Appendix A-2: 

2007 Emissions Inventory

Documentation

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Development of the Point Source 

Emission Inventory for 2007 

in the SESARM Region 

(Version 1.10a) 

Prepared for: 

John Hornback 

Executive Director, Southeastern States Air Resource Managers, Inc. 

526 Forest Parkway, Suite F 

Forest Park, GA 30297-6140. 

(404) 361-4000, FAX (404) 361-2411 

hornback@metro4-sesarm.org

Prepared by: 

AMEC E&I, Inc. 

404 SW 140th Terrace 

Newberry, FL 32669 

(352) 333-6617, FAX (352) 333-6622 

wrbarnard@ AMEC.com

Mark Diblin 

Senior Principal 

William R. Barnard 

Senior Principal 

AMEC Project No.: 6066-09-0326.02 

Contract No.: S-2009-06-02 

March 27, 2012 

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Table of Contents 

1.0 ANNUAL 2007 INVENTORY FOR POINT SOURCES .......................................................... 1

1.1 INTRODUCTION ............................................................................................................... 1

1.2 INITIAL DATA SOURCES AND QA REVIEW .................................................................... 2 

1.2.1 State Submittals and Conversion into a NIF Database ............................................. 2

1.2.1.1 Alabama ................................................................................................................ 5 

1.2.1.2 Alabama – Jefferson County ................................................................................. 5 

1.2.1.3 Florida ................................................................................................................... 6 

1.2.1.4 Georgia .................................................................................................................. 6 

1.2.1.5 Kentucky ................................................................................................................ 6 

1.2.1.6 Kentucky – Jefferson County................................................................................. 6 

1.2.1.7 Mississippi ............................................................................................................. 7 

1.2.1.8 North Carolina ....................................................................................................... 7 

1.2.1.9 North Carolina – Buncombe County ...................................................................... 7 

1.2.1.10 North Carolina – Forsyth County ....................................................................... 8 

1.2.1.11 North Carolina – Mecklenburg County .............................................................. 8 

1.2.1.12 South Carolina ................................................................................................... 9 

1.2.1.13 Tennessee ....................................................................................................... 10 

1.2.1.14 Tennessee – Davidson County ....................................................................... 10 

1.2.1.15 Tennessee – Hamilton County ........................................................................ 10 

1.2.1.16 Tennessee – Knox County .............................................................................. 10 

1.2.1.17 Tennessee – Shelby County ........................................................................... 10 

1.2.1.18 Virginia ............................................................................................................. 11 

1.2.1.19 West Virginia ................................................................................................... 11

1.3 EPA CAMD HOURLY EMISSION DATA ......................................................................... 11

1.4 PM AUGMENTATION ..................................................................................................... 12 

1.4.1 Initial QA and Remediation of PM Pollutants .......................................................... 14

1.4.2 Updating of PM Factor Ratios ................................................................................. 15

1.4.3 PM Emission Calculations ....................................................................................... 15

1.4.4 PM Emission Results .............................................................................................. 17

1.5 EMISSION RELEASE POINT QA CHECKS .................................................................... 18 

1.5.1 QA Checks and Gap-Filling for Location Coordinates ............................................. 18

1.5.2 QA Checks and Gap-Filling for Emission Release Parameters .............................. 19

1.6 STATE REVIEW OF INITIAL VERSION .......................................................................... 22 

1.6.1 Alabama .................................................................................................................. 22

1.6.2 Alabama – Jefferson County ................................................................................... 22

1.6.3 Florida ..................................................................................................................... 22

1.6.4 Georgia .................................................................................................................... 23

1.6.5 Kentucky .................................................................................................................. 24

1.6.6 Kentucky – Jefferson County .................................................................................. 25

1.6.7 Mississippi ............................................................................................................... 25

1.6.8 North Carolina ......................................................................................................... 25

1.6.9 North Carolina – Buncombe County ........................................................................ 26

1.6.10 North Carolina – Forsyth County ......................................................................... 26

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1.6.11 North Carolina – Mecklenburg County ................................................................ 26

1.6.12 South Carolina ..................................................................................................... 26

1.6.13 Tennessee ........................................................................................................... 27

1.6.14 Tennessee – Davidson County ........................................................................... 28

1.6.15 Tennessee – Hamilton County ............................................................................ 28

1.6.16 Tennessee – Knox County .................................................................................. 28

1.6.17 Tennessee – Shelby County ............................................................................... 28

1.6.18 Virginia ................................................................................................................ 28

1.6.19 West Virginia ....................................................................................................... 29

1.7 STAKEHOLDER REVIEW .............................................................................................. 29

1.7.1 Alabama .................................................................................................................. 29

1.7.2 Florida ..................................................................................................................... 29

1.7.3 Georgia .................................................................................................................... 30

1.7.4 Kentucky .................................................................................................................. 30

1.7.5 North Carolina ......................................................................................................... 30

1.7.6 Tennessee ............................................................................................................... 30

1.8 IDENTIFICATION OF EGU AND NONEGU POINT SOURCES ...................................... 30

1.9 FINAL S/L AGENCY QA REVIEW ................................................................................... 31 

1.9.1 Kentucky .................................................................................................................. 32

1.9.2 North Carolina ......................................................................................................... 32

1.9.3 North Carolina – Forsyth County ............................................................................. 32

1.9.4 South Carolina ......................................................................................................... 32

1.9.5 Virginia .................................................................................................................... 32

1.9.6 West Virginia ........................................................................................................... 32

1.10 2007 POINT SOURCE EMISSION SUMMARY ........................................................... 70 

1.11 DATA FILES ................................................................................................................ 79 

1.12 REFERENCES ............................................................................................................ 80

List of Exhibits

Exhibit 1 – Summary of Initial Point Source Submittals 

Exhibit 2 – PM Compound Descriptions 

Exhibit 3 – PM Compounds Reported in Initial State Submittals 

Exhibit 4 – PM Cases and Steps Required to Augment PM Emissions 

Exhibit 5 – Comparison of PM Emissions from the Initial S/L Data Submittals and Version 1.1 of 

the SEMAP 2007 Point Source Inventory 

Exhibit 6 – Stack Parameter Data Replacement Matrix 

Exhibit 7 – 2002 and 2007 Point Source CO Emissions by State 

Exhibit 8 – 2007 Point Source CO Emissions by Category 

Exhibit 9 – 2002 and 2007 Point Source NH3 Emissions by State 

Exhibit 10 – 2007 Point Source NH3 Emissions by Category 

Exhibit 11 – 2002 and 2007 Point Source NOx Emissions by State 

Exhibit 12 – 2007 Point Source NOx Emissions by Category 

Exhibit 13 – 2002 and 2007 Point Source PM10-PRI Emissions by State 

Exhibit 14 – 2007 Point Source PM10-PRI Emissions by Category 

Exhibit 15 – 2002 and 2007 Point Source PM25-PRI Emissions by State 

Exhibit 16 – 2007 Point Source PM25-PRI Emissions by Category 

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Exhibit 17 – 2002 and 2007 Point Source SO2 Emissions by State 

Exhibit 18 – 2007 Point Source SO2 Emissions by Category 

Exhibit 19 – 2002 and 2007 Point Source VOC Emissions by State 

Exhibit 20 – 2007 Point Source VOC Emissions by Category 

List of Acronyms and Abbreviations

Acronym Description 

AMEC AMEC Environment & Infrastructure, Inc. 

