
, , N Single Unit Dwellings.
. . = (533 x 106 gal) x —
'""' V ' Single Unit Dwellings^
(Eq. 5.18-3)
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-48
Lead Emissions Methodology
Category: 12-01
-------
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.
GC
Motorcycles
= TV
Motorcycles
X
Motorcyles, Off-highway
MPG
(Eq. 5.18-4)
where: GC
N
M
MPG
= gasoline consumption
= number of motorcycles
= mileage
= 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. •
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-49
Lead Emissions Methodology
Category: 12-01
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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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
5-50
Lead Emissions Methodology
Category: 12-01
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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
GSPV
GSP:
95 —
growth factor for year v
gross state product for year y
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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6-1
1997-2010 Methodology
Projections
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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 HI 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 m MACT controls. The
stringency of the Title El 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 HI 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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Procedures Document for 1900-1996
6-2
1997-2010 Methodology
Projections
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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, SO* 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 1-0 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.* 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:
EAFy = Cy/C95
where: EAR,
-95
= efficiency adjustment factor for projection year y
= consumption per unit output for projection year y
= 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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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1997-2010 Methodology
Projections
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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.l 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:
EAF=CFJCFt
95
where: EAFy
CR.
CF,
95
efficiency adjustment factor for projection year y
consumption factor for projection year y
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
L 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
Procedures Document for 1900-1996
6-4
1997-2010 Methodology
Projections
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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
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6-5
1997-2010 Methodology
Projections
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Table 6.2-2. Point Source VOC Controls
Source Category
VOC Control
Efficiency lo>
National Rules
Marine vessel loading: petroleum liquids
TSDFs
Benzene NESHAP (national)
By-product coke mfg
By-product coke - flushing-liquor circulation tank
By-product coke - excess-ammonia liquor tank
By-product coke mfg. - tar storage
By-product coke mfg. - light oil sump
By-product coke mfg. - light oil dec/cond vents
By-product coke mfg. - tar bottom final cooler
By-product coke mfg. - naphthalene processing
By-product coke mfg. - equipment leaks
By-product coke manufacture - other
By-product coke manufacture - oven charging
Coke ovens - door and topside leaks
Coke oven by-product plants
2-Year MACT (national)
Synthetic Organic Chemical Manufacturing Industry (SOCMI) HON
- SOCMI processes
- VOL storage
— SOCMI fugitives (equipment leak detection and repair)
- SOCMI wastewater
- Ethylene oxide manufacture
— Phenol manufacture
- Acrylonitrile manufacture
- Polypropylene manufacture
— Polyethylene manufacture
- Ethylene manufacture
Dry Cleaning
- Perchloroethylene
-Other
4-Year MACT (national)*
TSDFs (offsite waste operations)
Shipbuilding and repair
Polymers and resins II
Polymers and resins IV
Styrene-butadiene rubber manufacture (polymers & resins group I)
Wood furniture surface coating
Aircraft surface coating (aerospace)
80
96
85
95
98
98
98
98
81
100
83
94
94
94
94
79
95
60
0
98
98
98
98
98
98
95
70
96
24
78
70
70
30
60
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-6
1997-2010 Methodology
Projections
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Table 6.2-2 (continued)
Source Category
VOC Control
Efficiency (%)
Petroleum Refineries: other sources
- Fixed roof petroleum product tanks
- Fixed roof gasoline tanks
- External floating roof petroleum product tanks
- External floating roof gasoline tanks
- Petroleum refinery wastewater treatment
- Petroleum refinery fugitives
- Petroleum refineries - Slowdown w/o control
- Vacuum distillation
Halogenated Solvent Cleaners
- Open top degreasing - halogenated
- In-line (conveyorized) degreasing - halogenated
Printing
- Flexographic
- Gravure
Gasoline Marketing
- Storage
- Splash loading
- Balanced loading
- Submerged loading
- Transit
- Leaks
7/10-Year MACT (national)
Paint and varnish manufacture
Rubber tire manufacture
Green tire spray
Automobile surface coating
Beverage can surface coating
Paper surface coating
Flatwood surface coating
Fabric printing
Metal surface coating
Plastic parts surface coating
Pulp and paper production
Agricultural chemical production
Pharmaceutical production
Polyesters
Fabric coating
Petroleum refineries - fluid catalytic cracking
Oil and natural gas production
Explosives
98
96
90
95
72
72
78
72
63
39
32
27
5
99
87
99
5
39
35
70
90
79
57
78
90
80
90
45
70
79
79
70
70
70
90
70
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-7
1997-2010 Methodology
Projections
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Table 6.2-2 (continued)
Source Category
VOC Control
