DEVELOPMENT OF MODELING INVENTORY AND BUDGETS
FOR REGIONAL NOx SIP CALL
U. S. Environmental Protection Agency
Office of Air Quality Planning and Standards
September 24, 1998
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Chapter I
Introduction
Table of Contents
l
Chapter II
Electric Generating Unit Point Source Data 3
A. Development of Base Year Data 3
B. 2007 Base Case 7
C. 2007 Budget Case 7
D. EGU Emission Summary 8
Chapter III
Non-EGU Point Source Data 11
A. Development of Base Year Data 11
B. 2007 Base Case 11
C. 2007 Budget Case 12
D. Non-EGU Emission Summary 14
Chapter IV
Stationary Area and Nonroad Source Data 29
A. Development of Base Year Data 29
B. 2007 Base Case 29
C. 2007 Budget Case 30
D. Stationary Area and Nonroad Emission Summary 30
Chapter V
Highway Vehicle Source Data 33
A. Development of Base Year Data 33
B. 2007 Base Case 33
C. 2007 Budget Case 34
D. Highway Vehicle Emission Summary 34
Chapter VI
Statewide NOx Budgets 37
APPENDIX A
2007 BASE CASE CONTROLS
APPENDIX B
NON-EGU POINT SOURCE CATEGORY CODES
APPENDIX C
SOURCE SPECIFIC EGU BASE AND BUDGET EMISSIONS FILE
APPENDIX D
SOURCE SPECIFIC NON-EGU POINT SOURCE BASE AND BUDGET EMISSIONS FILE
APPENDIX E
COUNTY LEVEL STATIONARY AREA BASE AND BUDGET EMISSIONS FILE
APPENDIX F
COUNTY LEVEL NONROAD MOBILE BASE AND BUDGET EMISSIONS FILE
APPENDIX G
COUNTY LEVEL HIGHWAY MOBILE BASE AND BUDGET EMISSIONS FILE
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Chapter I
Introduction
The purpose of this document is to describe the development of the emissions and control
data used in the United States (U.S.) Environmental Protection Agency's (EPA) Regional NOx
State Implementation Plan (SIP) Call Final Rulemaking (NFR) and to describe the process for
calculation of the associated Statewide budgets.
Chapter II of this document describes the development of the EGU point source data and
budget, Chapter III describes the development of the non-EGU point source data and budget,
Chapter IV describes the stationary area and nonroad mobile source data and budget, and
Chapter V describes the highway mobile source data and budget.
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Chapter II
Electric Generating Unit Point Source Data
A. Development of Base Year Data
The base year electric generating unit (EGU) data base developed for this modeling effort
consists of both electric utility units and nonutility electricity generating units. The nonutility
electricity generating units include independent power producers (IPPs) and nonutility
generators (NUGs). Two alternative base year data sets were developed: one using the higher of
1995 or 1996 heat input (determined at the State-level) and one using 1996 heat input. For each
base year data set both seasonal (for budget determination) and daily emission estimates (for
modeling) were developed.
Eight data sources were used to develop the base year EGU data:
1. EPA's Acid Rain Data Base (ARDB) (Pechan, 1997c);
2. EPA's 2007 Integrated Planning Model Year 2007 (IPM);
3. EPA's Emission Tracking System/Continuous Emissions Monitoring System
(ETS/CEM) (EPA, 1997b);
4. DOE's Form EIA-860 (DOE, 1995a);
5. DOE's Form EIA-767 (DOE, 1995b);
6. EPA's National Emissions Trends Data Base (NET) (EPA, 1997c);
7. DOE's Form EIA-867 (DOE, 1995c); and
8. The OTAG Emission Inventory (Pechan, 1997a).
Each of these data sources is described below.
EPA's Acid Rain Data Base (ARDB) was developed in response to the Acid Rain
Program authorized under Title IV. The data base was originally an update to the boiler-based
National Allowance Data Base Version 3.11 (NADBV311) which was used in the calculation of
the S02 allowances as specified in Title IV. Over the last few years, the data base has been
expanded to include ETS/CEM 1994-1996 S02, NOx, C02, and heat input; as well as 1985-1995
NET utility data, boiler identification, characteristics, and locational data. The existing boilers
and planned turbines (as of 1990) in the ARDB are used as units for the EGU.
EPA's 2007 Integrated Planning Model Year 2007 (IPM) data base represents a unit-
level disaggregated IPM Clean Air Act (CAA) baseline simulation developed for OTAG
modeling. The IPM includes over 7,000 records (nationally) with data on existing electricity
generating units. The records are maintained in EPA's National Electric Energy Data System
(NEEDS). In general, generator-level utility turbines and engines, as well as nonutility units that
are not required to report to EPA under the Title IV program, are used as units for the EGU.
Supplemental data, provided by EPA, including the start year, the base year (1994) NOx rate, and
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type of ownership, were added to the IPM data base. This file was used to obtain NOx emissions
and heat input data for these units. Where units could be matched to other inventories, actual
locational data are included in the IPM; otherwise, county centroids are used.
EPA's Emission Tracking System/Continuous Emissions Monitoring System
(ETS/CEM) data contains hourly S02, C02, NOx rate, and heat input data at the monitoring stack
level and boiler level for all boilers included in the Acid Rain Program that was mandated by
Title IV of the Clean Air Act Amendments of 1990 (CAAA). In 1994, data were collected from
the 263 Phase I boilers; beginning in 1995, data are collected from Phase II as well as Phase I
affected boilers. These data were used for NOx tons and heat input. Data were provided in a
variety of files from EPA.
DOE's Form EIA-860 is an annual utility survey, "Annual Electric Generator Report,"
that provides utility data on a generator level. Both existing and planned generators are reported;
the data include generator identification data, status, capacity, prime mover, and fuel type(s).
Units reported on this form were generally only included in the EGU file if they also were
included in the IPM file since NOx tons and heat input are not derivable from Form EIA-860
alone. This form was useful, however, in providing other information, such as prime mover and
unit status.
DOE's Form EIA-767 is an annual survey, "Steam-Electric Plant Operation and Design
Report," that contains data for fossil fuel steam boilers such as fuel quantity and quality; boiler
identification, locational, status, and design information; and FGD scrubber and particulate
collector device information. Note that boilers in plants with less than 10 MW do not report all
data elements. The relationship between boilers and generators is also provided, along with
generator-level generation and nameplate capacity. Note that boilers and generators are not
necessarily in a one-to-one correspondence.
EPA's NET fossil fuel steam data base has been developed for EPA for many years. The
data base is initially based on DOE's Form EIA-767 data, but the coal NOx emissions have been
superseded by calculations using EPA NOx rates, and the NOx, S02 and heat input data from
ETS/CEM are always used if available. Source Classification Codes (SCCs) are assigned to
each boiler based on boiler and fuel characteristics; AP-42 emission factors are always used to
calculate VOC, CO, PM10, and PM2.5 emissions. The 1990 and 1995 Trends data bases were
used to obtain SCCs, stack parameters, and NOx tons and heat input.
DOE's Form EIA-867 ("Annual Nonutility Power Producer Report") is similar in content
to, although more limited than, the utility Forms EIA-860 and EIA-767. The EIA-867, however,
is a confidential form, and aside from the facility identification data (which includes State and
capacity), EIA can only provide most data from this form on an aggregated basis. Only a few of
the records from this file were ultimately used since it was difficult to obtain NOx tons, heat
input, or locational data unless they matched to another source.
The OTAG data base was developed by collecting and compiling electric utility emission
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inventory data from States in the OTAG domain. This inventory is for the year 1990 and
contains summer day emission estimates, as well as variables required for photochemical
modeling. This data base was used to obtain NOx and locational data.
In general, the operating units in the ARDB identified the steam boilers, while the IPM
data base identified the generator-level utility turbines and engines, as well as the nonutility
units. While some units originated in the other data bases, their primary purpose was to add
variables required for modeling to the units identified by the ARDB or IPM data.
The data from the above sources was further refined by the consideration of comments
submitted to the NOx SIP call NPR.
In order for a unit to be used, it had to have enough data to estimate emissions. Data had
to be available on either daily or seasonal heat input or daily or seasonal NOx emissions. The
NOx emission rate was also required, but a default NOx emission rate from AP-42 was assigned
to units that had data on heat input or emissions, and no NOx rate. The emissions from 421 units
could not be estimated because there was no NOx emissions or heat input information available
to EPA for these units. This suggests that these units may not have operated in the summer
seasons of 1995 and 1996.
The first step in developing the base year data was to develop a file containing all
available heat input, NOx emissions and NOx rate information.
1. Seasonal NOx Tons and Heat Input
The hierarchy for obtaining seasonal NOx tons and heat input for a particular unit is provided
below.
For the 1995/1996 base year:
1. Determine what year of data to use for a given boiler, based on the State that the
boiler is in and whether 1996 or 1995 heat input was higher for that State.
2. Based on that boiler year information, use ETS/CEM data to obtain 1996 seasonal
NOx tons and 1996 seasonal heat input, or 1995 seasonal NOx rate and 1995
seasonal heat input to calculate 1995 seasonal NOx tons.
3. Based on that boiler year information, use the 1996 projected or 1995 NET data
base (Both of which include annual boiler-level ETS/CEM data) for annual NOx
tons and heat input, then convert to seasonal.
4. Use 1990 OTAG file for ozone season day (OSD) NOx tons and OSD heat input
(or July month heat input and divide by 31), then convert to seasonal and forecast.
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5. Use IPM N0X rate and 2007 July heat input, calculate NOx tons, convert to
seasonal, and backcast.
6. If there is a heat input and no NOx tons or rate, assign an AP-42 default NOx rate
based on SCC and convert to seasonal.
For 1996 base year:
1. Use ETS/CEM 1996 file for seasonal NOx tons and 1996 seasonal heat input.
2. Use the 1996 projected or 1995 NET data base (both of which include annual
boiler-level ETS/CEM data) for annual NOx tons and heat input, then convert to
seasonal.
3. Use 1990 OTAG file for OSD NOx tons and OSD heat input (or July month heat
input and divide by 31), then convert to seasonal and forecast.
4. Use IPM NOx rate and 2007 July heat input, calculate NOx tons, convert to
seasonal, and backcast.
5. If there is a heat input and no NOx tons or rate, assign an AP-42 default NOx rate
based on SCC and convert to seasonal.
2. Source Classification Codes (SCCs)
The methodology for assigning SCC is as follows:
1. Match with NET 1995 or 1990 inventory and assign the major SCC (based on
heat input) to the boiler.
2. Match with OTAG and assign the major SCC.
3. Assign default SCCs based on prime mover, fuel type, and (in the case of steam
units) boiler bottom and firing types.
3. Stack Parameters
The methodology for obtaining stack parameters is as follows:
1. Match with NET 1995 or 1990 inventory and use the stack data.
2. Match with OTAG and use the stack data.
3. Assign default stack parameters, based on prime mover and fuel type, that were
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originally developed for the Regional Oxidant Model (ROM). (Note that since
stack parameters in IPM were originally developed by matching with OTAG and
NET inventories, followed by defaults, any stack parameters obtained from IPM
are likely to be default parameters.)