CAMD Clean Air Markets Division of EPA 

CAP Criteria Air Pollutant 

CEM Continuous Emission Monitoring System 

CE Control Equipment (NIF table) 

CERR Consolidated Emission Reporting Rule 

CO Carbon Monoxide 

EGU Electric Generating Unit 

EM Emission (NIF table) 

EP Emission Process (NIF table) 

EPA U.S. Environmental Protection Agency 

ER Emission Release (NIF table) 

EU Emission Unit (NIF table) 

LATLON Latitude / Longitude 

MANE-VU Mid-Atlantic/Northeast Visibility Union 

MARAMA Mid-Atlantic Regional Air Management Association 

NAAQS National Ambient Air Quality Standards 

NEI National Emission Inventory 

NH3 Ammonia 

NIF3.0 National Emission Inventory Input Format Version 3.0 

nonEGU Non Electric Generating Unit 

NOx Oxides of Nitrogen 

PE Period (NIF table) 

PM Particulate Matter 

PM-CON Primary PM, Condensable portion only (all < 1 micron) 

PM-FIL Primary PM, Filterable portion only 

PM-PRI Primary PM, includes filterables and condensables 

PM-PRI= PM-FIL + PM-CON 

PM10-FIL Primary PM10, Filterable portion only 

PM10-PRI Primary PM10, includes filterables and condensables, 

PM10- PRI = PM0-FIL + PM-CON 

PM25-FIL Primary PM2.5, Filterable portion only 

PM25-PRI Primary PM2.5, includes filterables and condensables 

PM25-PRI= PM25-FIL + PM-CON 

QA Quality Assurance 

QAPP Quality Assurance Project Plan 

SCC Source Classification Code 

SEMAP Southeastern Modeling, Analysis, and Planning 

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Acronym Description 

SESARM Southeastern State Air Resource Managers, Inc. 

SMOKE Sparse Matrix Operator Kernel Emissions (modeling system) 

SI Site (NIF Table) 

SIC Standard Industrial Classification code 

SIP State Implementation Plan 

S/L State/Local 

SO 

2 Sulfur Dioxide 

TR Transaction (NIF Table) 

TSD Technical Support Document 

UTM Universal TransMercator 

VISTAS Visibility Improvement State and Tribal Association of the Southeast 

VOC Volatile Organic Compounds 

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1.0 ANNUAL 2007 INVENTORY FOR POINT SOURCES 

1.1 INTRODUCTION 

In 2009, the Southeastern State Air Resource Managers, Inc. (SESARM) initiated a new 

Southeastern Modeling, Analysis, and Planning (SEMAP) project. The SEMAP project addresses 

the next phase of ozone, fine particle, and regional haze assessment obligations through funding 

from two grants awarded by the U.S. Environmental Protection Agency (EPA). 

This technical support document (TSD) explains the data sources, methods, and results for 

preparing the 2007 criteria air pollutant (CAP) and ammonia (NH3) emission inventory for point 

sources for the Southeastern U.S. The region includes Alabama, Florida, Georgia, Kentucky, 

Mississippi, North Carolina, South Carolina, Tennessee, Virginia, and West Virginia. In general, point 

sources in this inventory are sources classified as major sources under the Title V permitting 

program and sources required to submit hourly emissions data to EPA under various Clean Air Act 

programs. Some State and local agencies included smaller sources in the point source inventory. 

The inventory includes annual emissions for sulfur dioxide (SO 

2), oxides of nitrogen (NOx), volatile 

organic compounds (VOC), carbon monoxide (CO), ammonia (NH3), and five components of 

particulate matter (PM). 

The inventory also includes particulate matter (PM) emissions, categorized as filterable, 

condensable, or total. Filterable emissions are generally considered to be the particles that are 

trapped by the glass fiber filter in the front half of a Reference Method 5 or Method 17 sampling train. 

Vapors and particles less than 0.3 microns pass through the filter. Condensable particulate matter is 

material that is emitted in the vapor state which later condenses to form homogeneous and/or 

heterogeneous aerosol particles. The PM species in the inventory are categorized as: all filterable 

and condensable particles with an aerodynamic diameter less than or equal to a nominal 10 and 2.5 

micrometers (i.e., PM10-PRI and PM25-PRI); filterable particles with an aerodynamic diameter less 

than or equal to a nominal 10 and 2.5 micrometers (i.e., PM10-FIL and PM25-FIL); and condensable 

particles (PM-CON). Note that PM10-PRI equals the sum of PM10-FIL and PM-CON, and PM25-

PRI equals the sum of PM25-FIL and PM-CON. 

The EPA has provided guidance on developing emission inventories to be used with models and 

other analyses for demonstrating attainment of air quality goals for ozone, fine particles, and regional 

haze (EPA 2005, EPA 2007). According to the EPA guidance, there are potentially two different 

base year emissions inventories. One is the base case inventory which represents the actual 

emissions for the meteorological period that is being modeled. This inventory is generally used for 

model performance evaluations. The second potential base year inventory is called the baseline

inventory, which is generally used as the basis for projecting emissions to the future. The base case

inventory may include day specific information (e.g. hourly continuous emission monitoring data for 

point sources) that USEPA considers not appropriate for using in future year projections. Therefore, 

the baseline inventory may need to replace the day specific emissions with average or “typical” 

emissions (for certain types of sources). However, while a “typical” EGU inventory was prepared 

and submitted to SEMAP for review and comment, it was never finalized. As a consequence, for the 

2007 SEMAP point source inventory, the base case and baseline inventories are one in the same. 

As indicated above, a “typical” year inventory for EGU sources was prepared as part of the base 

year point source development effort. That inventory was provided to the states for review, but 

AMEC never received any comments back from that review. Thus the “typical” EGU inventory was 

never finalized or put into NIF format. The inventory contained 3-year average SO2, NOx, and heat 

input for each unit that reports data to CAMD. 

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The inventory went through several rounds of quality assurance (QA) reviews by State and local 

(S/L) agencies, as well as a review by stakeholders. Numerous corrections and improvements were 

made to the inventory. Updated versions of the inventory were released throughout the inventory 

development process to facilitate S/L agency and stakeholder review. The following summarizes the 

different versions of the inventory: 

 Version 1.1, released April 2010. S/L agency submittals were compiled into this initial 

version of the inventory, emissions for units reporting to EPA’s Clean Air Markets Division 

(CAMD) were analyzed, and the PM emissions were augmented to provide a complete set of 

PM species. Sections 1.2, 1.3, and 1.4 of this report describe the work done to prepare 

Version 1.1. 

 Version 1.2, not released. This version was used internally and included updates to stack 

parameters as described in Section 1.5 of this report. 

 Version 1.3, released May 18, 2010. This version contained the updates and corrections to 

the inventory specified by S/L agencies as described in Section 1.6. This version was 

released for Stakeholder review. 

 Version 1.4, not released. This version was used internally and included updates to classify 

units into electric generating units (EGUs) and nonEGUs according to the classification 

scheme discussed in Section 1.7. It also included updates and corrections based upon 

stakeholder review, as well as additional review by S/L agencies, as described in 

Section 1.8. 

 Version 1.5, released September 2, 2010. This version removed extraneous or incomplete 

information that was not needed for air quality modeling, such as emissions of hazardous air 

pollutants and emissions for non-annual averaging times. This version was provided to 

SEMAP for use in preparing emission density maps and bubble plots that were provided to 

S/L agencies for final QA of source locations and emission values. 

 Version 1.6, released October 20, 2010. This version included updates provided by S/L 

agencies after their review of the emission density maps and bubble plots. 

 Version 1.7, released December 7, 2010. This version included emission updates to two 

facilities in Kentucky and replaced geographic coordinates with latitude and longitude for all 

sources (in previous versions, the geographic coordinates were a mixture of 

latitude/longitude and UTM coordinates, depending on the agency). 

 Version 1.8, released January 26, 2001. This version included revisions to the 

documentation and data files to respond to comments from EPA Region 4 dated November 

10, 2011. The main revision to the data files was to delete facilities in North Carolina that 

had permanently shutdown prior to 2007 but were inadvertently included in the 2007 

inventory with non-zero emissions. 

State-level emission summaries of the 2007 point source inventory, referred to as Version 1.10a are 

provided in Section 1.10. Final deliverables are described in Section 1.11. 

1.2 INITIAL DATA SOURCES AND QA REVIEW 

Version 1.1 of the 2007 point source inventory was developed using data submitted by State and 

local agencies in the region, as well as data from the CAMD hourly emission monitoring database. 