Efficiency'0'
Plywood/particle board
Reinforced plastics
7/10-Year MACT (national) (continued)
Publicly-owned treatment works (POTWs)
Phthalate plasticizers
Polymers and resins III
Rayon production
Polyvinyl chloride
Spandex production
Nylon 6 production
Alkyd resins
Polyester resins
Chelating agents
New CTGs (moderate and above)
SOCMI reactor
SOCMI distillation
Printing - lithographic
Non-CTG and Group III CTG RACT (moderate and above)*
Carbon black manufacture
Whiskey fermentation - aging
Charcoal manufacturing
Cold cleaning
Bakeries
Urea resins - general
Organic acids manufacture
Leather products
CTG RACT (marginal and above)**
Terephthalic acid manufacture
Cellulose acetate manufacture
Vegetable oil manufacture
Dry cleaning - stoddard
Stage I - splash unloading
Stage I - submerged unloading
Open top degreasing
In-line (conveyorized) degreasing
Petroleum refineries - blowdown
70
70
70
70
78
70
70
70
70
70
70
70
85
85
44
90
85
80
63
95
90
90
90
98
54
42
70
95
95
42
42
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
Procedures Document for 1900-1996
6-8
1997-2010 Methodology
Projections
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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
NGR = Natural gas reburning
SNCR = Selective noncatalytic reduction
IR = Ignition timing retardation
AF = Air/Fuel adjustment
ULNB = Ultra-low NOX burners
Control Strategy
LNB
LNB
LNB
LNB
None
NGR
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
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1997-2010 Methodology
Projections
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Table 6.2-4. EAFs for Industrial Sector
RATIO
CODE
SC
RO
DO
NG
RE
MCC
OP
LP
RATIO
CODE
ROO
RNG
RRE
ROF
RLP
COO
CNQ
ORE
COF
NAME
Steam Coal - Industrial
Residual Oil - Industrial
Distillate Oil - Industrial
Natural Gas - Industrial
1999
0.977
0.667
1.000
0.976
Renewables (hydroelectric, wood, wood waste, solid waste) - Industrial 0.979
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
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
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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
Procedures Document for 1900-1996
6-11
1997-2010 Methodology
Projections
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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 Units Oil-Fired Units Gas-Fired Units
Heat Rate (Btu/kWh) 10,070
Capacity Utilization Factor 0.90
9,680
0.20
9,680
0.90
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.
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.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-12
1997-2010 Methodology
Projections
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• 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 n
limits, and New Source Performance Standard (NSPS) NOX regulations.
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. .
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-13
1997-2010 Methodology
Projections
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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 n 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 n 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 fl 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 hy coal plants.
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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-14
1997-2010 Methodology
Projections
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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
Capital
O&M (total fixed + variable)
0.11 (11 percent per year)
154.26 $/kW (1995 dollars)
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 n standards, and any further reductions are typically found to
be uneconomic.
6.3.5 Other Issues
6.3.5.1 Particulate 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
were directly ratioed to calculate new PM emission levels. This was done for both PM-10 and for every
boiler where fuel switching occurred.
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-15
1997-2010 Methodology
Projections
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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
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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 Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
Coal
Oil
Natural Gas
1995
450.36
1.56
3.62
93.86
2.24
80.34
104.45
6.40
11.29
127.70
1.07
4.12
108.65
0.70
1.35
25.84
7.86
23.43
16.22
11.20
13.76
58.84
21.58
35.39
340.16
2.16
9.58
154.55
0.90
83.54
74.07
0.11
5.73
83.33
0.12
5.27
32.51
1.37
41.38
1996
451.71
2.44
8.88
98.23
0.59
95.70
98.70
7.33
15.16
131.75
1.58
10.09
99.98
0.89
3.63
23.25
4.70
17.18
16.11
9.00
15.05
60.32
22.71
28.19
342.22
5.30
13.52
159.73
0.92
74.38
72.33
0.08
2.46
89.18
0.18
11.81
36.37
0.85
26.97
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
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Table 6.3-3. Title IV or RACT NOX 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
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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 IE vapor recovery, federal consumer
solvent controls, and Title DIMACT 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 proced'ure 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
Procedures Document for 1900-1996
6-19
1997-2010 Methodology
Projections
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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 (or 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
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Table 6.4-2. Area Source Industrial Fuel Combustion NOX PACT 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
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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 MOBHJE5b 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.