B. 2007 Base Case
The 2007 base case summer season emissions for 2007 were determined using the
Integrated Planning Model (IPM). The base case includes all applicable controls required by the
CAAA. Applicable controls required for EGUs include Title IV Acid Rain controls and NOx
RACT. Details regarding the IPM model and the method can be found in the Regulatory Impact
Analysis (RIA) of the final SIP call (EPA, 1998c). The seasonal unit-specific data for 2007
output from the IPM model was processed using the Emissions Modeling System-95 (EMS) to
generate typical ozone season weekday, Saturday, and Sunday allocations for episodic modeling.
Appendix A presents the EGU source controls included in the 2007 base case.
C. 2007 Budget Case
The 2007 budget case was developed by applying growth factors and an emission rate to
the 1995/1996 base year heat input. Units greater than 25 MWe in the SIP call region had a
uniform emission rate of 0.15 lb NOx/MMBtu applied to them. Units 25MWe or smaller were
left at their 2007 base case NOx emission rate. A detailed file of EGU sources including
emissions, growth, and control information used to estimate the 2007 EGU budget is provided in
Appendix C of this document.
1. Growth Factors
The growth factors used in the 2007 base case were supplied by EPA and came from the
IPM projections. The growth factors are at the State-level (i.e., there was a single growth factor
for each State that was applied to all units in that State). Since publication of the SNPR, EPA
has revised its estimates of State-specific growth rates from 1996 to 2007. The estimates were
interpolated from the average annual growth of each State as forecasted by EPA using the IPM
and EPA's baseline electric generation forecast. In developing the average annual growth, EPA
relied on unit-specific summer energy use from 2000 to 2010 as forecasted by the IPM. The
final growth factors are shown in Table II-1.
The growth factors were applied to the 1995/1996 heat input to get 2007 projected heat
input. Emissions were then estimated by multiplying the 2007 projected heat input by the 2007
budget-applicable NOx rate.
D. EGU Emission Summary
Table II-2 is a State-level summary of the EGU data. It contains both daily and seasonal heat
input and NOx emissions for the 1995/1996 base year, the 1996 base year, and the 2007 budget
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case.
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Table II-l
IPM Growth Factors
1996-2007
State
Growth Factor
Alabama
1.10
Connecticut
0.60
District of
1.36
Columbia
Delaware
1.27
Georgia
1.13
Illinois
1.08
Indiana
1.17
Kentucky
1.16
Massachusetts
1.59
Maryland
1.35
Michigan
1.13
Missouri
1.09
North Carolina
1.21
New Jersey
1.29
New York
1.05
Ohio
1.07
Pennsylvania
1.15
Rhode Island
0.47
South Carolina
1.43
Tennessee
1.21
Virginia
1.32
Wisconsin
1.12
West Virginia
1.03
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Table II-2
Base and Budget Daily and Seasonal Heat Input and NOx Emissions of EGU Data
1995/1996
1996
2007
Heat Input
Emissions
Heat Input
Emissions
Heat Input
Budget
ST
Daily Seasonal
(MMBtu/day) (MMBtu/season)
Daily
(tons/day)
Seasonal
(tons/season)
Daily Seasonal
(MMBtu/day) (MMBtu/season)
Daily
(tons/day)
Seasonal
(tons/season)
Daily Seasonal
(MMBtu/day) (MMBtu/season)
Daily
(tons/day)
Seasonal
(tons/season)
AL
2,503,648
352,462,502
699
26,387
2,503,648
352,425,386
699
99,156
2,754,013
387,708,752
206
29,051
CT
500,695
57,963,067
53
4,304
500,695
57,963,067
53
6,045
300,417
34,777,840
22
2,583
DE
291,168
36,929,685
57
2,774
291,168
36,929,685
57
7,341
369,784
46,900,700
28
3,523
DC
31,698
2,026,082
0
152
2,006
128,205
0
23
43,110
2,755,472
3
207
GA
2,623,259
356,189,138
585
26,774
2,447,655
336,016,010
585
80,736
2,964,282
402,493,727
223
30,255
IL
2,629,757
380,831,882
942
29,672
2,629,757
380,831,882
900
113,741
2,840,138
411,298,433
21
32,045
IN
3,663,468
536,397,099
1,173
41,897
3,663,468
536,397,099
1,173
156,317
4,286,258
627,584,606
335
49,020
KY
2,817,630
418,293,392
1,066
30,106
2,817,630
418,293,392
1,066
150,225
3,268,450
485,220,335
248
36,753
MD
1,088,379
146,326,807
333
10,948
991,312
140,309,532
333
44,779
1,469,311
197,541,191
110
14,807
MA
849,027
124,714,270
108
9,455
849,027
113,610,193
108
14,755
1,349,953
198,295,689
103
15,033
MI
2,125,769
317,207,481
538
24,925
2,125,769
316,869,141
538
79,692
2,402,119
358,444,454
189
28,165
MO
2,000,402
286,136,866
561
21,948
2,000,402
278,158,320
561
79,565
2,180,437
311,889,185
168
23,923
NJ
816,787
102,386,614
135
8,421
793,851
88,723,256
122
14,445
1,053,655
132,078,731
78
10,863
NY
2,704,128
380,092,043
294
28,832
2,370,956
294,737,106
294
37,377
2,839,335
399,096,648
215
30,273
NC
2,575,405
343,950,596
941
25,946
2,575,405
343,950,596
941
125,237
3,116,241
416,180,221
235
31,394
OH
4,157,537
578,736,962
1,644
45,297
4,157,537
578,736,962
1,644
229,886
4,448,564
619,248,549
348
48,468
PA
3,937,388
563,665,148
853
45,218
3,937,388
563,665,148
853
116,304
4,527,996
648,214,923
364
52,000
RI
217,610
31,701,944
17
2,378
217,610
31,701,944
17
2,145
102,277
14,899,914
8
1,118
SC
1,128,591
151,900,826
385
11,391
1,128,591
151,900,826
385
51,822
1,613,885
217,218,182
121
16,290
TN
1,976,188
279,738,759
801
20,980
1,899,491
268,877,789
801
113,329
2,391,187
338,483,899
179
25,386
VA
1,480,154
183,906,327
348
13,832
1,266,114
155,553,455
348
44,508
1,953,803
242,756,353
147
18,258
WV
2,216,129
342,257,483
847
25,669
2,216,129
342,755,795
843
116,758
2,282,613
352,525,208
171
26,439
WI
1,395,215
210,372,259
314
16,046
1,342,849
201,659,868
294
42,407
1,562,641
235,616,930
121
17,972
Total
43,730,032
6,184,187,232
12,692
473,351
42,728,458
5,990,194,657
12,613
1,726,590
50,120,470
7,081,229,940
3,839
543,825
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Chapter III
Non-EGU Point Source Data
A. Development of Base Year Data
The non-EGU point source inventory was based on data sets originating with the OTAG
1990 base year inventory. The OTAG prepared these base year inventories with 1990 State
ozone SIP emission inventories, and EPA supplemented them with either State inventory data, if
available, or EPA's National Emission Trends (NET) data if State data were not available.
For the SNPR, non-EGU point source inventory data for 1990 were then grown to 1995
using Bureau of Economic Analysis (BEA) historical growth estimates of industrial earnings at
the State 2-digit Standard Industrial Classification (SIC) level. These emissions were grown to
1995 for the purposes of modeling and to maintain a consistent base year inventory with the
EGU data.
NOx RACT controls were applied to major sources in ozone nonattainment areas (NAA)
and the Ozone Transport Region (OTR) unless the area received a NOx waiver. The data to
model NOx RACT came from the OTAG data base which was developed by surveying
applicable States on their implementation of NOx RACT (Pechan, 1997b). These data include
unit specific NOx RACT control efficiencies for many units. For units without specific control
information either ozone nonattainment area/SCC NOx RACT efficiencies collected from the
States or national/SCC NOx RACT default efficiencies were applied. Table III-l presents the
national/SCC NOx RACT default efficiencies used in the base calculation.
Based on comments submitted during the NPR and SNPR public comment periods, EPA
revised the 1995 non-EGU point source inventory with approved data addressing issues such as
emission estimate revisions, missing sources, retired sources, incorrect source sizes, base year
control levels, and facility name changes. Where 1990 base year data were submitted and
accepted, the methods described earlier in this section were utilized to account for growth to
1995 levels. Details of these comments and their affect on the base inventory can be found in the
response to significant comments document for the NFR (EPA, 1998a).
B. 2007 Base Case
The inventory data for 1995 was projected to 2007 using BEA projections of Gross State
Product (GSP) at the 2-digit SIC level and the Emissions Modeling System-95 (EMS) to
generate typical ozone season weekday, Saturday, and Sunday allocations for episodic modeling.
Consistent with the SNPR 2007 projection methodology, the growth factors developed were
based on the change in projected GSP between 1990 and 2007. The amount of growth estimated
to have occurred between 1990 and 1995 was factored out of the 1990 to 2007 growth factors
using the following formula:
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_ 1990 to 2007
1995 to 2007 rT7
1990 to 1995
where:
GF1995to2oo7 = the 1995 to 2007 growth factor used to project from 1995 to 2007
GF1990to2oo7 = the 1990 to 2007 growth factor used in OTAG to project from 1990 to 2007
GF1990tol995 = the 1990 to 1995 growth factor used to project the 1990 OTAG emissions to
1995 for the SIP Call base year data.
The resulting 1995 to 2007 growth factors were applied to the 1995 base year emissions to
project 2007 emissions.
In addition to NOx RACT, MACT control assumptions were applied to large municipal
waste combustors (MWC) in the base case. As demonstrated in the supporting TSD, a 30
percent NOx reduction is attainable and assumed for sources identified by this rule (EPA,
1998b). Appendix A presents the non-EGU point source controls included in the 2007 base
case.
Seasonal emissions were calculated by multiplying the weekday emissions by 109 days,
and each of the weekend allocations by 22 days to estimate a 153-day ozone season. This
seasonal value was then divided by 153 days to estimate the typical ozone day for summary
purposes.
C. 2007 Budget Case
To determine assumed control strategy reduction for non-EGU point sources for purposes
of calculating the budget, emissions were initially totaled at each source to a primary fuel (SCC)
based on decreasing daily NOx emissions from the base year inventory. This was done to
prevent the application of multiple control strategies, and the costs associated with those
controls, to units firing multiple fuels. A source category was then assigned to this primary fuel
from which NOx reduction strategies were associated and where deemed applicable. Appendix B
presents a list of these categories which are identified in the emissions files by the field name
[POD],
For the 2007 budget case calculation, an additional distinction was needed between large
(>250 MMBtu/hr or greater than 1 ton NOx/day) and small (<=250 MMBtu/hr and emitting less
than or equal to 1 ton NOx/day) points for non-EGU sources. Where heat input capacity data
were available for a unit, these data were used in determining the source's size. However, a
majority of the non-EGU point source records in the inventory did not include boiler capacity
data. For these cases, data from EPA's NET Inventory were used to determine whether a non-
EGU source was assumed as a large or small source as was similarly done for NPR budget
calculation purposes.