1.2.1 State Submittals and Conversion into a NIF Database 

Each S/L agency collects point source data according to EPA approved procedures that are included 

in each State’s point source emission inventory quality assurance project plan with accompanying 

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standard operating procedures. These plans and procedures are updated on a continuing basis and 

are available upon request. 

States were requested to submit 2007 data for those major sources that they would normally submit 

to EPA during the 3-year requirements of the Consolidated Emission Reporting Rule (CERR). Some 

S/L agencies were able to submit a complete set of data representing 2007. Other S/L agencies 

were only able to submit 2007 data for very large sources. In this case, inventories for other years 

were used to create a complete 2007 point source inventory. In a few other cases, the S/L agency 

submittal was supplemented with data from EPA’s 2005-based modeling platform (EPA 2009c). S/L 

agencies prepare point source emission inventory files in a variety of formats – some use the NEI 

Input Format (NIF) while others used different formats. Exhibit 1 summarizes the data sources and 

formats for the S/L agency point source submittals with additional explanatory notes provided in the 

following sections. 

As noted in Exhibit 1, a few S/L agencies provided emissions data for a year other than 2007. 

Georgia was the only State that requested that a linear projection from 2005/2008 to 2007 be made 

when both 2005 and 2008 were available. There result of this interpolation for Georgia showed that 

for sources where 2007 were not available, the emissions changed very little between 2005 and 

2007. Other S/L agencies indicated that 2005, 2006, or 2008 emissions data should be considered 

representative of 2007 for modeling purposes. This recommendation appears to be reasonable, 

given the small amount of emissions associated with the facilities where 2007 were not available 

(i.e., 97 percent of the point source NOx emissions and 99 percent of the SO 

2 emissions are 2007 

data). It was decided that spending limited resources to obtain and apply appropriate growth factors 

to project these emissions from 2005/2006/2008 to 2007 would provide an almost unnoticeable 

improvement to the SEMAP 2007 inventory. 

Also note that some S/L agencies submitted many more facilities than were included in the 2002 

VISTAS inventory, while others submitted fewer facilities. An explanation of the reason why the 

number of facilities differs between 2002 and 2007 is provided for each S/L agency in the following 

sub-sections. SESARM’s area source contractor has developed procedures to reconcile the point 

and area source inventories to both (1) ensure that emissions minor point sources that are included 

the point source inventory are not double counted in the area source inventory and (2) that 

emissions from minor point source sources that are not in the point source inventory are included in 

the area source inventory. 

After the each S/L submittal was formatted into a standard NIF database, AMEC Environment & 

Infrastructure, Inc. (AMEC) performed an initial review of the S/L inventories using EPA’s Basic 

Format and Content Checker tool (EPA 2004). The tool was used to verify the data was in the 

correct format, to check for referential integrity and duplicate record issues, and to check certain 

fields for proper valid codes and ranges. Only minor issues were identified and were resolved by 

AMEC without the need for assistance from the S/L agencies. Following this initial QA review, these 

individual inventory files were consolidated into a single data set. Additional QA activities identified 

in the Quality Assurance Project Plan (SESARM 2009) were carried out and documented in the 

remainder of this document. 

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Exhibit 1 – Summary of Point Source Data Sources 

Agency 

# of 

Facilities in 

VISTAS 2002 

Inventory 

# of Facilities 

in SEMAP 

2007 V_1.10a

Inventory 

Submittal 

Format Data Used for 2007 Inventory 

AL 319 909 NIF ACCESS 2007 data for 328 major facilities; 

2007 data for 613 minor facilities; 

32 facilities had only HAP emissions 

and were removed from the 2007 

CAP inventory 

AL 

Jefferson 

243 237 NIF ACCESS 2007 data for 37 very large facilities; 

2005 S/L data for 237 facilities, 

which also included the 37 very 

large facilities 

FL 1,050 1,136 NIF Text 2007 data for 1,136 facilities 

GA 234 268 NIF ACCESS 2007 S/L data for 74 facilities 

2007 CAMD data for 19 facilities not 

in S/L submittal 

2008 S/L data for 109 additional 

facilities 

2005 S/L data for 66 additional 

facilities 

KY 1,581 2,306 NIF xml 2007 data for 2,780 facilities 

474 facilities had only HAP 

emissions and were removed from 

the 2007 CAP inventory 

781 facilities were included in the 

2007 SEMAP inventory but were not 

included in the 2002 VISTAS 

inventory 

KY 

Jefferson 

76 155 NIF ACCESS 2007 data for 155 facilities 

MS 640 282 NIF Text 2007 data for 46 facilities 

2005 NEI data for 236 facilities 

NC 994 1,908 ORL xls 2007 data for 2,145 facilities 

See Section 1.1.1.8 for more 

information regarding the increase in 

the number of facilities 

NC 

Buncombe 

6 64 NIF ACCESS 2007 data for 9 Title V facilities 

2006 S/L data 64 facilities, which 

also included the 9 Title V facilities 

NC 

Forsyth 

30 82 EIS ACCESS 2007/08 data for 82 facilities 

See Section 1.9.3 for discussion 

NC 

Mecklenburg 

242 221 Quasi-ORL 

xls 

2007 data for 221 facilities 

SC 802 291 NIF xml 2007 data for 291 facilities 

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Agency 

# of 

Facilities in 

VISTAS 2002 

Inventory 

# of Facilities 

in SEMAP 

2007 V_1.10a

Inventory 

Submittal 

Format Data Used for 2007 Inventory 

TN 373 232 NIF xls 2007 data for 166 Type A and other 

facilities 

2005 NEI data for 66 facilities 

TN 

Davidson 

201 205 NIF Text 2007 data for 205 facilities 

TN 

Hamilton 

220 177 Quasi-ORL 

xls 

2007 data for 177 facilities 

TN 

Knox 

11 8 NIF ACCESS 2007 data for 8 facilities 

TN 

Shelby 

35 29 NIF xls 2008 S/L data for 29 facilities 

VA 762 801 NIF ACCESS 2007 data for 801 facilities 

WV 192 177 NIF ACCESS 2007 data for 177 facilities 

1.2.1.1 Alabama 

Alabama’s initial submittal contained two National Emission Inventory (NEI) Input Format (NIF) 

ACCESS database files. The first contained 2007 emissions data for 328 major sources, while the 

second contained 2007 emission data for 613 minor sources. AMEC merged the major source file 

with the minor source found and identified 10 facilities that were in both files. We used the data from 

the 2007 major source file and deleted the data from the minor source file to ensure that there was 

no double counting of emissions for these 10 facilities. Alabama ensured that the minor source 

emissions that were included in the point source file were not double counted in the area source file. 

Another contractor reconciled the point and area source inventories and Alabama reviewed the 

results on a per category basis to ensure that double counting did not occur. 

There were numerous records flagged for out-of-range values for stack parameters or location 

coordinates, or inconsistencies between the flow rate and velocity. These cases are discussed later 

in this document. A large increase in VOC and PM emissions from 2002 to 2007 was identified. 

Alabama investigated this problem and identified a serious problem in their data conversion process. 

New Emission (EM) and Control Equipment (CE) tables were provided in May 2010 to correct this 

problem. 

1.2.1.2 Alabama – Jefferson County 

Jefferson County submitted two NIF ACCESS database files. The first contained 2007 emissions 

data for 37 very large sources, while the second contained 2005 emission data for 237 sources. 

AMEC merged the 2007 very large source file with the 2005 file and identified that the 37 very large 

facilities were in both files. We used the data from the 2007 file and deleted the corresponding 

facilities from the 2005 file to ensure no double counting of emissions. AMEC did not project 2005 

emission data to 2007, as the 2005 data was considered to be representative of 2007. 

Jefferson County submitted emissions data for a large number of hazardous air pollutants. Since 

these pollutants are not needed for regional ozone and fine particle modeling, they were stripped 

from the EM and CE tables. 

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The EPA’s Basic Format and Content Checker identified several relational widow/orphan issues. 

These were caused by the Emission Unit ID and Emission Release Point ID being reversed in the 

EP table for some records. AMEC made the necessary corrections to the NIF EP table to ensure 

that all NIF EM records had a match in the NIF Emission Unit (EU), Emission Process (EP), and EM 

tables. 