PYVTiM
VMI
95,vr,us
where: VMTGFPY(VTiM
VMTpY>VTjUS
VMT9SiVTiUS
POP95
-------
used the 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 (QMS), 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 PARTS 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 H 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.
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Procedures Document for 1900-1996
6-23
1997-2010 Methodology
Projections
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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 MOBELESb 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 MONTH Flag
When modeling months from January through June for the projection years, the MONTH flag
within the MOBUJESb 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 MOBJUBSb 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 QMS
I/M program summary sheet.5 In consultation with QMS, 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
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-24
1997-2010 Methodology
Projections
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program 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 CAAAI7M program. These data were used in the Trends emission projection calculations by
assigned the I/M programs defined in the QMS I/M program summary for a given state to the counties
within that state listed as having a projected UM 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 arid 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.
Federal Tier I Transitional LEV
Model Year Standards Standards LEV Standards
1999
2000
2001 and later
30%
40%
40%
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
Procedures Document for 1900-1996
6-25
1997-2010 Methodology
Projections
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Model
Year
Federal Tier I
Standards
TLEV Standards
Intermediate LEV
Standards
Intermediate
LEV Standards ULEV Standards ULEV Standards
1996
1997
1998
80%
73%
47%
20%
25%
2%
51%
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 FM 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.
Emission Standard Nonmethane Organic Gas (NMOG)
CO
NO,
Federal Tier 1
Transitional LEV (TLEV)
LEV-
ULEV
0.250 grams/mile
nonmethane hydrocarbon (NMHC)
0.125 grams/mile
0.075 grams/mile
0.040 grams/mile
3.4 grams/mile 0.40 grams/mile
3.4 grams/mile 0.40 grams/mile
3.4 grams/mile 0.20 grams/mile
1.7 grams/mile 0.20 grams/mile
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
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1997-2010 Methodology
Projections
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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
NOX
ZML DR
Model Year (g/bhp-hr) (g/bhp-hr/10kmi)
1998+ 3.19 0.045
1994 +
1994-
2003
voc
ZML
(g/bhp-hr)
0.364
0.283
DR
(g/bhp-hr/10kmi)
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 MOBILESb, 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."
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Procedures Document for 1900-1996
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1997-2010 Methodology
Projections
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Vehicle
Category
HDDV
Model Year
2004 +
ZML
(g/bhp-hr)
1.84
NOX
DR
(g/bhp-hr/10kmi)
0.000
voc
ZML
(g/bhp-hr)
0.257
DR
(g/bhp-hr/10kmi)
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 MOBILE5a,
referred to as CALI5, was used for California. Input files used with this model are essentially identical
to MOBILBSa input files, and the model internally handles the different emission standards.