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Using data from the NET data base, a default boiler capacity file that contained the mean
and median boiler capacities by the first 6-digits of SCCs was developed. For each 6-digit SCC,
the file also contained the average daily NOx emissions for records with boiler capacities closest
to 250 MMBtu/hr. These data are listed in Table III-2.
As an example, for the 6-digit SCC "202001", the boiler capacity closest to 250
MMBtu/hr is listed in Table III-2 as 276 MMBtu/hr. If there was only one record with a boiler
capacity of 276 MMBtu/hr, the daily NOx emissions from that unit were included from that
record. If more than one record had a boiler capacity of 276 MMBtu/hr, the mean daily
emissions of those records was used. Each non-EGU record in the inventory was matched to the
file described above based on the first 6-digits of its SCC.
The following rules were then used to determine if a unit's boiler capacity was considered
greater than, equal to, or less than 250 MMBtu/hr.
1. If boiler capacity data were provided for the unit, size determination was made
based on those data.
2. If boiler capacity data were not provided for the unit and a match could be made
to the SNPR non-EGU inventory, the default identification of large sources
developed for the SNPR budget calculation was used.
3. If both the mean and median boiler capacity in the file were greater than
300 MMBtu/hr, it was assumed that the record's boiler capacity was greater than
250 MMBtu/hr.
4. If either the mean or median boiler capacity was in between 200 and 300 MMBtu/
hr, then the daily NOx emissions were used to determine the boiler size. If the
record's daily NOx emissions were greater than the average daily NOx emissions
in the default boiler capacity file, it was assumed that the record's boiler capacity
was greater than 250 MMBtu/hr. If the record's daily NOx emissions were less
than the average daily NOx emissions in the default boiler capacity file, it was
assumed that the record's boiler capacity was less than 250 MMBtu/hr.
5. If both the mean and median boiler capacity in the file were less than 200
MMBtu/hr, it was assumed that the record's boiler capacity was less than 250
MMBtu/hr.
6. If the record could not be matched to the default boiler capacity file, it was
assumed that the record's boiler capacity was less than 250 MMBtu/hr.
Records for which the boiler capacity was estimated to be greater than 250 MMBtu/hr
were categorized as large sources. Additionally, 1995 point-level emissions were checked for
each record where the boiler capacity was estimated to be less than 250 MMBtu/hr. If the 1995
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point-level emissions were more than 1 ton/day, the record was categorized as a large source.
Otherwise the record was categorized as a small source.
In contrast to the NPR and SNPR methods of applying a 70 percent control to all large
sources and RACT to all medium sources within the affected SIP Call domain, assumed budget
reductions were assigned only to large sources in the specific source categories listed in Table
III-3. RACT requirements are not assumed for medium or small-sized sources in the budget
calculation of the NFR. Emission decreases from sources smaller than the heat input capacity
cutoff level, and that emit less than 1 ton of NOx per ozone season day, are not assumed as part
of the budget calculation; these sources are included in the budget at baseline levels.
Additionally, those sources without adequate information to determine potentially applicable
control techniques are included in the budget at baseline levels.
Budget reductions were estimated from 2007 uncontrolled emission levels first calculated
by removing base case control efficiency and rule effectiveness values. The budget reduction
percentage was then applied with the same rule effectiveness to estimate budget level emissions.
No emission reduction in addition to base case controls are assumed for small sources. No
additional VOC or CO controls were applied in the 2007 budget case.
It should be noted that the budget reductions were applied to all sources even if they were
less stringent than the existing 2007 base case controls. This resulted in an increase in emissions
from the 2007 base case to the 2007 budget case for some sources, but is consistent with the
EGU budget calculation. A detailed file of non-EGU sources including emissions, growth, and
control information is provided in Appendix D of this document.
D. Non-EGU Emission Summary
Table III-4 is a State-level summary of the seasonal non-EGU data. It contains five
month ozone season NOx emissions for the 2007 base case and the 2007 budget case.
14
-------
Table III-l
Default NOx RACT Control Assumptions
Default NOx
RACT
Control Efficiency
see
NOy RACT Control Group
(Percent)
10200101
Industrial Boiler - PC
50
10200104
Industrial Boiler - Stoker - Overfeed
55
10200201
Industrial Boiler - PC - Wet
50
10200202
Industrial Boiler - PC - Dry
50
10200203
Industrial Boiler - Cyclone
53
10200204
Industrial Boiler - Stoker - Spreader
55
10200205
Industrial Boiler - Stoker - Overfeed
55
10200206
Industrial Boiler - Stoker
55
10200210
Industrial Boiler - Stoker - Overfeed
55
10200212
Industrial Boiler - PC - Dry
50
10200213
Industrial Boiler - PC - Wet
50
10200217
Industrial Boiler - PC
50
10200219
Cogeneration - Coal
50
10200222
Industrial Boiler - PC - Dry
50
10200223
Industrial Boiler - Cyclone
53
10200224
Industrial Boiler - Stoker - Spreader
55
10200225
Industrial Boiler - Stoker - Overfeed
55
10200229
Cogeneration - Coal
50
10200301
Industrial Boiler - PC
50
10200306
Industrial Boiler - Stoker - Spreader
55
10200401
Industrial Boiler - Residual Oil
50
10200402
Industrial Boiler - Residual Oil
50
10200403
Industrial Boiler - Residual Oil
50
10200404
Industrial Boiler - Residual Oil
50
10200405
Cogeneration - Oil Turbines
68
10200501
Industrial Boiler - Distillate Oil
50
10200502
Industrial Boiler - Distillate Oil
50
10200503
Industrial Boiler - Distillate Oil
50
10200504
Industrial Boiler - Distillate Oil
50
10200505
Cogeneration - Oil Turbines
68
10200601
Industrial Boiler - Natural Gas
50
15
-------
Table III-l
Default NOx RACT Control Assumptions
Default NOx
RACT
Control Efficiency
see
NOy RACT Control Group
(Percent)
10200602
Industrial Boiler - Natural Gas
50
10200603
Industrial Boiler - Natural Gas
50
10200604
Cogeneration - Natural Gas Turbines
84
10200699
Industrial Boiler - Natural Gas
50
10200701
Industrial Boiler - Natural Gas
50
10200704
Industrial Boiler - Natural Gas
50
10200707
Industrial Boiler - Natural Gas
50
10200710
Cogeneration - Natural Gas Turbines
84
10200799
Industrial Boiler - Natural Gas
50
10200802
Industrial Boiler - PC
50
10200804
Cogeneration - Coal
50
10201001
Industrial Boiler - Natural Gas
50
10201002
Industrial Boiler - Natural Gas
50
10201402
Cogeneration - Coal
50
10300101
Industrial Boiler - PC
50
10300102
Industrial Boiler - Stoker - Overfeed
55
10300103
Industrial Boiler - PC
50
10300205
Industrial Boiler - PC - Wet
50
10300206
Industrial Boiler - PC - Dry
50
10300207
Industrial Boiler - Stoker - Overfeed
55
10300208
Industrial Boiler - Stoker
55
10300209
Industrial Boiler - Stoker - Spreader
55
10300211
Industrial Boiler - Stoker - Overfeed
55
10300217
Industrial Boiler - PC
50
10300221
Industrial Boiler - PC - Wet
50
10300222
Industrial Boiler - PC - Dry
50
10300224
Industrial Boiler - Stoker - Spreader
55
10300225
Industrial Boiler - Stoker - Overfeed
55
10300309
Industrial Boiler - Stoker - Spreader
55
10300401
Industrial Boiler - Residual Oil
50
10300402
Industrial Boiler - Residual Oil
50
16
-------
Table III-l
Default NOx RACT Control Assumptions
Default NOx
RACT
Control Efficiency
see
NOy RACT Control Group
(Percent)
10300404
Industrial Boiler - Residual Oil
50
10300501
Industrial Boiler - Distillate Oil
50
10300502
Industrial Boiler - Distillate Oil
50
10300503
Industrial Boiler - Distillate Oil
50
10300504
Industrial Boiler - Distillate Oil
50
10300601
Industrial Boiler - Natural Gas
50
10300602
Industrial Boiler - Natural Gas
50
10300603
Industrial Boiler - Natural Gas
50
10300701
Industrial Boiler - Natural Gas
50
10300799
Industrial Boiler - Natural Gas
50
10301001
Industrial Boiler - Natural Gas
50
10301002
Industrial Boiler - Natural Gas
50
10500205
Process Heaters - Distillate Oil
74
10500206
Process Heaters - Natural Gas
75
10500210
Process Heaters - Other
74
20100101
Gas Turbines - Oil
68
20100102
IC Engines - Oil - Reciprocating
25
20100201
Gas Turbines - Natural Gas
84
20100202
IC Engines - Natural Gas - Reciprocating
30
20100702
Industrial Boiler - Other
50
20100801
Industrial Boiler - Other
50
20100802
Industrial Boiler - Other
50
20100901
Industrial Boiler - Other
50
20200101
Gas Turbines - Oil
68
20200102
IC Engines - Oil - Reciprocating
25
20200103
Cogeneration - Oil Turbines
68
20200104
Cogeneration - Oil Turbines
68
20200201
Gas Turbines - Natural Gas
84
20200202
IC Engines - Natural Gas - Reciprocating
30
20200203
Cogeneration - Natural Gas Turbines
84
20200204
Industrial Cogeneration - Nat. Gas
50
17
-------
Table III-l
Default NOx RACT Control Assumptions
Default NOx
RACT
Control Efficiency
see
NOy RACT Control Group
(Percent)
20200301
Industrial Boiler - Other
50
20200401
Industrial Boiler - Other
50
20200402
Industrial Boiler - Other
50
20200403
Cogeneration - Oil Turbines
68
20200501
IC Engines - Oil - Reciprocating
25
20200901
Industrial Boiler - Other
50
20200902
Industrial Boiler - Other
50
20201001
IC Engines - Natural Gas - Reciprocating