The flow rates provided in the NIF Emission Release (ER) table were reported in cubic feet per 

minute. The NIF specifications require that this field be reported in cubic feet per second. AMEC 

recalculated the flow rate by dividing the flow rate provided by Jefferson County by 60. 

1.2.1.3 Florida 

Florida submitted NIF tables in ASCII text format with 2007 emissions data for 1,139 facilities. There 

were numerous records flagged for out-of-range values for stack parameters or location coordinates, 

or inconsistencies between the flow rate and velocity by the EPA’s Basic Format and Content 

Checker. These cases are discussed later in Section 1.5 of this document. Otherwise the data 

passed all of the QA checks. 

1.2.1.4 Georgia 

Georgia submitted three NIF ACCESS database files. The first contained 2007 emissions data for 

74 very large sources. The second file contained 2008 emission data for 109 additional facilities. 

And the third file contained 2005 data for 69 additional facilities. AMEC merged the three files using 

the 2007 data when available, the 2008 data where 2007 data were not available, and 2005 data as 

a last resort. We used the data from the 2007 file and deleted the corresponding facilities from the 

2008/2005 files to ensure no double counting of emissions. No significant issues were identified by 

EPA’s Basic Format and Content Checker. No projecting of 2005 emissions to 2007 or back casting 

of 2008 emissions to 2007 was done during the initial processing of the submittals. See Section 

1.6.4 for a discussion of how 2007 emissions were subsequently estimated for the final SEMAP 

inventory when only 2005 or 2008 data were available. 

1.2.1.5 Kentucky 

Kentucky submitted an xml file that was loaded into an ACCESS database with NIF tables with 2007 

emissions data for 2,780 facilities. There were approximately 474 facilities in Kentucky’s submittal 

that had only HAP emissions (i.e., emissions were zero for all criteria air pollutants at the facility) and 

were removed from the 2007 inventory. An additional 781 facilities were included in the 2007 

SEMAP inventory but were not included in the 2002 VISTAS inventory. These additional facilities in 

the 2007 SEMAP inventory were generally very small sources, and the aggregate NOx emissions 

from these 781 small facilities totaled only 805 tons per year. 

The EPA’s Basic Format and Content Checker identified several relational widow issues, that is, 

there were SI, ER, EU, EP, PE and CE records with no corresponding emissions data in the EM file. 

These widow records were removed from the SI, ER, EU, EP, PE, and CE tables. 

The flow rates provided in the ER table were reported in cubic feet per minute. The NIF 

specifications require that this field be reported in cubic feet per second. AMEC recalculated the 

flow rate by dividing the flow rate provided by Kentucky by 60. 

There were numerous records flagged for out-of-range values for stack parameters or location 

coordinates, or inconsistencies between the flow rate and velocity by the EPA’s Basic Format and 

Content Checker. These cases are discussed later in Section 1.5 of this document. 

1.2.1.6 Kentucky – Jefferson County 

Jefferson County submitted two NIF ACCESS databases containing 2007 emissions data – one file 

contained criteria air pollutants and the other file contained hazardous air pollutants. Only the 

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criteria air pollutant file was processed. Jefferson County’s submittal passed all of checks made by 

the EPA’s Basic Format and Content Checker. 

 

1.2.1.7 Mississippi 

Mississippi submitted NIF tables in ASCII text format with 2007 emissions data for 45 facilities. 

Mississippi’s submittal passed all of checks made by the EPA’s Basic Format and Content Checker. 

Mississippi’s 2007 submittal was supplemented with data from EPA’s 2005-based modeling platform 

(EPA 2009c). The data were provided in SMOKE ORL format, converted into a NIF database, and 

merged with Mississippi’s submittal. We used the data from Mississippi’s 2007 file and deleted the 

corresponding facilities from the 2005 EPA file to ensure no double counting of emissions. 

Mississippi decided to include 236 facilities from the 2005 NEI from the 2007 SEMAP inventory. At 

this time, AMEC did not perform any projecting of 2005 data to 2007. No significant issues were 

identified by EPA’s Basic Format and Content Checker. 

 

1.2.1.8 North Carolina 

North Carolina submitted a SMOKE one-record-per-line (ORL) file with 2007 data for 2,145 facilities. 

AMEC converted the ORL file to a NIF database. There was no control information in the ORL file, 

so we were not able to create a NIF CE table. 

There were numerous records flagged for out-of-range values for stack parameters or location 

coordinates, or inconsistencies between the flow rate and velocity by the EPA’s Basic Format and 

Content Checker. These cases are discussed later in Section 1.5 of this document. Otherwise the 

data passed all of the QA checks. 

A large increase in VOC emissions from 2002 to 2007 was identified. North Carolina investigated 

this problem and identified a serious problem in their data conversion process. New EM and CE 

tables were provided in May 2010 to correct this problem. 

The 2007 SEMAP inventory contains many more sources than were included in the 2002 VISTAS 

inventory. There are three reasons to explain the large increase in the number of facilities in the 

2007 inventory versus the 2002 inventory: 

 There are some new permit sources added since 2002; 

 There were about 163 facilities in NC’s initial submittal that were permanently closed 

between 2002 and 2006 that were inadvertently left in the 2007 inventory with non-zero 

emissions. These facilities were removed from the 2007 SEMAP inventory; and 

 Most the new facilities in 2007 are due to the following reason: 2002 was the year NC 

changed the emission reporting system. From 1993 to 2002, all non-title V sources reported 

their emission once every three years (1993, 1996, 1999, and 2002). Since 2002, NC 

changed the emission reporting system from once every three years to once every five year 

and each facility reports their emission the year their permit expired. So the 2007 point 

source emission inventory is much more inclusive compared to 2002 emission inventory, 

which only included the facilities reported during the year of 2002, not all facilities that 

operated in 2002. 

1.2.1.9 North Carolina – Buncombe County 

Buncombe County submitted two NIF ACCESS database files. The first contained 2007 emissions 

data for 9 Title V facilities, while the second contained 2006 emission data for 65 facilities. AMEC 

merged the 2007 Title V source file with the 2006 file and verified that the 9 Title V facilities were in 

both files. We used the data from the 2007 file for the Title V facilities and deleted the corresponding 

facilities from the 2006 file to ensure no double counting of emissions. We also deleted all records 

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for Snider Tire (Facility ID 0861) which ceased operation in 2006 and did not operate in 2007. 

AMEC did not project the 2006 emissions to 2007, as the 2006 emissions are considered to be 

representative of 2007. 

There were several records flagged for out-of-range values for stack parameters or location 

coordinates, or inconsistencies between the flow rate and velocity by the EPA’s Basic Format and 

Content Checker. These cases are discussed later in Section 1.5 of this document. Otherwise the 

data passed all of the QA checks. 

1.2.1.10 North Carolina – Forsyth County 

Forsyth County provided 2008 data for 84 facilities in an EIS-formatted ACCESS database. The 

data is actually a mix of 2008, 2007 and previous year data, but Forsyth County indicated that the 

submittal is representative of calendar year 2007. AMEC performed data reformatting a number of 

data augmentation steps to create reasonably complete NIF tables, as follows: 

 SI Table – relevant fields from the “FacilitySite” ACCESS table were mapped to NIF SI table 

fields. 

 ER Table – relevant fields from the “ReleasePoint” ACCESS table were mapped to NIF ER 

table fields. The flow rate in the “Release Point” table was in cubic feet per minute. The NIF 

specifications require that this field be reported in cubic feet per second. AMEC recalculated 

the flow rate by dividing the flow rate provided by 60. There were no stack-level geographic 

coordinates in the “ReleasePoint GeographicCoordinates” ACCESS table. However, there 

were facility-level coordinates for some facilities in the “FacilitySiteGeographicCoordinates” 

ACCESS table, and these were used for all emission release points associated with the 

facility. Where a facility match could not be made, we substituted the county centroid for the 

geographic coordinates (longitude -80.24, latitude 36.114). 