Phase n 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 CALK 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
1 areas modeled with the high enhanced FM 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. MOBILESb 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
Procedures Document for 1900-1996
6-28
1997-2010 Methodology
Projections
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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 Ill-
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
Procedures Document for 1900-1996
6-29
1997-2010 Methodology
Projections
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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
2BHDDV
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
198
4,203
16,241
131,184
8,105
11,476
2,691,564
1,809,586
491 ,886
250,592
62,357
3,529
2,028
171,272
213
4,502
17,393
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
4,951
19, 128
154,504
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
163,704
10,114
12,868
3,092,846
1,995,184
572,088
291 ,450
73,547
463
1,327
205,21 1
256
5,395
20,840
168,320
10,400
13,076
3,152,346
2,059,873
599,170
305,248
77,537
65
1,264
216,487
270
5,692
21,985
177,569
10,972
13,499
3,273,747
National Air Polluiant Emission Trends
Procedures Document for 1900-1996
6-30
1997-2010 Methodology
Projections
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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
69,81 1
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
3,152,346
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
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Procedures Document for 1900-1996
6-31
1997-2010 Methodology
Projections
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Table 6.5-3. Monthly RVP Values Modeled in Projection Years
(in psi)
Slate
AL
AL
AK
AZ
A2
AR
CA
CO
CT
DE
DC
FL
FL
FL
GA
GA
HI
10
IL
IN
IA
KS
KY
LA
LA
LA
ME
MO
MO
MD
MO
MD
MA
Ml
MN
MS
MO
MO
MT
NE
NV
NV
NH
NJ
NM
NY
NC
NC
NC
NC
NO
OH
OK
OR
OR
Nonattalnment 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 Plm 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
Rost of State
Entire State
Entire State
Reno
Rest of State
Entire State
Entire State
Entire State
Entire State
Charlotte-Gastonta
Greensboro
Raleigh-Durham
Rest of State
Entire State
Entire State
Entire State
Portland-Vancouver
Rost 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
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
-------
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Table 6.5-5. Average Speeds by Road Type and Vehicle Type
(MPH)
Rural
LDV
LOT
HDV
Interstate
60
55
40
Principal
Arterial
45
45
35
Minor Major Minor
Arterial Collector Collector Local
40
40
30
35 30 30
35 30 30
25 25 25
Urban
LDV
LOT
HDV
Interstate
45
45
35
Other Freeways
& Expressways
45
45
35
Principal Minor
Arterial Arterial Collector
20 20 20
20 20 20
15 15 15
Local
20
20
15
Table 6.5-6. State-Supplied Trip Length Distribution Inputs
Percentage of Total VMT
Nonattainment Area
Washington, DC/MD/VA
Baltimore
Houston
Dallas
<10
Minutes
16.6
15.1
14.8
9.8
11 to 20
Minutes
33.9
31.7
27.9
19
21 to 30
Minutes
23.4
26
22.4
23.8
Accumulated in Trips of:
31 to 40
Minutes
13.3
13.3
14.3
19.4
41 to 50
Minutes
6.1
6.5
8.5
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
1978
1967-2020
TO
Biennial
YES
YES
YES
YES
Idle Test
220/1.2/999
1.00/1.00/1.00
I/M Program Control Flag Record
Technical Training and Certification Program
Remote Sensing Device Inspections Program
I/M 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 Outpoints 220/1.2/999 220/1.2/999
Effectiveness Rates (% HC/CO/NOJ 0.85/0.85/0.85 0.85/0.85/0.85
I/M 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)
Anti-Tamperinq 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
0.85/0.85/0.85 0.85/0.85/0.85
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
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
!/M Program
Name
Included Counties
AKIM991 Anchorage Ed
AKIM992 Fairbanks Ed
AZ1M991 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
CO1M992 Pitkin Co, El Paso Co, Larimer Co, Weld Co
CTIM99 Fairfield Co, Hartford Co, Litchfieid 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
6AIMG02 Cherokee Co, Clayton Co, Coweta Co, Douglas Co, Fayette Co, Forsylh Co, Henry Co, Paulding Co,
Rockdale Co
GAIM021 Cobb Co, De Kalb Co, Fulton Co, Gwinnett Co
GAIMQ22 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
GA1M992 Cherokee Co, Clayton Co, Coweta Co, Douglas Co, Fayette Co, Forsyth Co, Henry Co, Paulding Co,
Rockdale Co
IDIM99 Ada Co
1LIM991* Cook Co, Du Page Co, Lake Co, Madison Co, St. Glair Co
ILIM992* Kane Co, Kendall Co, McHenry Co, Will Co, Monroe Co
1NIM99* 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
MDiMOOl* Anne Arundel Co, Baltimore Co, Carroll Co, Harford Co, Howard Co, Baltimore, Montgomery Co, Prince