30
20201002
IC Engines - Natural Gas - Reciprocating
30
20300101
IC Engines - Oil - Reciprocating
25
20300102
Gas Turbines - Oil
68
20300201
IC Engines - Natural Gas - Reciprocating
30
20300202
Gas Turbines - Natural Gas
84
20300203
Cogeneration - Natural Gas Turbines
84
20300204
Cogeneration - Natural Gas Turbines
84
20300301
Industrial Boiler - Other
50
20301001
IC Engines - Natural Gas - Reciprocating
30
20400301
Gas Turbines - Natural Gas
84
20400302
Gas Turbines - Oil
68
20400401
IC Engines - Oil - Reciprocating
25
20400402
IC Engines - Oil - Reciprocating
25
30100101
Adipic Acid Manufacturing Plant
81
30101301
Nitric Acid Manufacturing Plant
95
30101302
Nitric Acid Manufacturing Plant
95
30190003
Process Heaters - Natural Gas
75
30190004
Process Heaters - Natural Gas
75
30390001
Process Heaters - Distillate Oil
74
30390003
Process Heaters - Natural Gas
75
30390004
Process Heaters - Other
74
30490001
Process Heaters - Distillate Oil
74
30490003
Process Heaters - Natural Gas
75
18
-------
Table III-l
Default NOx RACT Control Assumptions
Default NOx
RACT
Control Efficiency
see
NOy RACT Control Group
(Percent)
30490004
Process Heaters - Other
74
30590001
Process Heaters - Distillate Oil
74
30590002
Process Heaters - Residual Oil
73
30590003
Process Heaters - Natural Gas
75
30600101
Process Heaters - Distillate Oil
74
30600102
Process Heaters - Natural Gas
75
30600103
Process Heaters - Distillate Oil
74
30600104
Process Heaters - Natural Gas
75
30600105
Process Heaters - Natural Gas
75
30600106
Process Heaters - Natural Gas
75
30600107
Process Heaters - Natural Gas
75
30600111
Process Heaters - Residual Oil
73
30600199
Process Heaters - Other
74
30790001
Process Heaters - Distillate Oil
74
30790002
Process Heaters - Residual Oil
73
30790003
Process Heaters - Natural Gas
75
30890003
Process Heaters - Natural Gas
75
30990001
Process Heaters - Distillate Oil
74
30990002
Process Heaters - Residual Oil
73
30990003
Process Heaters - Natural Gas
75
31000401
Process Heaters - Distillate Oil
74
31000403
Process Heaters - Residual Oil
73
31000404
Process Heaters - Natural Gas
75
31000405
Process Heaters - Natural Gas
75
31390003
Process Heaters - Natural Gas
75
39990001
Process Heaters - Distillate Oil
74
39990002
Process Heaters - Residual Oil
73
39990003
Process Heaters - Natural Gas
75
39990004
Process Heaters - Natural Gas
75
40201001
Process Heaters - Natural Gas
75
40201002
Process Heaters - Distillate Oil
74
19
-------
Table III-l
Default NOx RACT Control Assumptions
Default NOx
RACT
see
NOy RACT Control Group
Control Efficiency
(Percent)
40201003
Process Heaters - Residual Oil
73
40201004
Process Heaters - Natural Gas
75
20
-------
Table III-2
Default Boiler Capacity Data From the NET
Boiler
Daily NOx (tpd)
Mean
Median
Capacity
of Boiler with
Boiler
Boiler
Closest to
Capacity
6-Digit
Capacity
Capacity
250
Closest to 250
see
(MMBtu/hr) (MMBtu/hr)
MMBtu/hr
MMBtu/hr
102001
75.97
55
264
2.6597
102002
236.65
150
250
0.7282
102003
150.44
58
87
0.4796
102004
393.35
73
250
0.3292
102005
299.63
80
250
0.1365
102006
251.96
86
250
0.2127
102007
268.49
198
250
0.1313
102008
515.30
420
241
1.0534
102009
348.64
132
250
0.2103
102010
123.57
45
224
0.0848
102011
193.00
193
193
0.1606
102012
252.00
180
246
0.4668
102013
194.81
172
250
0.0351
102014
287.62
297
267
0.1636
103001
49.45
43
137
0.2052
103002
90.28
74
248
1.1403
103003
85.00
93
101
0.1194
103004
113.01
59
245
0.0417
103005
89.05
71
249
0.0468
103006
152.38
97
249
0.0468
103007
211.00
197
197
0.7150
103009
65.18
66
166
0.0132
103010
138.00
138
138
0.0179
103012
240.33
75
200
0.5335
103013
93.45
59
250
0.5194
105001
68.22
58
200
0.0035
105002
106.77
108
115
0.0108
202001
228.87
62
276
1.2046
202002
294.62
9
271
0.5596
202005
62.00
62
62
0.1882
202009
70.00
70
70
0.3557
203001
75.00
35
256
8.0303
203002
29.47
8
197
0.7150
204001
567.14
390
210
0.1043
204004
6.00
6
6
0.0223
21
-------
Table III-2
Default Boiler Capacity Data From the NET
Boiler
Daily NOx (tpd)
Mean
Median
Capacity
of Boiler with
Boiler
Boiler
Closest to
Capacity
6-Digit
Capacity
Capacity
250
Closest to 250
see
(MMBtu/hr) (MMBtu/hr)
MMBtu/hr
MMBtu/hr
301001
288.00
288
288
0.6520
301003
760.62
782
445
1.0585
301005
30.50
31
43
0.0143
301006
100.00
100
134
0.1488
301009
31.00
31
31
0.0335
301018
42.00
50
70
0.1422
301021
68.00
68
68
0.0902
301023
149.00
168
168
0.0031
301024
310.00
310
310
2.5889
301026
62.00
40
247
0.3385
301030
45.80
29
75
0.0668
301032
17.33
10
60
0.0005
301033
4.00
4
4
0.0030
301035
65.50
52
130
0.9466
301050
1.50
2
2
0.6707
301125
399.50
56
105
0.2021
301140
86.00
86
86
0.1106
301250
189.33
178
230
0.5717
301800
170.00
170
170
1.1550
301888
103.00
103
156
1.1209
301900
9.36
13
16
0.0166
301999
1027.50
40
74
0.5594
302002
5.00
5
5
0.1122
302004
36.00
36
36
0.0633
302007
17.75
17
35
0.1559
302009
95.20
66
260
0.0059
302010
123.00
123
123
0.6380
302999
17.50
18
30
0.0030
303000
4.50
5
6
0.0019
303003
338.27
160
260
0.6746
303008
355.60
227
227
0.6253
303009
244.23
105
263
0.5550
303014
37.74
21
310
0.1934
303999
10.00
10
10
0.0195
304001
11.00
11
11
0.0092
22
-------
Table III-2
Default Boiler Capacity Data From the NET
Boiler
Daily NOx (tpd)
Mean
Median
Capacity
of Boiler with
Boiler
Boiler
Closest to
Capacity
6-Digit
Capacity
Capacity
250
Closest to 250
see
(MMBtu/hr) (MMBtu/hr)
MMBtu/hr
MMBtu/hr
304003
51.33
33
89
0.0127
304004
20.50
21
24
0.0023
304007
24.25
25
36
0.0013
304008
41.00
41
41
0.0624
304020
82.25
93
93
0.1393
304999
28.00
28
52
0.0110
305001
9.20
6
26
0.1109
305002
37.87
21
190
0.0488
305003
17.13
15
29
0.0204
305005
7.00
7
7
0.0033
305006
196.75
230
250
0.4356
305007
724.00
724
248
4.2005
305008
42.00
42
42
0.3154
305009
30.00
30
30
0.0129
305010
106.30
100
221
0.1372
305014
55.53
49
150
3.0135
305015
18.11
10
58
0.0506
305016
100.13
103
172
0.4122
305019
76.33
70
89
1.3739
305020
4.00
4
4
0.0283
305021
19.00
19
19
0.0124
305040
110.00
110
110
0.1642
305999
43.00
43
43
0.1661
306001
127.20
63
250
0.2181
306002
243.83
235
238
0.2882
306003
172.00
232
249
0.3476
306011
5.00
5
5
0.0231
306012
126.00
126
126
0.0888
306099
12.50
13
15
0.0303
306888
41.00
41
41
0.4362
306999
21.17
21
31
0.0814
307001
403.92
338
248
0.1822
307002
340.00
340
52
0.0193
307007
44.67
32
160
0.1408
307008
40.00
40
40
0.4065
23
-------
Table III-2
Default Boiler Capacity Data From the NET
Boiler
Daily NOx (tpd)
Mean
Median
Capacity
of Boiler with
Boiler
Boiler
Closest to
Capacity
6-Digit
Capacity
Capacity
250
Closest to 250
see
(MMBtu/hr) (MMBtu/hr)
MMBtu/hr
MMBtu/hr
307013
58.50
59
112
0.0478
307020
24.00
24
37
0.0039
307900
77.33
61
110
0.1716
307999
30.00
25
40
0.1038
308999
46.00
46
46
0.0050
309999
143.17
178
269
0.0564
310002
16.99
6
289
0.1779
310004
39.56
29
118
0.0616
313999
26.00
36
36
0.0013
314999
26.00
36
36
0.0013
390001
5.00
5
5
0.0418
390002
121.50
101
248
4.2005
390004
174.36
71
250
0.3908
390005
32.16
28
141
0.0014
390006
152.17
36
250
0.3908
390007
310.48
80
231
0.1690
390008
4.00
4
4
0.0125
390009
88.60
28
357
0.3891
390010
9.57
11
15
0.0032
390013
14.25
8
39
0.0682
399999
30.00
30
30
0.0475
401002
56.00
56
56
0.0224
402001
30.60
5
133
0.0285
402006
2.00
2
2
0.0032
402008
7.13
8
12
0.0035
402009
69.50
70
133
0.0285
402010
6.67
5
12
0.0035
402013
56.00
56
56
0.1172
402017
3.17
5
5
0.0036
402025
46.00
46
46
0.0050
403001
10.00
10
10
0.0099
403011
1.00
1
1
0.0047
404001
20.00
20
20
0.0035
405001
3.33
4
5
0.0017
405005
3.00
3
3
0.0022
24
-------
Table III-2
Default Boiler Capacity Data From the NET
Boiler
Daily NOx (tpd)
Mean
Median
Capacity
of Boiler with
Boiler
Boiler
Closest to
Capacity
6-Digit
Capacity
Capacity
250
Closest to 250
see
(MMBtu/hr) (MMBtu/hr)
MMBtu/hr
MMBtu/hr
406001
56.50
57
70
0.3557
490999
21.00
21
21
0.0348
501001
3345.82
37
375
1.3650
502001
17943.33
245
245
0.0485
502005
1.00
1
1
0.0085
503001
1347.94
10
140
0.3322
503005
276.25
361
361
0.3686
25
-------
Table III-3
Budget Reduction Levels From Uncontrolled Emissions
Budget Reduction
Source Category Percentage
ICI Boilers - Coal/Wall 60
ICI Boilers - Coal/FBC 60
ICI Boilers - Coal/Stoker 60
ICI Boilers - Coal/Cyclone 60
ICI Boilers - Residual Oil 60
ICI Boilers - Distillate Oil 60
ICI Boilers - Natural Gas 60
ICI Boilers - Process Gas 60
ICI Boilers - LPG 60
ICI Boilers - Coke 60
Gas Turbines - Oil 60
Gas Turbines - Natural Gas 60
Gas Turbines - Jet Fuel 60
Internal Combustion Engines - Oil 90
Internal Combustion Engines - Gas 90
Internal Combustion Engines - Gas, Diesel, LPG 90
Cement Manufacturing - Dry 30
Cement Manufacturing - Wet 30
In-Process; Bituminous Coal; Cement Kiln 30
26
-------
Table III-4
Base and Budget Ozone Season NOx Emissions
Non-EGU Point Sources
State
1995 Base*
2007 Base
2007 Budget
Reduction
Alabama
42,190
49,781
37,696
24%
Connecticut
5,674
5,273
5,056
4%
Delaware
1,443
1,781
1,645
8%
District of Columbia
395
310
292
6%
Georgia
28,370
33,939
27,026
20%
Illinois
67,391
55,721
42,011
25%
Indiana
60,348
71,270
44,881
37%
Kentucky
15,736
18,956
14,705
22%
Maryland
14,228
10,982
7,593
31%
Massachusetts
11,611
9,943
9,763
2%
Michigan
65,758
79,034
48,627
38%
Missouri
12,892
13,433
11,054
18%
New Jersey
21,930
22,228
19,804
11%
New York
24,240
25,791
24,128
6%
North Carolina
28,150
34,027
25,984
24%
Ohio
47,014
53,241
35,145
34%
Pennsylvania
78,588
73,748
65,510
11%
Rhode Island
338
327
327
0%
South Carolina
25,675
34,740
25,469
27%
Tennessee
49,794
60,004
35,568
41%
Virginia
36,000
39,765
27,076
32%
West Virginia
41,102
40,192
31,286
22%
Wisconsin
17,852
22,796
17,973
21%
Total
696,718
757,281
558,618
26%
* 1995 Base emissions estimated by multiplying typical ozone season daily emissions by 153 days.