 EU Table – relevant fields from the “EmissionUnit” ACCESS table were mapped to NIF EU 

table fields. 

 EP Table – relevant fields from the “EmissionProcess” ACCESS table were mapped to NIF 

EP table fields. The emission release point identifier was obtained from the 

“ReleasePointApportionment” ACCESS table. 

 PE Table – relevant fields from the “EmissionProcess” ACCESS table were mapped to NIF 

PE table fields. 

 CE Table – no information on control equipment was provided. 

 EM Table – relevant fields from the “Emissions” ACCESS table were mapped to NIF ER 

table fields. The emission release point identifier was obtained from the 

“ReleasePointApportionment” ACCESS table. 

There were several records flagged for out-of-range values for stack parameters or location 

coordinates, or inconsistencies between the flow rate and velocity by the EPA’s Basic Format and 

Content Checker. These cases are discussed later in Section 1.5 of this document. Otherwise the 

data passed all of the QA checks. 

1.2.1.11 North Carolina – Mecklenburg County 

Mecklenburg County provided 2007 emissions data for 539 facilities in a spreadsheet that contained 

a limited number of NIF fields. AMEC performed data reformatting and a number of data 

augmentation steps to create reasonably complete NIF tables, as follows: 

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 SI Table – only the facility id# and facility name were provided; we obtained the SIC code 

from the VISTAS 2002 B&F inventory where we were able to match facilities. 

 ER Table – the submittal did not contain any stack parameters and the geographic 

coordinates were in NC State Planar coordinates, not UTM coordinates or latitude/longitude 

as required by the NIF specification. To fill in the geographic coordinates, we obtained the 

latitude and longitude from the VISTAS 2002 B&F inventory where we were able to match 

facilities. Where a facility match could not be made, we substituted the county centroid for 

the geographic coordinates (longitude -80.789, latitude 35.252). Stack parameters for the 

Stage I gasoline distribution facilities were assigned a fugitive release height of 10 feet. 

Stack parameters for all other sources will be filled in according to the gap-filling procedures 

discussed later in Section 1.5 of this document. 

 EU Table – the submittal only contained the unit description, all other EU non-key data 

elements were left blank. 

 EP Table – the submittal only contained SCC and the process description, all other EP nonkey data elements were left blank. 

 PE Table – we filled in the PE table with the PE key identifiers, and added the startdate of 

20070101 and end date of 20071231. All other PE non-key data elements were left blank. 

 CE Table – no control information was provided, so the CE table is blank. 

 EM Table – the submittal contained annual emissions for all criteria air pollutants and 

ammonia. 

After reformatting the spreadsheet into NIF tables, we ran the EPA’s Basic Format and Content 

Checker and did not detect any QA issues other than the missing stack parameters. 

Mecklenburg County initially included 319 Stage I gasoline stations in the point source inventory. 

For consistency with other counties in North Carolina (where Stage I emissions are included in the 

area source inventory) and to avoid double counting, these gasoline stations were removed from the 

point source inventory. 

1.2.1.12 South Carolina 

South Carolina submitted an xml file that was loaded into an ACCESS database with NIF tables with 

2007 emissions data for 293 facilities. 

The EPA’s Basic Format and Content Checker identified that certain EM records associated with 

facility ID 2320-0034 (NAN YA Plastics) were assigned to FIPS 45041 (Florence County) while other 

NIF records associated with this plant were associated with FIPS 45089 (Williamsburg County). 

AMEC changed the FIPS to 45089 for the records in the EM table to resolve this orphan issue. 

Geographic coordinates in the ER table were not changed. 

The flow rates provided in the ER table were reported in cubic feet per minute. The NIF 

specifications require that this field be reported in cubic feet per second. AMEC recalculated the 

flow rate by dividing the flow rate provided by South Carolina by 60. 

South Carolina’s 2007 submittal included many fewer facilities than were in the VISTAS 2002 

inventory. South Carolina reviewed data from EPA’s 2005-based modeling platform. South Carolina 

decided that the sources that were included in the 2002 but not in the 2007 inventory were 

predominantly minor sources, and that the use of EPA’s 2005 NEI data was not appropriate for use 

in the 2007 SEMAP inventory. 

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1.2.1.13 Tennessee 

Tennessee submitted two spreadsheets with NIF tables for all counties except the four local program 

counties. The first file contained 2007 emissions data for 45 very large sources (i.e., Type A 

sources), while the second contained 2007 emission data for additional smaller facilities. AMEC 

merged the two files and checked for duplicate facilities. One facility – JW Aluminum (Facility ID 

47113-0010) – was found in both submittals. Only the Type A submittal for this facility was used to 

avoid double counting of emissions. 

Tennessee submitted emissions data for a large number of hazardous air pollutants. Since these 

pollutants are not needed for regional ozone and fine particle modeling, they were stripped from the 

EM and CE tables. 

The EPA’s Basic Format and Content Checker identified several relational widow/orphan issues. 

AMEC made the necessary corrections to the NIF tables to ensure that all EM records had a match 

in the EU, EP, PE and EM tables. 

Tennessee’s 2007 submittals were supplemented with data from EPA’s 2005-based modeling 

platform. These data were downloaded from EPA’s ftp site (file name: 

2005v4CAPHAP_orl_point.zip). The data were provided in SMOKE ORL format, converted into a 

NIF database, and merged with Tennessee’s submittal. We used the data from Tennessee’s 2007 

files and deleted the corresponding facilities from the 2005 EPA file to ensure no double counting of 

emissions. At this time, AMEC did not perform any projecting of 2005 data to 2007. No significant 

issues were identified by EPA’s Basic Format and Content Checker. An additional 280 facilities 

were added during this augmentation process. 

1.2.1.14 Tennessee – Davidson County 

Davidson County submitted NIF tables in ASCII text format with 2007 emissions data for 

205 facilities. There were numerous records flagged for out-of-range values for stack parameters or 

location coordinates, or inconsistencies between the flow rate and velocity by the EPA’s Basic 

Format and Content Checker. These cases are discussed later in Section 1.5 of this document. 

Otherwise the data passed all of the QA checks. 

1.2.1.15 Tennessee – Hamilton County 

Hamilton County provided data representative of 2007 for 177 facilities in a spreadsheet that 

contained the NIF fields needed for regional air quality modeling. AMEC performed data 

reformatting to create reasonably complete NIF tables. The data passed all of the QA checks. 

1.2.1.16 Tennessee – Knox County 

Knox County submitted a NIF ACCESS database containing 2007 emissions data for 9 facilities. 

There were a few records flagged for out-of-range values for stack parameters or location 

coordinates, or inconsistencies between the flow rate and velocity by the EPA’s Basic Format and 

Content Checker. These cases are discussed later in Section 1.5 of this document. Otherwise the 

data passed all of the QA checks. 

1.2.1.17 Tennessee – Shelby County 

Shelby County submitted a spreadsheet with NIF tables for 29 facilities with 2008 emissions data. 

The 2008 was considered representative of 2007 for all sources except the TVA Allen Plant (Facility 

ID 47157-00528), for which we used the 2007 annual SO 

2 and NOx emissions as reported in EPA’s 

CAMD database. 

Shelby County submitted emissions data for a large number of hazardous air pollutants. Since 

these pollutants are not needed for regional ozone and fine particle modeling, they were stripped 

from the EM and CE tables. 

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The EPA’s Basic Format and Content Checker identified several relational widow/orphan issues. 

AMEC made the necessary corrections to the NIF tables to ensure that all EM records had a match 

in the EU, EP, PE and EM tables. 

1.2.1.18 Virginia 

Virginia submitted a NIF ACCESS database containing 2007 emissions data for 801 facilities. Since 

Virginia is participating with MARAMA in developing a regional modeling inventory for the 

northeastern States, Virginia’s data has already undergone considerable QA review and updating. 

As part of the MARAMA inventory development process, Virginia provided emissions data for a 

number of additional distributed generation units. Virginia’s submittal to MARAMA was subjected to 

the QA and PM augmentation procedures described in this report. Virginia has accepted the 

MARAMA 2007 point source inventory for use in the SEMAP 2007 point source modeling inventory. 