Georges Co
MOIM002* Calvert Co, Cecil Co, Queen Annes Co, Charles Co, Frederick Co, Washington Co
MOIM021* 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
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
MDIM991*
MDIM992*
ME1M99
MNIMOO
MNIN02
MNIN99
MOIM02
MOIM99
NCIM991
NCIM992
NC1M993
NCIM994
NH1M99
NJIM99
NMIM99
NVIM99
NYIM001
NYIM002
NYIM021
NYIM022
NYIM993
OHIM001*
OHIM002*
OHIM021*
OHIM022*
OHIM991*
OHIM992*
ORIM991*
ORIM992*
PAIM991
PAIM992
Anne Arundel Co, Baltimore Co, Carroll Co, Harford Co, Howard Co, Baltimore, Montgomery Co, Prince
Georges Co
Calvert Co, Cecil Co, Queen Annes Co, Charles Co, Frederick Co, Washington Co
Cumberland Co
Anoka Co, Carver Co, Dakota Co, Hennepin Co, Ramsey Co, Scott Co, Washington Co
Anoka Co, Carver Co, Dakota Co, Hennepin Co, Ramsey Co, Scott Co, Washington Co
Anoka Co, Carver Co, Dakota Co, Hennepin Co, Ramsey Co, Scott Co, Washington Co
Jefferson Co, St. Charles Co, St. Louis Co, St. Louis
Jefferson Co, St. Charles Co, St. Louis Co, St. Louis
Mecklenburg Co
Durham Co, Wake Co
Forsyth Co, Guilford Go, Gaston Co
Cabarrus Co, Union Co, Orange Co
Hillsborough Co, Rockingham 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
Bernalillo Co
Clark Co, Washoe Co
Bronx Co, Kings Co, Nassau Co, New York Co, Queens Co, Richmond Co, Rockland Co, Suffolk Co,
Westchester Co
Orange Co
Bronx Co, Kings Co, Nassau Co, New York Co, Queens Co, Richmond Co, Rockland Co, Suffolk Co,
Westchester Co
Orange 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, 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
Clermont Co, Geauga Co, Medina Co, Portage Co, Summit Co, Warren Co, Butler Co, Hamilton Co, Lake
Co, Lorain Co, Cuyahoga Co
Clark Co, Greene Co, Montgomery Co
Clermont Co, Geauga Co, Medina Co, Portage Co, Summit Co, Warren Co, Butler Co, Hamilton Co, Lake
Co, Lorain Co, Cuyahoga Co
Clark Co, Greene Co, Montgomery Co
Clermont Co, Geauga Co, Medina Co, Portage Co, Summit Co, Warren Co, Butler Co, Hamilton Co, Lake
Co, Lorain Co, Cuyahoga Co
Clark Co, Greene Co, Montgomery Co
Jackson Co, Josephine Co
Clackamas Co, Multnomah Co, Washington Co
Lehigh Co, Northampton Co
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
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
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
TN1M992 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
VA1M991 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
WAIMQ01 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
WHM992* Sheboygan Co . .
"Indicates 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
\/M Program Parameters
Program Start Year
Stringency Level (Percent)
Model Years Covered
Waiver Rate for Pre-1 981 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/NOJ
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 (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 Low Enhanced I/M High Enhanced I/M
Performance Standard Performance Standard 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
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
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
1 986-2020
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
LDQV
LDGT1
LDGT2
HOGV
Program Type
Inspection Frequency
Compliance Rate (%)
Purge Test Program Parameters
Program Start Year
Model Years Covered
Effectiveness Rate
Vehicle Types Tested
LDGV
LD6T1
LDGT2
HDGV
Program Type
Inspection Frequency
Compliance Rate (%)
Years ol 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
County
Basic Alaska Fairbanks Ed
Arizona Pima Co
Colorado Pitkin Co, El Paso Co, Larimer Co, Weld Co
Florida Broward Co, Dade Co, Duval Co, Hillsborough Co, Palm Beach Co, Pinellas Co
Idaho Ada Co
Kentucky Boyd Co, Greenup Co, Boone Co, Campbell Co, Kenton Co, Jefferson Co
Minnesota Anoka Co, Carver Co, Dakota Co, Hennepin Co, Ramsey Co, Scott Co, Washington Co
New Mexico Bernaliilo Co
North Carolina Cabarrus Co, Union Co, Orange Co, Forsyth Co, Guilford Co, Durham Co, Gaston Co,
Mecklenburg Co, Wake Co
Tennessee Rutherford Co, Sumner Go, 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 Anchorage Ed
Arizona Maricopa Co
California 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, Mann 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
Colorado Adams Co, Arapahoe Co, Boulder Co, Douglas Co, Jefferson Co, Denver CO
Connecticut Fairfield Co, Hartford Co, Litchfield Co, Middlesex Co, New Haven Co, New London Co,
Tolland Co, Windham Co
~ DC Washington
National Air Pollutant Emission Trends
Procedures Document for 1900-1996
6-45
1997-2010 Methodology
Projections
-------
Table 6.5-10 (continued)
VM Performance
Standard Modeled
State
County
High Enhanced
(continued)
Georgia 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
Illinois Cook Co, Du Page Co, Lake Co, Kane Co, Kendall Co, McHenry Co, Will Co, Madison Co,
St. Clair Co, Monroe Co