27
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28
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Chapter IV
Stationary Area and Nonroad Source Data
A. Development of Base Year Data
The stationary area and nonroad mobile source inventory was based on data sets
originating with the OTAG 1990 base year inventory. These base year inventories were
prepared with 1990 State ozone SIP emission inventories supplemented with either State
inventory data, if available, or EPA's National Emission Trends (NET) data if State data were
not available. The OTAG 1990 nonroad emission inventories were based primarily on estimates
of actual 1990 nonroad activity levels found in the October 1995 edition of EPA's annual report,
"National Air Pollutant Emission Trends." These area and nonroad mobile source inventory data
for 1990 were then grown to 1995 using BEA historical growth estimates of industrial earnings
at the State 2-digit SIC level.
Based on comments submitted during the NPR and SNPR public comment periods, the
1995 stationary area and nonroad mobile source inventories were revised with data addressing
issues such as emission estimate revisions, spacial allocation revisions, and base year control
levels. Where 1990 base year data were used, the method described above was utilized to
account for growth to 1995 levels. Details of these comments and their affect on the base
inventory can be found in the response to significant comments document for the NFR (EPA,
1998a).
B. 2007 Base Case
The inventory data for 1995 was projected to 2007 using BEA projections of Gross State
Product (GSP) at the 2-digit SIC level and the Emissions Modeling System-95 (EMS) to
generate typical ozone season weekday, Saturday, and Sunday allocations for episodic modeling.
Consistent with the SNPR 2007 projection methodology, the growth factors developed were
based on the change in projected GSP between 1990 and 2007. The amount of growth estimated
to have occurred between 1990 and 1995 was factored out of the 1990 to 2007 growth factors
using the following formula:
/-yjp _ ^1990 to 2007
1995 to 2007 rj7
1990 to 1995
where:
GF1995to2oo7 = the 1995 to 2007 growth factor used to project from 1995 to 2007
GF199„to2oo7 = the 1990 to 2007 growth factor used in OTAG to project from 1990 to 2007
GF1990tol995 = the 1990 to 1995 growth factor used to project the 1990 OTAG emissions to
1995 for the SIP Call base year data.
The resulting 1995 to 2007 growth factors were applied to the 1995 base year emissions to
29
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project 2007 emissions.
In contrast to the SNPR, reductions from certain nonroad mobile controls were assumed
to occur in the base case as a result of measures implemented between promulgation of the final
rule and base year 2007. These measures include the Federal Small Engine Standards, Phase II;
Federal Marine Engine Standards (for diesel engines of greater than 50 horsepower); Federal
Locomotive Standards; and the Nonroad Diesel Engine Standards. Controls previously reflected
in the budget were not included in the base case in the original SNPR calculations. These
measures were included in the base case, rather than the budgets, because the measures would be
implemented even in the absence of the final rulemaking. Appendix A presents the stationary
area and nonroad mobile control measures included in the 2007 base case.
Resulting seasonal emissions were calculated by multiplying the weekday emissions by
109 days, and each of the weekend allocations by 22 days to estimate a 153-day ozone season.
This seasonal value was then divided by 153 days to estimate the typical ozone day for summary
purposes.
C. 2007 Budget Case
For stationary area and nonroad mobile sources, no additional reduction was incurred
between the base and budget cases. A detailed file of county-level stationary area and nonroad
mobile source emissions and growth is provided in Appendices E and F of this document.
D. Stationary Area and Nonroad Emission Summary
Table IV-1 is a State-level summary of the seasonal stationary area and nonroad mobile
data. It contains five month ozone season NOx emissions for the 2007 base and budget cases.
30
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Table IV-1
Base and Budget Ozone Season NOx Emissions
Stationary Area and Nonroad Mobile
1995
1995
2007
2007
Stationary
Nonroad
Stationary
Nonroad
State
Area*
Mobile*
Area
Mobile
Alabama
24,247
29,497
25,225
16,594
Connecticut
4,258
13,101
4,588
9,584
Delaware
1,728
4,355
963
4,261
District of Columbia
838
1,924
741
3,470
Georgia
10,694
37,007
11,902
21,588
Illinois
8,824
76,957
7,822
47,035
Indiana
18,009
44,942
25,544
22,445
Kentucky
35,584
30,979
38,773
19,627
Maryland
4,055
20,463
4,105
17,249
Massachusetts
9,984
25,662
10,090
18,911
Michigan
22,289
35,899
28,128
23,495
Missouri
6,540
36,256
6,603
17,723
New Jersey
10,602
30,629
11,098
21,163
New York
17,294
43,706
15,587
29,260
North Carolina
9,330
30,744
10,651
17,799
Ohio
16,899
62,715
19,425
37,781
Pennsylvania
15,002
50,303
17,103
25,554
Rhode Island
373
3,076
420
2,073
South Carolina
6,748
18,829
8,359
11,903
Tennessee
9,881
66,783
11,990
44,567
Virginia
21,301
35,786
18,622
21,551
West Virginia
5,358
15,471
4,790
10,220
Wisconsin
9,111
25,772
8,160
12,965
Total
268,949
740,856
290,689
456,818
* 1995 Base emissions estimated by multiplying typical ozone season daily emissions by 153 days.
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32
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Chapter V
Highway Vehicle Source Data
A. Development of Base Year Data
The highway vehicle source inventory was based on data sets originating with historical
1995 VMT levels from the Highway Performance Monitoring System (HPMS). The HPMS data
were used to estimate States' 1995 VMT by vehicle category, except in those cases where EPA
accepted revisions per the NPR and SNPR comment periods. These VMT estimates reflect the
growth in overall VMT from 1990 to 1995, as well as the increase in light truck and sport-utility
vehicle use relative to light-duty vehicle use. The 1995 NOx emissions inventories also reflect
the type and extent of inspection and maintenance programs in effect as of that year and the
extent of the Federal reformulated gasoline program. The 1995 highway vehicle budget
components are based on EPA's MOBILE5a emission inventory model with corrected default
inputs.
B. 2007 Base Case
The EPA is continuing to use the growth methods developed by OTAG for the purpose of
projecting VMT growth between 1995 and 2007. Growth in highway mobile sources was
modeled by growing the 1995 vehicle miles traveled (VMT). VMT growth factors were
developed using data from the MOBILE4.1 Fuel Consumption Model. This model estimates
national VMT by vehicle type through the year 2020. To calculate the VMT growth factors, the
1995 and 2007 MOBILE4.1 Fuel Consumption Model VMT was first allocated to MSAs and
rest-of-state areas using 1995 population and projected 2007 population estimates. The actual
growth factors were calculated as the ratio of the allocated 2007 VMT to the allocated 1995
VMT by MSA or rest-of-state area and road type. Based on comments submitted during the
NPR and SNPR public comment periods, EPA revised the base VMT and VMT growth factors
were revised with appropriately explained and documented growth estimates. Details of these
comments are their affect on the base inventories can be found in the response to significant
comments document for the NFR (EPA, 1998a).
Emissions were calculated using average minimum and maximum monthly historical
(1970 to 1997) State-level temperatures and NOx RFG correction in RFG areas. Table V-l
presents these monthly temperatures by State.
In contrast to the SNPR, reductions from certain highway mobile controls were assumed
to occur in the base case as a result of measures implemented between promulgation of the final
rule and base year 2007. These measures include National Low Emission Vehicle Standards and
the 2004 Heavy-Duty Engine Standards. Controls previously reflected in the budget were not
included in the base case in the original SNPR calculations. These measures were included in
the base case, rather than the budgets, because the measures would be implemented even in the
absence of the final rulemaking. Appendix A presents the highway mobile control measures
included in the 2007 base case.
33
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C. 2007 Budget Case
For highway mobile sources, no additional reduction was incurred between the base and
budget cases. A detailed file of county-level highway mobile source VMT, growth, and
emissions is provided in Appendix G of this document.
D. Highway Vehicle Emission Summary
Table V-2 is a State-level summary of the seasonal highway vehicle data. It contains five
month ozone season NOx emissions for the 2007 base and budget cases.