1.2.1.19 West Virginia 

West Virginia submitted a NIF ACCESS database containing 2007 emissions data for 177 facilities. 

West Virginia’s submittal passed all of checks made by the EPA’s Basic Format and Content 

Checker with the exception of some of the stack parameter values. There were numerous records 

flagged for out-of-range values for stack parameters or location coordinates, or inconsistencies 

between the flow rate and velocity by the EPA’s Basic Format and Content Checker. These cases 

are discussed later in Section 1.5 of this document. 

1.3 EPA CAMD HOURLY EMISSION DATA 

The second source of data was the hourly emission data reported to EPA by facilities to comply with 

various provisions of the Clean Air Act. AMEC downloaded the 2007 CAMD annual inventory 

containing NOx and SO 

2 emissions, heat input data and other information from the CAMD web site 

(EPA 2009a). 

AMEC prepared an initial crosswalk file to match facilities and units in the CAMD inventory to 

facilities and units in the 2007 SEMAP inventory. In the CAMD inventory, the Office of Regulatory 

Information Systems (ORIS) identification (ID) code identifies unique facilities and the unit ID 

identifies unique boilers and internal combustion engines (i.e., turbines and reciprocating engines). 

AMEC also downloaded the 2007 CAMD hourly inventory containing hourly NOx and SO 

2 emissions 

and heat input data from the CAMD website (EPA 2009b). AMEC summed the hourly emissions to 

the annual level (or 6-month level for 6-month reporting units) by emission unit. The summed hourly 

data was compared to the annual summary data, which matched in virtually all case. This check was 

made because SEMAP is considering using the actual 2007 hourly data rather than average 

temporal profiles in the next round of regional air quality modeling. 

As a starting point for developing the CAMD-to-NIF crosswalk, AMEC obtained and used the CAMDto-NIF crosswalk that was developed for the VISTAS Best & Final inventory (VISTAS, 2007). This 

file was useful for matching many facilities and units. However, in many other cases either the 

CAMD unit identifier changed or the facility and unit identifiers in the S/L database changed. For 

example, the facility IDs in West Virginia’s 2002 VISTAS database were a 4-digit field, while the 

facility IDs in the 2007 SEMAP inventory are a 5-digit field. In Kentucky, the facility IDs in the 2002 

VISTAS database consisted of the five-digit FIPS code followed by a 5-digit facility ID, while the 

facility IDs in the 2007 SEMAP inventory consisted of only the 5-digit facility ID. In North Carolina, 

nearly all unit IDs changed between 2002 and 2007. 

AMEC prepared an Excel Workbook file for each S/L agency with linkages between the CAMD 

identifiers and the S/L agency identifiers and a comparison between the CAMD annual summary 

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emissions, the annual emissions summed from the hourly CAMD database, and annual emissions 

reported in the S/L inventory. This spreadsheet matched the CAMD unit-level IDs (ORISID and 

UNITID) with corresponding NIF table IDs (FIPS, SITE ID, EU ID, EP ID, ER ID). Emissions were 

shown as obtained from (1) the CAMD unit level file, (2) the sum of the CAMD hourly emission file, 

and (3) the State submitted NIF tables. Note that the CAMD Emissions are reported at the unit level 

while the NIF emissions are reported at the Unit/Process/Stack level. 

AMEC added three fields to the NIF EP table to facilitate the linkage to the CAMD database. We 

added fields to store the CAMD ORISID, CAMD Unit ID, and CAMD number of reporting months. 

AMEC prepared a CAMD-to-NIF crosswalk spreadsheet for each State. S/L agencies were asked to 

review this list and verify that (1) the linkages are correct, (2) there are no large sources missing 

from the CAMD-to-NIF crosswalk, and (3) there are not any large discrepancies between the 

emissions reported to CAMD and the emissions reported in the SEMAP database. 

There are three types of possible linkages: 

 CAMD facility has no match in NIF SI facility table. The emissions from these facilities 

reported to CAMD are small, and initially accounted for about 0.5% of the NOx and 

0.07% of the SO 

2 emissions in the CAMD database. 

 CAMD unit could not be matched in NIF. The emissions from these facilities reported to 

CAMD were small, accounting for about 0.9% of the NOx and 0.007% of the SO 

2

emissions in the CAMD database. Most of the units that could not be matched at the unit 

level are either peaking units or industrial sources such as paper mills or chemical plants. 

In addition, there were several instances where multiple CAMD units match to a single 

NIF record (i.e., units are grouped in the NIF tables but reported individually in the CAMD 

database). 

 CAMD unit matches with a single NIF record or CAMD unit matches with multiple NIF 

records (in many cases, the NIF tables include multiple records for different fuel types). 

The emissions from these units reported to CAMD account for about 98.6% of the NOx

and 99.9% of the SO 

2 emissions in the CAMD database. In most cases the sum of the 

emissions from the matching NIF records are generally very close to the CAMD unit level 

emissions; and S/L agencies verified that linkages were correct. 

As another QA check, AMEC compiled a list of sources with EGU SCCs of 1-01-xxx-xx and 2-01-

xxx-xx in the S/L agency NIF tables that could not be linked to the CAMD CEM table to help resolve 

some of the linkage issues noted above. S/L agencies made significant efforts to improve the 

crosswalk between the CAMD identifiers and the S/L agency identifiers. 

1.4 PM AUGMENTATION 

PM compounds may be reported in several forms, as identified in Exhibit 2. Exhibit 3 provides a 

count of the number of annual NIF EM table records in each agency’s NIF Submittal by type of PM 

compound. The PM augmentations process gap-fills missing PM pollutant complements. We 

generated emission estimates for filterable and primary PM-2.5, filterable and primary PM-10 and 

condensable PM if emission estimates for those species were missing from the S/L agency submittal 

.For example, if a S/L agency provided only PM10-PRI emissions, the PM augmentation process 

filled in estimates for PM-CON, PM10-FIL, PM25-PRI, and PM25-FIL. 

The PM augmentation process is essentially the same process used in developing the 2002 VISTAS 

Best and Final inventory and is virtually identical to the EPA methodology used for the 2002 NEI 

(EPA 2006a). The steps in the PM augmentation process were as follows: 

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 Step 1: Initial QA and remediation of S/L provided PM pollutants; 

 Step 2: Updating of PM factor ratios previously developed for MARAMA based on factors 

from the Factor Information and Retrieval Data System and the EPA PM Calculator; 

 Step 3: Implementation of the ratios developed in step 2; 

 Step 4: Presentation of PM augmentation results to S/L agencies for review and comment; 

and 

 Step 5: Updates to augmented values in cases where the S/L agency was able to obtain 

source-specific data. 

Exhibit 2 – PM Compound Descriptions 

Pollutant 

Code Pollutant Pollutant Description 

PM-CON Primary PM

Condensable portion

only (all < 1 micron) 

Material that is vapor phase at stack conditions, but 

which condenses and/or reacts upon cooling and 

dilution in the ambient air to form solid or liquid PM 

immediately after discharge from the stack. 

PM-FIL Primary PM, Filterable

portion only 

Particles that are directly emitted by a source as a solid 

or liquid at stack or release conditions and captured on 

the filter of a stack test train. 

PM-PRI Primary PM, includes

filterables and

condensables 

PM-PRI= 

PM-FIL + PM-CON 

Particles that enter the atmosphere as a direct 

emission from a stack or an open source. It is 

comprised of two components: Filterable PM and 

Condensable PM. 

PM10-FIL Primary PM10,

Filterable portion only 

Particles with an aerodynamic diameter equal to or less 

than 10 micrometers that are directly emitted by a 

source as a solid or liquid at stack or release conditions 

and captured on the filter of a stack test train. 