Indiana Clark Co, Floyd Co, Lake Co, Porter Co
Maryland 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
Massachusetts 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
Missouri Jefferson Co, St. Charles Co, St. Louis Co, St. Louis
New Hampshire Hillsborough Co, Rockingham Co, Stratford Co
New Jersey 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
New York Bronx Co, Kings Co, Nassau Co, New York Co, Queens Co, Richmond Co, Rockland Co,
Suffolk Co, Westchester Co, Orange Co
Ohio 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
Oregon
Pennsylvania
Rhode Island
Texas
Virginia
Wisconsin
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 J 900-1996
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
Portsrnouth-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 YorR-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)
Phiiadelphia-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
Vehicle
Type
HDGV
LDGT2
LDGT2
_ „ . . LEV
Pollutant Credits
NO,
NO,
NO,
NO,
NO,
VOC
VOC
VOC
VOC
VOC
VOC
VOC
VOC
VOC
VOC
VOC
CO
CO
CO
CO
CO
CO
CO
NO,
NO,
NO,
NO,
NO,
VOC
VOC
VOC
VOC
VOC
VOC
VOC
CO
CO
CO
CO
CO
CO
CO
NO,
NO,
NO,
NO,
NO,
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 (n
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 +
Deterioration Rate
ero Mile Level
3Vs: g/bhp-hr) <50,000 mi >50,000 mi
(LDVs: g/mi) (HDVs: G/bhp-hr/10 kmi) (HDVs: g/bhp-hr/10 kmi)
(LDVs: g/mi/10 kmi) (LDVs: g/mi/10 kmi)
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
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
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-J 996
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 QMS 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
Procedures Document for 1900-1996
6-51
1997-2010 Methodology
Projections
-------
represented by each of these 27 SCCs was calculated for each of the 27 areas for which QMS 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.
QMS 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 n 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 Nizicri, 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.
1997-2010 Methodology
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 SIC Name
999* Population
15 Construction
998* Total Manufacturing
999* Population
01 Farm
998* Total Manufacturing
07 Agricultural Services, Forestry, Fisheries,
and Other
45 Transportation by Air
45 Transportation by Air
992* Federal, military
LTO* Landing-Takeoff Operations
44 Water Transportation
999* Population
992* Federal, military
40 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
03
OS
06
08
06
06
06
06
06
08
OS
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*
LTO*
01
07
15
40
44
45
992*
998*
999'
LTO*
01
07
15
40
44
45
992*
998"
999*
LTO*
01
07
15
40
44
45
992*
998'
999'
LTO*
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*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
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)
Slate
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
ao
20
20
20
21
SIC
44
45
992*
998*
999*
LTO*
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*
LTO*
01
07
15
40
44
45
992*
998*
999'
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO'
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
Ii536
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*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
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)
Slate
Code
28
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'
LTO'
01
07
15
40
44
45
992'
998'
999'
LTO'
01
07
15
40
44
45
992'
998*
999'
LTO'
01
07
15
40
44
45
992*
998'
999'
LTO'
01
07
15
40
44
45
992'
998'
999'
LTO'
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 J900-1996
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*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
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
.358
.268
.495
.020
.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*
LTO'
01
07
15
40
44
45
992'
998'
999'
LTO'
01
07
15
40
44
45
992'
998*
999'
LTO'
01
07
15
40
44
45
992'
998'
999'
LTO'
01
07
15
40
44
45
992'
998*
999'
LTO'
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*
LTO*
01
07
15
40
44
45
992*
998*
999*
LTO*
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
.079
.182
.187
.362
,115
.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
SO
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
58
56
SIC
992'
998'
999'
LTO'
01
07
15
40
44
45
992*
998'
999'
LTO'
01
07
15
40
44
45
992'
998'
999*
LTO'
01
07
15
40
44
45
992'
998*
999'
LTO'
01
07
15
40
44
45
992'
998*
999'
LTO'
01
07
15
40
44
45
992'
998'
999'
LTO'
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.Q72
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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TECHNICAL REPORT DATA
(PLEASE READ INSTRUCTIONS .ON THE REVERSE BEFORE COMPLETING)