34
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Table V-l
Historical Statewide Average Monthly Minimum and Maximum Temperatures
(Degrees Fahrenheit)
May
May
June
June
July
July
August
August
September
September
State
Max
Min
Max
Min
Max
Min
Max
Min
Max
Min
Alabama
80.8
57.9
87.4
65.7
90.5
70.0
89.8
69.2
84.5
63.3
Connecticut
71.9
49.0
80.0
57.0
85.0
62.6
82.7
60.8
74.3
52.1
Delaware
74.9
53.3
83.0
61.9
87.5
67.5
85.9
66.1
79.7
59.2
DC
75.9
56.4
84.5
65.9
88.7
71.1
86.7
69.4
80.0
62.7
Georgia
79.9
59.3
86.4
66.9
89.3
70.6
87.7
69.9
82.4
64.5
Illinois
74.6
52.5
83.8
61.9
87.0
66.0
84.7
64.0
78.3
55.6
Indiana
73.4
51.9
82.2
61.4
85.6
65.5
83.8
63.6
77.3
55.6
Kentucky
76.0
55.3
84.1
64.3
87.8
68.6
86.4
67.2
79.8
60.0
Maryland
74.2
52.8
83.1
62.1
87.5
67.5
85.6
65.9
78.7
59.0
Massachusetts
66.8
50.2
76.7
59.4
82.3
65.5
80.3
64.6
72.5
56.8
Michigan
69.8
50.1
78.8
59.8
83.3
65.2
81.0
63.5
73.3
56.1
Missouri
75.3
53.5
84.3
62.3
89.4
66.9
88.7
65.7
80.0
57.9
New Jersey
72.6
54.1
81.4
63.6
86.3
69.4
84.6
68.0
76.9
60.1
New York
70.4
54.1
79.2
63.6
84.5
69.4
82.9
68.6
75.1
61.4
North Carolina
76.8
54.6
83.8
63.3
87.7
67.9
85.6
66.5
79.6
60.2
Ohio
72.4
50.5
80.8
59.5
84.5
64.0
83.0
62.5
76.1
55.3
Pennsylvania
72.4
51.6
80.9
60.9
85.7
66.2
83.8
64.7
75.9
56.9
Rhode Island
68.4
48.7
77.2
57.8
82.5
64.3
81.0
62.8
73.3
54.4
South Carolina
83.5
58.4
89.2
66.4
92.5
70.7
90.2
69.7
85.5
64.0
Tennessee
78.4
56.6
86.0
65.0
89.6
69.4
88.5
68.2
82.3
61.5
Virginia
77.7
54.6
85.4
63.2
89.2
68.4
87.2
66.8
81.3
60.0
West Virginia
75.0
51.8
81.8
60.0
85.9
65.5
84.3
63.6
77.9
56.8
Wisconsin
65.1
45.8
75.5
56.3
80.5
62.8
78.5
62.0
70.9
54.0
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Table V-2
VMT and 2007 Budget Ozone Season NOx Emissions
Highway Mobile
Daily
Daily
Seasonal
1995 VMT
2007 VMT
2007 VMT
Final Budget
State
(thousands)
(thousands)
(thousands)
(tons/season)
Alabama
134,341
165,931
23,642,476
50,111
Connecticut
85,823
105,884
14,960,237
18,762
Delaware
23,101
29,621
4,206,684
8,131
District of Columbia
10,473
13,742
1,946,068
2,082
Georgia
261,911
350,942
49,777,317
86,611
Illinois
258,319
329,567
46,967,435
81,297
Indiana
165,944
200,011
30,253,176
60,694
Kentucky
126,429
155,617
22,133,666
45,841
Maryland
137,769
175,807
24,837,510
27,634
Massachusetts
146,732
181,366
25,608,187
24,371
Michigan
262,502
311,904
44,258,682
83,784
Missouri
182,783
228,386
32,349,941
55,230
New Jersey
186,381
229,501
32,442,260
34,106
New York
351,902
412,077
58,360,433
80,521
North Carolina
190,514
267,983
38,191,543
66,019
Ohio
308,982
371,334
52,640,487
99,079
Pennsylvania
289,803
350,345
49,759,266
92,280
Rhode Island
21,158
25,694
3,611,724
4,375
South Carolina
119,181
154,748
22,025,312
47,404
Tennessee
172,476
222,304
31,546,130
64,965
Virginia
214,559
273,737
38,789,952
70,212
West Virginia
53,765
64,272
9,160,525
20,185
Wisconsin
157,966
196,343
27,941,500
49,470
Total
3,862,814
4,817,116
685,410,511
1,173,164
36
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Chapter VI
Statewide NOx Budgets
The Statewide base case and budget emissions were calculated by summing the
individual base case and budget emissions components. Table VI-1 shows the seasonal
Statewide base case and budget NOx emissions and the percent reduction between the base case
and the budget. Table VI-2 presents the base and budget cases by major source category
component.
37
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Table VI-1
Seasonal Statewide NOx Base and Budgets
(Tons/Season)
State
Final Base
Final Budget
Reduction
Alabama
218,637
158,677
27%
Connecticut
43,843
40,573
7%
Delaware
20,974
18,523
12%
District of Columbia
6,606
6,792
-3%
Georgia
240,495
177,382
26%
Illinois
311,186
210,210
32%
Indiana
316,726
202,584
36%
Kentucky
231,026
155,699
33%
Maryland
92,573
71,388
23%
Massachusetts
79,794
78,168
2%
Michigan
301,041
212,199
30%
Missouri
175,086
114,533
35%
New Jersey
106,947
97,034
9%
New York
190,358
179,769
6%
North Carolina
213,311
151,847
29%
Ohio
372,658
239,898
36%
Pennsylvania
331,787
252,447
24%
Rhode Island
8,277
8,313
0%
South Carolina
138,705
109,425
21%
Tennessee
252,434
182,476
28%
Virginia
191,034
155,719
18%
West Virginia
190,877
92,920
51%
Wisconsin
145,353
106,540
27%
Total
4,179,728
3,023,116
28%
38
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Table VI-1
Seasonal Statewide NOx Base and Budgets by Major Source Category
(Tons/Season)
State
EGU
Non-EGU
Area
2007 Base NOx Emissions (tons/season)
Nonroad Highway Total
EGU
Non-EGU
2007 Budget NOx Emissions (tons/season)
Area Nonroad Highway Total
Alabama
76,926
49,781
25,225
16,594
50,111
218,637
29,051
37,696
25,225
16,594
50,111
158,677
Connecticut
5,636
5,273
4,588
9,584
18,762
43,843
2,583
5,056
4,588
9,584
18,762
40,573
Delaware
5,838
1,781
963
4,261
8,131
20,974
3,523
1,645
963
4,261
8,131
18,523
District of Columbia
3
310
741
3,470
2,082
6,606
207
292
741
3,470
2,082
6,792
Georgia
86,455
33,939
11,902
21,588
86,611
240,495
30,255
27,026
11,902
21,588
86,611
177,382
Illinois
119,311
55,721
7,822
47,035
81,297
311,186
32,045
42,011
7,822
47,035
81,297
210,210
Indiana
136,773
71,270
25,544
22,445
60,694
316,726
49,020
44,881
25,544
22,445
60,694
202,584
Kentucky
107,829
18,956
38,773
19,627
45,841
231,026
36,753
14,705
38,773
19,627
45,841
155,699
Maryland
32,603
10,982
4,105
17,249
27,634
92,573
14,807
7,593
4,105
17,249
27,634
71,388
Massachusetts
16,479
9,943
10,090
18,911
24,371
79,794
15,033
9,763
10,090
18,911
24,371
78,168
Michigan
86,600
79,034
28,128
23,495
83,784
301,041
28,165
48,627
28,128
23,495
83,784
212,199
Missouri
82,097
13,433
6,603
17,723
55,230
175,086
23,923
11,054
6,603
17,723
55,230
114,533
New Jersey
18,352
22,228
11,098
21,163
34,106
106,947
10,863
19,804
11,098
21,163
34,106
97,034
New York
39,199
25,791
15,587
29,260
80,521
190,358
30,273
24,128
15,587
29,260
80,521
179,769
North Carolina
84,815
34,027
10,651
17,799
66,019
213,311
31,394
25,984
10,651
17,799
66,019
151,847
Ohio
163,132
53,241
19,425
37,781
99,079
372,658
48,468
35,145
19,425
37,781
99,079
239,898
Pennsylvania
123,102
73,748
17,103
25,554
92,280
331,787
52,000
65,510
17,103
25,554
92,280
252,447
Rhode Island
1,082
327
420
2,073
4,375
8,277
1,118
327
420
2,073
4,375
8,313
South Carolina
36,299
34,740
8,359
11,903
47,404
138,705
16,290
25,469
8,359
11,903
47,404
109,425
Tennessee
70,908
60,004
11,990
44,567
64,965
252,434
25,386
35,568
11,990
44,567
64,965
182,476
Virginia
40,884
39,765
18,622
21,551
70,212
191,034
18,258
27,076
18,622
21,551
70,212
155,719
West Virginia
115,490
40,192
4,790
10,220
20,185
190,877
26,439
31,286
4,790
10,220
20,185
92,920
Wisconsin
51,962
22,796
8,160
12,965
49,470
145,353
17,972
17,973
8,160
12,965
49,470
106,540
Total
1,501,775
757,282
290,689
456,818
1,173,164
4,179,728
543,826
558,619
290,689
456,818
1,173,164
3,023,116
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References
DOE, 1995a: U.S. Department of Energy, Energy Information Administration, "Steam-Electric
Plant Operation and Design Report," Form EIA-767, 1995.
DOE, 1995b: U.S. Department of Energy, Energy Information Administration, "Annual Electric
Generator Report, " Form EIA-860, 1995.
DOE, 1995c: U.S. Department of Energy, Energy Information Administration, "Annual
Nonutility Power Producers Report," Form EIA-867, 1995.
EPA, 1997b: U.S. Environmental Protection Agency, Data files receivedfrom EPA Acid Rain
Division, Washington DC, December 1997.
EPA, 1997c: U.S. Environmental Protection Agency, "National Air Pollutant Emission Trends,
1900-1996, " EPA-454/R-97-011, Research Triangle Park, NC, December, 1997.
EPA, 1998a: U.S. Environmental Protection Agency, "Responses to Significant Comments on
the Proposed Finding of Significant Contribution and Rulemaking for Certain States in
the Ozone Transport Assessment Group (OTAG) Region for Purposes of Reducing
Regional Transport of Ozone (62 FR 60318, November 7, 1997 and 63 FR 25902, May
11, 1998)," Docket A-96-56, VI-C-01, September, 1998.
EPA, 1998b: U.S. Environmental Protection Agency, "Technical Support Document for
Municipal Waste Combustors (MWCs), " Docket A-96-56, VI-B-12, September, 1998.
EPA, 1998c: U.S. Environmental Protection Agency, "Regulatory Impact Analysis for the
Regional NOx SIP Call," Docket A-96-56, VI-B-09, September, 1998.
Pechan, 1997a: E.H. Pechan & Associates, Inc., "Ozone Transport Assessment Group (OTAG)
Emissions Inventory Development Report - Volume I: 1990 Base Year Development, "
(revised draft) preparedfor U.S. Environmental Protection Agency, Office of Air Quality
Planning and Standards, Research Triangle Park, NC, February, 1997.
Pechan, 1997b: E.H. Pechan & Associates, Inc., "Ozone Transport Assessment Group (OTAG)
Emissions Inventory Development Report - Volume III: Projections and Controls, "
(draft) preparedfor U.S. Environmental Protection Agency, Office of Air Quality
Planning and Standards, Research Triangle Park, NC, June, 1997.
Pechan, 1997c: E.H. Pechan & Associates, Inc., "The Acid Rain Data Base for 1996
(ARDB96) Technical Support Document," (draft) preparedfor U.S. Environmental
Protection Agency, Office of Atmospheric Programs, September 1997.
