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.


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APPENDIX A

2007 BASE CASE CONTROLS


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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


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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


-------
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


-------