1. REPORT NO.
EPA-454/R-98-008
3. RECIPIENT'S ACCESSION NO.
4. TITLE AND SUBTITLE
NATIONAL AIR POLLUTANT EMISSION TRENDS PROCEDURES
DOCUMENT. 1990-1996 AND 1999-2010
5. REPORT DATE
6/1/98
6. PERFORMING ORGANIZATION CODE
USEPA/OAQPS/EMAD/EFIG
7. AUTHOR(S)
SHARON V. NIZICH./AND E. H. PECHAN & ASSOCIATES
8. PERFORMING ORGANIZATION REPORT NO.
9. PERFORMING ORGANIZATION NAME AND ADDRESS
U. S. ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF AIR QUALITY PLANNING AND STANDARDS
EMISSION FACTOR AND INVENTORY GROUP (MD-14)
RESEARCH TRIANGLE PARK, NORTH CAROLINA 27711
10. PROGRAM ELEMENT NO.
11. CONTRACT/GRANT NO.
68-D7-0067
12. SPONSORING AGENCY NAME AND ADDRESS
DIRECTOR, OFFICE OF AIR QUALITY PLANNING AND STANDARDS
OFFICE OF AIR AND RADIATION
U.S. ENVIRONMENTAL PROTECTION AGENCY
RESEARCH TRIANGLE PARK, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
TECHNICAL 1900-1996, 1999-2010
14. SPONSORING AGENCY CODE
EPA/200/04
15. SUPPLEMENTARY NOTES
16. ABSTRACT
The Emission Factor and Inventory Group (EFIG) annually produces a publication on the trends in emissions of
criteria pollutants. These publications are needed by the States to evaluate emission trends in each State and to
compare emission trends among the States. The latest such report, entitled National Air Pollutant Emission Trends
1900-1996 (EPA-454-R-97-011) was published in December 1997. Data from this report has also been used for the
Biennial Assessment report, the Air Quality Trends report, the Industrial SO2 Report to Congress, and the 1994 Report
to Congress. The emission estimates developed and included in the Emission Trends data base have been utilized to
support development of the National Particulates Inventory, in support of recent evaluations of the particulate matter
and ozone NAAQS, in support of the FACA process, and in support of the CAA Section 812 retrospective analysis.
The enclosed procedures document provides information on the methods and data used in the beforementioned report
. Methods for calculating 1900-1996 and projecting estimates for 1999-2010 are also included.
KEYWORDS/DESCRIPTORS: CRITERIA AIR POLLUTANT, EMISSION TRENDS,
17.
KEYWORDS AND DOCUMENT ANALYSIS
a. DESCRIPTORS
AIR EMISSION TRENDS NITROGEN OXIDES
AIR POLLUTION OZONE
AMMONIA PARTICULATE MATTER
BIOGENICS _ SULFUR DIOXIDE
CANADA TOTAL SUSPENDED PARTICULATE
CARBON MONOXIDE VOLATILE ORGANIC COMPOUNDS
NITROGEN DIOXIDE
b. IDENTIFIERS/OPEN ENDED TERMS
AIR POLLUTION CONTROL
AIR POLLUTION RESEARCH
AIR POLLUTION TRENDS
c. COSATI FIELD/GROUP
18. DISTRIBUTION STATEMENT
UNLIMITED
UNCLASSIFIED
21. NO. OF PAGES
712
22. PRICE
UNCLASSIFIED
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