-------
APPENDIX A
2007 BASE CASE CONTROLS
-------
Table A-l
2007 Base Case Controls
EGU
- Title IV Controls [ phase 1 & 2 ]
- 250 Ton PSD and NSPS
- RACT & NSR in non-waived NAAs
Non-EGU Point
Stationary Area
Nonroad Mobile
Highway Vehicles
- NOx RACT on major sources in non-waived NAAs
- 250 Ton PSD and NSPS
- NSR in non-waived NAAs
- CTG & Non-CTG VOC RACT at major sources in NAAs & OTR
- New Source LAER
- NOx MACT standards to municipal waste combustors (MWCs)
- Two Phases of VOC Consumer and Commercial Products & One Phase
of Architectural Coatings controls
- VOC Stage 1 & 2 Petroleum Distribution Controls in NAAs
- VOC Autobody, Degreasing & Dry Cleaning controls in NAAs
- Fed Phase II Small Eng. Stds
- Fed Marine Eng. Stds.
- Fed Nonroad Heavy-Duty (>=50 hp) Engine Stds - Phase 1
- Fed RFGII (statutory and opt-in areas)
- 9.0 RVP maximum elsewhere in OTAG domain
- Fed Locomotive Stds (not including rebuilds)
- Fed Nonroad Diesel Engine Stds - Phases 2 & 3
- On-board vapor recovery
- National LEV
- Fed RFG II (statutory and opt-in areas)
- Phase II RVP limits elsewhere in OTAG domain
- High Enhanced, Low Enhanced, or Basic I/M in areas specified by State
- Clean Fuel Fleets (mandated NAAs)
- HDV 2 gm std
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APPENDIX B
NON-EGU POINT SOURCE CATEGORY CODES
-------
Table B-l
Non-EGU Point Source Category Codes and Descriptions
POD Source Category
0 No Match
11 ICI Boilers - Coal/Wall
12 ICI Boilers - Coal/FBC
13 ICI Boilers - Coal/Stoker
14 ICI Boilers - Coal/Cyclone
15 ICI Boilers - Residual Oil
16 ICI Boilers - Distillate Oil
17 ICI Boilers - Natural Gas
18 ICI Boilers - Wood/Bark/Stoker
19 ICI Boilers - Wood/Bark/FBC
20 ICI Boilers - MSW/Stoker
21 Internal Combustion Engines - Oil
22 Internal Combustion Engines - Gas
23 Gas Turbines - Oil
24 Gas Turbines - Natural Gas
25 Process Heaters - Distillate Oil
26 Process Heaters - Residual Oil
27 Process Heaters - Natural Gas
28 Adipic Acid Manufacturing
29 Nitric Acid Manufacturing
30 Glass Manufacturing - Container
31 Glass Manufacturing - Flat
32 Glass Manufacturing - Pressed
33 Cement Manufacturing - Dry
34 Cement Manufacturing - Wet
35 Iron & Steel Mills - Reheating
36 Iron & Steel Mills - Annealing
37 Iron & Steel Mills - Galvanizing
38 Municipal Waste Combustors
39 Medical Waste Incinerators
40 Open Burning
41 ICI Boilers - Process Gas
42 ICI Boilers - Coke
43 ICI Boilers - LPG
44 ICI Boilers - Bagasse
45 ICI Boilers - Liquid Waste
46 IC Engines - Gas, Diesel, LPG
47 Process Heaters - Process Gas
48 Process Heaters - LPG
49 Process Heaters - Other Fuel
50 Gas Turbines - Jet Fuel
51 Engine Testing - Natural Gas
52 Engine Testing - Diesel GT
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Table B-l
Non-EGU Point Source Category Codes and Descriptions
POD
Source Category
53
Engine Testing - Oil IC
54
Space Heaters - Distillate Oil
55
Space Heaters - Natural Gas
56
Ammonia - NG-Fired Reformers
57
Ammonia - Oil-Fired Reformers
58
Lime Kilns
59
Comm./Inst. Incinerators
60
Indust. Incinerators
61
Sulfate Pulping - Recovery Furnaces
62
Ammonia Prod; FeedstockDesulfurization
63
Plastics Prod-Specific; (ABS) Resin
64
Starch Mfg; Combined Operations
65
By-Product Coke Mfg; Oven Underfiring
66
Pri Cop Smel; Reverb Smelt Furn
67
Iron Prod; Blast Furn; Blast Htg Stoves
68
Steel Prod; Soaking Pits
69
Fuel Fired Equip; Process Htrs; Pro Gas
70
Sec Alum Prod; Smelting Furn/Reverb
71
Steel Foundries; Heat Treating Furn
72
Fuel Fired Equip; Furnaces; Natural Gas
73
Asphaltic Cone; Rotary Dryer; Conv Plant
74
Ceramic Clay Mfg; Drying
75
Coal Cleaning-Thrml Dryer; Fluidized Bed
76
Fbrglass Mfg; Txtle-Type Fbr; Recup Furn
77
Sand/Gravel; Dryer
78
Fluid Cat Cracking Units; Cracking Unit
79
Conv Coating of Prod; Acid Cleaning Bath
80
Natural Gas Prod; Compressors
81
In-Process; Bituminous Coal; CementKiln
82
In-Process; Bituminous Coal; Lime Kiln
83
In-Process Fuel Use;Bituminous Coal; Gen
84
In-Process Fuel Use; Residual Oil; Gen
85
In-Process Fuel Use; Natural Gas; Gen
86
In-Proc;Process Gas;Coke Oven/Blast
Furn
87
In-Process; Process Gas; Coke Oven Gas
88
Surf Coat Oper;Coating Oven Htr;Nat Gas
89
Solid Waste Disp;Gov;Other Incin; Sludge
-------
APPENDIX C
SOURCE SPECIFIC EGU BASE AND BUDGET EMISSIONS FILE
-------
Table C-l
Regional NOx SIP Call EGU Point Source File
File Format
Filename:
Description:
Location:
NFREGU.TXT
Regional NOx SIP Call Base and Budget Determination EGU Point Source File
ftp.epa.gov/pub/scram001/modelingcenter/budget/
Variable Type Length Decimal Description
FIPSST
C
2
0
FIPS State Code
FIPSCNTY
C
3
0
FIPS County Code
ORISID
C
6
0
ORIS ID Code
PLANTID
C
15
0
Plant ID Code
PLANT
C
35
0
Plant Name
BLRID
C
15
0
Boiler ID Code
POINTID
C
15
0
Point ID Code
STACKID
C
15
0
Stack ID Code
SEGMENT
C
15
0
Segement ID
see
C
10
0
Source Classification Code
SIC
N
4
0
Standard Industrial Classification Code
HEAT RATE
N
10
2
Heat Rate
STKHGT
N
4
0
Stack Height (ft)
STKDIAM
N
6
2
Stack Diameter (ft)
STKTEMP
N
4
0
Stack Temperature (degrees F)
STKFLOW
N
10
2
Stack Flow (cu. ft./min)
STKVEL
N
9
2
Stack Velocity (ft/sec)
LAT
N
9
4
Latitude (degrees)
LON
N
9
4
Longitude (degrees)
BOILCAP
N
8
2
Boiler Capacity (MW)
YEAR9596
N
4
0
Indicates 1995 or 1996 data used for Base File
SHEAT95
N
15
1
1995 Ozone Season Heat Input (MMBtu)
SHEAT96
N
15
1
1996 Ozone Season Heat Input (MMBtu)
SHEAT9596
N
15
1
Base Ozone Season Heat Input (MMBtu) based on YEAR9596
DHEAT95
N
15
1
1995 Typical Ozone Season Daily Heat Input (MMBtu)
DHEAT96
N
15
1
1996 Typical Ozone Season Daily Heat Input (MMBtu)
DHEAT9596
N
15
1
Base Typical Ozone Season Daily Heat Input (MMBtu) based on YEAR9596
RATE95
N
15
5
1995 NOx Emission Rate (Ibs/MMBtu)
RATE96
N
15
5
1996 NOx Emission Rate (Ibs/MMBtu)
DN0X9596
N
11
5
Base Typical Ozone Season Daily NOx Emissions (tons)
SN0X9596
N
11
5
Base Ozone Season NOx Emissions (tons)
SNOX95
N
13
5
1995 Ozone Season NOx Emissions (tons)
SVOC95
N
13
5
1995 Ozone Season VOC Emissions (tons)
SC095
N
13
5
1995 Ozone Season CO Emissions (tons)
SNOX96
N
13
5
1996 Ozone Season NOx Emissions (tons)
SVOC96
N
13
5
1996 Ozone Season VOC Emissions (tons)
SC096
N
13
5
1996 Ozone Season CO Emissions (tons)
DNOX95
N
13
5
1995 Typical Ozone Season Daily NOx Emissions (tons)
DVOC95
N
13
5
1995 Typical Ozone Season Daily VOC Emissions (tons)
DC095
N
13
5
1995 Typical Ozone Season Daily CO Emissions (tons)
DNOX96
N
13
5
1996 Typical Ozone Season Daily NOx Emissions (tons)
DVOC96
N
13
5
1996 Typical Ozone Season Daily VOC Emissions (tons)
DC096
N
13
5
1996 Typical Ozone Season Daily CO Emissions (tons)
GRX07
N
5
3
IPM 2007 Projected Growth Rate
DHEAT07
N
15
1
2007 Typical Ozone Season Daily Projected Heat Input (MMBtu)
SHEAT07
N
15
1
2007 Ozone Season Projected Heat Input (MMBtu)
DVOC07
N
13
5
2007 Typical Ozone Season Daily VOC Emissions (tons)
DCO07
N
13
5
2007 Typical Ozone Season Daily CO Emissions (tons)
SVOC07
N
13
5
2007 Ozone Season VOC Emissions (tons)
SCO07
N
13
5
2007 Ozone Season CO Emissions (tons)
BRATE07
N
15
5
2007 Budget NOx Emission Rate (Ibs/MMBtu)
BDNOX07
N
13
5
2007 Typical Ozone Season Daily Budget NOx Emissions (tons)
BSNOX07
N
13
5
2007 Ozone Season Budqet NOx Emissions (tons)
-------
APPENDIX D
SOURCE SPECIFIC NON-EGU POINT SOURCE BASE AND BUDGET EMISSIONS
FILE
-------
Table D-l
Regional NOx SIP Call Non-EGU Point Source File
File Format
Filename: NFRPT.TXT
Description: Regional NOx SIP Call Non-EGU Point Source File
Location: ftp.epa.gov/pub/scram001/modelingcenter/budget/
Variable
Type
Length
Decimal
Description
FIPSST
C
2
0
FIPS State Code
FIPSCNTY
C
3
0
FIPS County Code
PLANTID
c
15
0
Plant ID Code
PLANT
c
40
0
Plant Name
POINTID
c
15
0
Point ID Code