PM10-PRI Primary PM10,

includes filterables and

condensables, 

PM10- PRI =

PM0-FIL + PM-CON 

Particles with an aerodynamic diameter equal to or less 

than 10 micrometers that enter the atmosphere as a 

direct emission from a stack or an open source. It is 

comprised of two components: Filterable PM and 

Condensable PM. (As specified in § 51.15 (a)(2), 

These two PM components are the components 

measured by a stack sampling train such as EPA 

Method 5.) 

PM25-FIL Primary PM2.5,

Filterable portion only 

Particles with an aerodynamic diameter equal to or less 

than 2.5 micrometers that are directly emitted by a 

source as a solid or liquid at stack or release conditions 

and captured on the filter of a stack test train. 

PM25-PRI Primary PM2.5,

includes filterables and

condensables 

PM25-PRI= 

PM25-FIL + PM-CON 

Particles with an aerodynamic diameter equal to or less 

than 2.5 micrometers that enter the atmosphere as a 

direct emission from a stack or an open source. It is 

comprised of two components: Filterable PM and 

Condensable PM. (As specified in § 51.15 (a)(2), 

These two PM components are the components 

measured by a stack sampling train such as EPA 

Method 5.) 

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Exhibit 3 – PM Compounds Reported in Initial State Submittals 

 Number of Annual EM Records in S/L Agency’s Initial NIF Submittal 

Agency PMCON PMFIL PMPRI PM10- 

FIL 

PM10- 

PRI 

PM25- 

FIL 

PM25- 

PRI 

AL 0 4,748 0 2,918 0 2,035 0 

AL Jefferson 0 318 0 631 0 626 0 

FL 0 3,576 0 3,672 0 0 0 

GA 0 137 2,912 0 1,869 0 1,285 

KY 0 0 29,856 0 29,859 0 99 

KY Jefferson 20 0 222 20 222 20 214 

MS1 413 56 3,073 429 3,251 429 3,251 

NC 0 0 0 0 9,120 0 5,800 

NC Buncombe 26 40 63 40 63 40 58 

NC Forsyth 12 4 408 23 381 5 210 

NC Mecklenburg 0 0 0 0 613 0 309 

SC1 1,241 409 6,645 1,439 5,992 1,422 4,224 

TN1 2,274 3,175 1,258 2,811 2,560 2,641 2,441 

TN Davidson 0 0 0 0 775 0 649 

TN Hamilton 0 0 394 0 279 0 332 

TN Knox 0 0 0 0 15 0 1 

TN Shelby 57 189 79 70 279 63 99 

VA2 5,238 0 0 5,238 5,241 5,238 5,241 

WV 167 2,138 802 1,814 737 1,586 691 

1) Includes PM records from EPA’s 2005-based modeling inventory, which have already been 

augmented by EPA 

2) Virginia’s PM augmentation was previously performed using an identical augmentation process 

during the development of the 2007 regional emission inventory for the Northeast/Mid-Atlantic 

States

1.4.1 Initial QA and Remediation of PM Pollutants 

Prior to executing the PM augmentation process, we first reviewed the data for inconsistencies. If 

values are found to be inconsistent, they were replaced. The consistency checks and replacement 

actions are as follows: 

1. If PM10-PRI >0 and PM25-PRI > PM10-PRI (and PM10-FIL, PM25-FIL and PM-CON are 

null or 0), then set PM25-PRI = PM10-PRI. 

2. If PM10-FIL > 0 and PM25-FIL > PM10-FIL (and PM10-PRI, PM25-PRI and PM-CON are 

null or 0), then set PM25-FIL = PM10-FIL. 

3. If PM10-PRI >0 and PM10-FIL > PM10-PRI (and PM25-PRI, PM25-FIL and PM-CON are 

null or 0), then set PM10-FIL = PM10-PRI. 

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4. If PM25-PRI > 0 and PM25-FIL > PM25-PRI (and PM10-PRI, PM10-FIL and PM-CON are 

null or 0), then set PM25-FIL = PM25-PRI. 

The consistency checks revealed very few occurrences of inconsistencies, and when 

inconsistencies did occur, the emission values were very small. As a result, S/L agencies were not 

asked to review this information and provide corrections because the inconsistencies did not involve 

significant emission sources. The replacement actions above were appropriate for an inventory 

used for regional air quality modeling. 

1.4.2 Updating of PM Factor Ratios 

The augmentation steps require the use of ratios developed from available emissions and particle 

size distribution data. These ratios are needed when only one PM term is available, and two or more 

terms need to be augmented. Examples of how we used the PM ratios are shown below: 

PM-FIL × RatioCON/FIL = PM-CON 

PM-PRI × RatioCON/PRI = PM-CON 

PM-CON × RatioFIL/CON = PM-FIL 

PM-CON × RatioPRI/CON = PM-PRI 

A table of PM compound ratios was developed utilizing the table developed for the MANE-VU 2002 

inventory (MARAMA, 2006). This table is keyed by SCC, primary control device, and secondary 

control device and provides the ratios listed in the above equations. We updated this table to 

include SCC, primary control device, and secondary control device codes found in the 2007 SEMAP 

inventory that were not contained in the 2002 MANE-VU inventory. 

1.4.3 PM Emission Calculations 

The gap-filling requires that the data be analyzed and separated into cases. The cases determine 

which math steps and ratios of PM terms will be applied. Exhibit 4 shows the various cases and the 

augmentation method that was applied. 

Exhibit 4 – PM Cases and Required Steps to Augment PM Emissions 

Case PM Reported Augmentation Methodology 

1 PM25-PRI PM-CON = PM25-PRI * CON_P25 ratio 

PM25-FIL = PM25-PRI - PM-CON 

PM10-FIL = PM25-FIL * F10_F25 ratio 

PM10-PRI = PM-CON + PM10-FIL 

2 PM10-PRI PM-CON = PM10-PRI * CON_P10 ratio 

PM10-FIL = PM10-PRI - PM-CON 

PM25-FIL = PM10-FIL / F10_F25 ratio 

PM25-PRI = PM-CON + PM25-FIL 

3 PM25-PRI 

PM10-PRI 

PM-CON = PM10-PRI * CON_P10 ratio 

PM10-FIL = PM10-PRI - PM-CON 

PM25-FIL = PM25-PRI - PM-CON 

4 PM10-FIL PM-CON = PM-CON * CON_F10 ratio 

PM10-PRI = PM-CON + PM10-FIL 

PM25-FIL = PM10-FIL / F10_F25 ratio 

PM25-PRI = PM-CON + PM25-FIL 

5 PM10-FIL 

PM25-FIL 

PM-CON = PM10-FIL * CON_F10 ratio 

PM10-PRI = PM-CON + PM10-FIL 

PM25-PRI = PM-CON + PM25-FIL 

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Case PM Reported Augmentation Methodology 

6 PM10-FIL 

PM10-PRI 

PM-CON = PM10-PRI - PM10-FIL 

PM25-FIL = PM10-FIL * F25_F10 ratio 

PM25-PRI = PM-CON + PM25-FIL 

7 PM25-FIL PM-CON = PM25-FIL * CON_F25 ratio 

PM10-FIL = PM25-FIL * F10-F25 ratio 

PM10-PRI = PM-CON + PM10-FIL 

PM25-PRI = PM-CON + PM25-FIL 

8 PM10-FIL 

PM10-PRI 

PM25-FIL 

PM25-PRI 

PM-CON = PM25-PRI - PM25-FIL 

9 PM-PRI PM-CON = PM-PRI * CON_PRI ratio 

PM-FIL = PM-PRI - PM-CON 

PM10-FIL = PM-FIL * F10_FIL ratio 

PM10-PRI = PM-CON + PM10-FIL 

PM25-FIL = PM10-FIL / F10_F25 ratio 

PM25-PRI = PM-CON + PM25-FIL 

10 PM25-FIL 

PM25-PRI 

PMCON = PM25-PRI - PM25-FIL 

PM10-FIL = PM25-FIL * F10_F25 ratio 

PM10-PRI = PM-CON + PM10-FIL 

11 PM-CON 

PM10-FIL 

PM25-FIL 

PM10-PRI = PM-CON + PM10-FIL 

PM25-PRI = PM-CON + PM25-FIL 

12 PM-CON PM10-FIL = PM-CON * F10_CON ratio 

PM25-FIL = PM10-FIL * F25_F10 ratio 

PM10-PRI = PM-CON + PM10-FIL 

PM25-PRI = PM-CON + PM25-FIL 

13 PM-CON 

PM10-FIL 

PM10-PRI 

PM25-FIL = PM10-FIL / F10_F25 ratio 

PM25-PRI = PMCON + PM25-FIL 

14 PM-CON 

PM10-FIL 

PM10-PRI 

PM25-FIL 

PM25-PRI 

None required; all PM compounds present 

15 PM-CON 

PM-FIL 

PM10-FIL = PM-CON / CON_F10 ratio 

PM25-FIL = PM10-FIL / F10_F25 ratio 

PM10-PRI = PM-CON + PM10-FIL 

PM25-PRI = PM-CON + PM25-FIL 

16 PM-CON 

PM10-PRI 

PM25-PRI 

PM10-FIL = PM10-PRI - PM-CON 

PM25-FIL = PM25-PRI - PM-CON 

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Case PM Reported Augmentation Methodology 