STACKID
c
15
0
Stack ID Code
SEGMENT
c
15
0
Segment ID
see
c
10
0
Source Classification Code
POD
c
3
0
Source Category Association
NEWSIZE
c
1
0
Budget Size
BOILCAP
N
8
0
Boiler Design Capacity (MMBtu/hr)
STKHGT
N
4
0
Stack Height (ft)
STKDIAM
N
6
2
Stack Diameter (ft)
STKTEMP
N
4
0
Stack Temperature (degrees F)
STKFLOW
N
10
2
Stack Flow (cu. ft./min)
STKVEL
N
9
2
Stack Velocity (ft/sec)
WINTHRU
N
3
0
Winter Throughput Percentage
SPRTHRU
N
3
0
Spring Throughput Percentage
SUMTHRU
N
3
0
Summer Throughput Percentage
FALTHRU
N
3
0
Fall Throughput Percentage
HOURS
N
2
0
Operating Hours/Day
DAYS
N
1
0
Operating Days/Weeks
WEEKS
N
2
0
Operating Weeks/Year
SIC
N
4
0
Standard Industrial Classification Code
LATC
N
9
4
Latitude (degrees)
LONC
N
9
4
Longitiude (degrees)
NOXCE95
N
5
2
1995 NOx Control Efficiency
COCE95
N
5
2
1995 CO Control Efficiency
VOCCE95
N
5
2
1995 VOC Control Efficiency
NOXRE95
N
5
2
1995 NOx Rule Effectiveness
CORE95
N
5
2
1995 CO Rule Effectiveness
VOCRE95
N
5
2
1995 VOC Rule Effectiveness
DNOX95
N
16
4
1995 Typical Ozone Season Daily NOx Emissions (tons)
DC095
N
16
4
1995 Typical Ozone Season Daily CO Emissions (tons)
DVOC95
N
16
4
1995 Typical Ozone Season Daily VOC Emissions (tons)
GF9507
N
7
2
1995 - 2007 Growth Factor
THU NOX07
N
16
5
2007 Ozone Season Weekday NOx Emissions (tons)
THU_CO07
N
16
5
2007 Ozone Season Weekday CO Emissions (tons)
THU_VOC07
N
16
5
2007 Ozone Season Weekday VOC Emissions (tons)
SAT_NOX07
N
16
5
2007 Ozone Season Saturday NOx Emissions (tons)
SAT_CO07
N
16
5
2007 Ozone Season Saturday CO Emissions (tons)
SAT_VOC07
N
16
5
2007 Ozone Season Saturday VOC Emissions (tons)
SUN_NOX07
N
16
5
2007 Ozone Season Sunday NOx Emissions (tons)
SUN_CO07
N
16
5
2007 Ozone Season Sunday CO Emissions (tons)
SUN_VOC07
N
16
5
2007 Ozone Season Sunday VOC Emissions (tons)
NOXRE07
N
5
2
2007 NOx Rule Effectiveness
CORE07
N
5
2
2007 CO Rule Effectiveness
VOCRE07
N
5
2
2007 VOC Rule Effectiveness
NOXCE07
N
5
2
2007 Base NOx Control Efficiency
COCE07
N
5
2
2007 Base CO Control Efficiency
-------
Table D-l
Regional NOx SIP Call Non-EGU Point Source File
File Format
Variable
Type
Length
Decimal
Description
VOCCE07
N
5
2
2007 Base VOC Control Efficiency
SNOX07
N
16
4
2007 Ozone Season Base NOx Emissions (tons)
SCO07
N
16
4
2007 Ozone Season Base CO Emissions (tons)
SVOC07
N
16
4
2007 Ozone Season Base VOC Emissions (tons)
DNOX07
N
16
5
2007 Typical Ozone Season Daily NOx Emissions (tons)
DCO07
N
16
5
2007 Typical Ozone Season Daily CO Emissions (tons)
DVOC07
N
16
5
2007 Typical Ozone Season Daily VOC Emissions (tons)
NOXCE07B
N
5
2
2007 Budget NOx Control Efficiency
SBNOX
N
16
4
2007 Ozone Season Budget NOx Emissions (tons)
DBNOX
N
16
5
2007 Typical Ozone Season Daily Budget NOx Emissions
(tons!
-------
APPENDIX E
COUNTY LEVEL STATIONARY AREA BASE AND BUDGET EMISSIONS FILE
-------
Table E-l
Regional NOx SIP Call Stationary Area Source File
File Format
Filename: NFRAR.TXT
Description: Regional NOx SIP Call Stationary Area Source File
Location: ftp.epa.gov/pub/scram001/modelingcenter/budget/
Variable
Type
Length
Decimal
Description
FIPSST
C
2
0
FIPS State Code
FIPSCNTY
C
3
0
FIPS County Code
see
c
10
0
Source Classification Code
NOX95
N
10
4
1995 Typical Ozone Season Daily NOx Emissions (tons)
C095
N
10
4
1995 Typical Ozone Season Daily CO Emissions (tons)
VOC95
N
10
4
1995 Typical Ozone Season Daily VOC Emissions (tons)
GR9507
N
7
2
1995 - 2007 Growth Factor
THU_NOX07
N
10
4
2007 Ozone Season Weekday NOx Emissions (tons)
THU_CO07
N
10
4
2007 Ozone Season Weekday CO Emissions (tons)
THU_VOC07
N
10
4
2007 Ozone Season Weekday VOC Emissions (tons)
SAT_NOX07
N
10
4
2007 Ozone Season Saturday NOx Emissions (tons)
SAT_CO07
N
10
4
2007 Ozone Season Saturday CO Emissions (tons)
SAT_VOC07
N
10
4
2007 Ozone Season Saturday VOC Emissions (tons)
SUN_NOX07
N
10
4
2007 Ozone Season Sunday NOx Emissions (tons)
SUN_CO07
N
10
4
2007 Ozone Season Sunday CO Emissions (tons)
SUN_VOC07
N
10
4
2007 Ozone Season Sunday VOC Emissions (tons)
SNOX07
N
10
4
2007 Ozone Season NOx Emissions (tons)
SCO07
N
10
4
2007 Ozone Season CO Emissions (tons)
SVOC07
N
10
4
2007 Ozone Season VOC Emissions (tons)
DNOX07
N
10
4
2007 Typical Ozone Season Daily NOx Emissions (tons)
DCO07
N
10
4
2007 Typical Ozone Season Daily CO Emissions (tons)
DVOC07
N
10
4
2007 Typical Ozone Season Daily VOC Emissions (tons)
-------
APPENDIX F
COUNTY LEVEL NONROAD MOBILE BASE AND BUDGET EMISSIONS
-------
Table F-l
Regional NOx SIP Call Nonroad Mobile Source File
File Format
Filename: NFRNR.TXT
Description: Regional NOx SIP Call Nonroad Mobile Source File
Location: ftp.epa.gov/pub/scram001/modelingcenter/budget/
Variable
Type
Length
Decimal
Description
FIPSST
C
2
0
FIPS State Code
FIPSCNTY
C
3
0
FIPS County Code
see
c
10
0
Source Classification Code
NOX95
N
10
4
1995 Typical Ozone Season Daily NOx Emissions (tons)
C095
N
10
4
1995 Typical Ozone Season Daily CO Emissions (tons)
VOC95
N
10
4
1995 Typical Ozone Season Daily VOC Emissions (tons)
GR9507
N
7
2
1995 - 2007 Growth Factor
THU_NOX07
N
10
4
2007 Ozone Season Weekday NOx Emissions (tons)
THU_CO07
N
10
4
2007 Ozone Season Weekday CO Emissions (tons)
THU_VOC07
N
10
4
2007 Ozone Season Weekday VOC Emissions (tons)
SAT_NOX07
N
10
4
2007 Ozone Season Saturday NOx Emissions (tons)
SAT_CO07
N
10
4
2007 Ozone Season Saturday CO Emissions (tons)
SAT_VOC07
N
10
4
2007 Ozone Season Saturday VOC Emissions (tons)
SUN_NOX07
N
10
4
2007 Ozone Season Sunday NOx Emissions (tons)
SUN_CO07
N
10
4
2007 Ozone Season Sunday CO Emissions (tons)
SUN_VOC07
N
10
4
2007 Ozone Season Sunday VOC Emissions (tons)
SNOX07
N
10
4
2007 Ozone Season NOx Emissions (tons)
SCO07
N
10
4
2007 Ozone Season CO Emissions (tons)
SVOC07
N
10
4
2007 Ozone Season VOC Emissions (tons)
DNOX07
N
10
4
2007 Typical Ozone Season Daily NOx Emissions (tons)
DCO07
N
10
4
2007 Typical Ozone Season Daily CO Emissions (tons)
DVOC07
N
10
4
2007 Typical Ozone Season Daily VOC Emissions (tons)
-------
APPENDIX G
COUNTY LEVEL HIGHWAY MOBILE BASE AND BUDGET EMISSIONS FILE
-------
Table G-l
Regional NOx SIP Call Highway Mobile Source File
File Format
Filename: NFRMB.TXT
Description: Regional NOx SIP Call Highway Mobile Source File
Location: ftp.epa.gov/pub/scram001/modelingcenter/budget/
Variable
Tvoe
Lenath
Decimal
Description
FIPSST
C
2
0
FIPS State Code
FIPSCNTY
C
3
0
FIPS County Code
see
c
10
0
Source Classification Code
V TYPE
c
5
0
Vehicle Type
DVMT95
N
16
3
1995 Typical Ozone Season Daily Vehicle Miles Traveled (VMT)
GR9507
N
5
3
1995 to 2007 VMT Growth Factor
DVMT07
N
16
3
2007 Typical Ozone Season Daily VMT
SVMT07
N
16
3
2007 Ozone Season VMT
SNOX07
N
13
6
2007 Ozone Season NOx Emissions (tons)
SCO07
N
13
6
2007 Ozone Season CO Emissions (tons)
SVOC07
N
13
6
2007 Ozone Season VOC Emissions (tons)
MAY VOC07
N
13
6
2007 May VOC Emissions (tons)
JUN VOC07
N
13
6
2007 June VOC Emissions (tons)
JUL VOC07
N
13
6
2007 July VOC Emissions (tons)
AUG VOC07
N
13
6
2007 August VOC Emissions (tons)
SEP VOC07
N
13
6
2007 September VOC Emissions (tons)
MAY NOX07
N
13
6
2007 May NOx Emissions (tons)
JUN NOX07
N
13
6
2007 June NOx Emissions (tons)
JUL NOX07
N
13
6
2007 July NOx Emissions (tons)
AUG NOX07
N
13
6
2007 August NOx Emissions (tons)
SEP NOX07
N
13
6
2007 September NOx Emissions (tons)
MAY CO07
N
13
6
2007 May CO Emissions (tons)
JUN CO07
N
13
6
2007 June CO Emissions (tons)
JUL CO07
N
13
6
2007 July CO Emissions (tons)
AUG CO07
N
13
6
2007 August CO Emissions (tons)
SEP CO07
N
13
6
2007 September CO Emissions (tons)
MAY VMT07
N
16
3
2007 May VMT
JUN VMT07
N
16
3
2007 June VMT
JUL VMT07
N
16
3
2007 July VMT
AUG VMT07
N
16
3
2007 August VMT
SEP VMT07
N
16
3
2007 September VMT
------- |