17 PM-FIL PM10-FIL = PM-FIL * F10_FIL ratio 

PM_CON = PM10-FIL * CON_F10 ratio 

PM25-FIL = PM10-FIL / F10_F25 ratio 

PM10-PRI = PM-CON + PM10-FIL 

PM25-PRI = PM-CON + PM25-FIL 

After completing the calculations, the data was QA checked to ensure that the calculations resulted 

in consistent values for the PM complement. On a few occasions, the mix of ratio value and the 

pollutants and values provided by the S/L agency resulted in negative values when FIL was backcalculated. In this case the negative FIL value was set to zero and the PRI value was readjusted. In 

a few cases the appropriate combination of ratios, SCC, and control efficiencies were not available 

to calculate the PM10-PRI and PM25-PRI values. In these cases, PM10-PRI and PM25-PRI were 

set equal. 

1.4.4 PM Emission Results 

Exhibit 5 compares the original PM emission estimates from the S/L submittals and the 2007 

SEMAP emissions estimates calculated using the above methodology. This table is intended to 

show that we took whatever States provided in the way of PM and filled in gaps to add in PM-CON 

where emissions were missing in order to calculate PM10-PRI and PM2.5 -PRI for all processes to get 

a complete set of particulate data. A spreadsheet (PM State SCC Sums.xls) shows the results 

obtained from the PM augmentation process by State and SCC. 

Exhibit 5 Comparison of PM Emissions from the Initial S/L Data Submittals and Version 1.1 of 

the SEMAP 2007 Point Source Inventory 

State Database PM-CON PM10-PRI PM10-FIL PM25-PRI PM25-FIL 

AL S/L Data 0 0 57,285 0 29,173 

 SEMAP 9,511 87,779 78,268 62,878 53,367 

FL S/L Data 0 0 26,234 0 0 

 SEMAP 10,218 36,707 26,489 29,033 18,785 

GA S/L Data 0 20,066 0 9,426 0 

 SEMAP 668 27,359 26,691 19,251 18,858 

KY S/L Data 0 24,699 206 2,019 196 

 SEMAP 325 24,986 24,662 15,435 15,110 

MS S/L Data 883 18,871 5,986 11,071 1,739 

 SEMAP 1,784 18,900 17,116 11,289 9,505 

NC S/L Data 18 46,852 28 30,055 16 

 SEMAP 2,982 46,909 43,926 36,881 33,899 

SC1 S/L Data 81 30,602 910 21,488 416 

 SEMAP 909 31,904 30,995 24,235 23,326 

TN1 S/L Data 11,177 26,708 12,826 19,734 7,048 

 SEMAP 11,270 30,240 18,971 23,742 12,491 

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State Database PM-CON PM10-PRI PM10-FIL PM25-PRI PM25-FIL 

VA2 S/L Data 4,783 19,203 14,419 14,888 10,105 

 SEMAP 4,783 19,203 14,419 14,875 10,092 

WV S/L Data 129 6,444 7,507 4,462 3,398 

 SEMAP 3,904 13,736 9,833 9,173 5,269 

1) Includes PM records from EPA’s 2005-based modeling inventory, which have already been 

augmented by EPA 

2) Virginia’s PM augmentation was previously performed using an identical augmentation process 

during the development of the 2007 inventory for the Northeast/Mid-Atlantic States

1.5 EMISSION RELEASE POINT QA CHECKS 

Stack parameters are an important component of an emission inventory used for regional air quality 

modeling. Careful QA was required to ensure that the point source emissions were properly located 

both horizontally and vertically on the modeling grid. This section describes the procedures used to 

quality assure, augment, and where necessary, revise, stack parameters using standardized 

procedures to identify and correct stack data errors. These procedures were implemented within the 

NIF file itself, and are based on the QA procedures built into SMOKE that are designed to catch 

missing or out-of-range stack parameters. 

1.5.1 QA Checks and Gap-Filling for Location Coordinates 

The emission release (ER) point record is used to report the location and relevant physical attributes 

of the emission release point. Location coordinates must be reported to identify where emissions are 

released to the ambient air, via a stack or non-stack (e.g., fugitive release). If a non-stack, or fugitive 

release, coordinates may be reported for the general location of the emission release point. In the 

ER record, location data may be reported as x and y coordinates from either of two coordinate 

systems - Latitude / Longitude (LATLON), or Universal TransMercator (UTM). X and Y coordinates 

reported as Latitude and Longitude must be reported in the decimal degree format specified. X and 

Y coordinates reported as UTM Easting and UTM Northing, must be reported in kilometers. In order 

to comply with the EPA data standard for Latitude/Longitude, any UTM data received in the 

SESARM files was processed by the AMEC Team and converted to, and stored as Latitude 

Measure and Longitude Measure in decimal degrees. 

All conversions of UTM to LATLON were conducting use a spreadsheet developed by the University 

of Wisconsin - Green Bay (Dutch 2005). This spreadsheet tool allowed for batch conversion of UTM 

data to decimal degree format and was configured for WGS 84 DATUM. While errors using this 

spreadsheet are typically a few meters, rarely 10 or more, the accuracy of the conversion is limited 

to the accuracy of the initial UTM data. A degree latitude/longitude is about 111,000 meters. Thus, to 

achieve roughly one-meter accuracy you need coordinates accurate to five decimal places. Four 

places will give you 10 meters accuracy and three will give you 100 meter accuracy. This accuracy 

could not be improved with the originally provided UTM coordinates, so all conversions should be 

checked for reasonableness. 

Once all conversions were made to LATLON decimal degrees (also the requirement of the SMOKE 

emissions processing system), reasonableness checks were conducted on each release point 

relative to county centroids and min/max coordinates associated with the FIPS codes assigned to 

each stack. If a stack was found to exist outside of the western-, eastern-, northern- or southernmost boundary of the county (based on SMOKE’s county lat/lon file), the point was flagged for 

additional review. These flagged sources were then mapped with GIS software to determine their 

placement relative to the FIPS County associated with the stack. If a source was found to be 

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outside of the county boundaries, it was further identified and reported for review by the data 

provider. 

For version 1.10a of the inventory additional GIS checks were made by personnel from GA EPD to 

evaluate any remaining inconsistencies between reported latitude and longitudes and county 

boundaries. Corrections were made to several emission release points. The emission release 

points corrected are found in Appendix A. 

1.5.2 QA Checks and Gap-Filling for Emission Release Parameters 

In preparing emissions for grid modeling, valid parameters for the physical characteristics of each 

release point (stack height, diameter, temperature, velocity, and flow) are necessary to correctly 

place facility release points and associated emissions into vertical layers for proper air quality 

modeling. Gaussian dispersion models need stack parameters to characterize the plume, which is 

needed to estimate proper concentrations from these models. The first step of our quality assurance 

involves review of the Emission Release Point Type. Using this type code, we used a routine to 

assess the validity of the stack parameters, to replace values if necessary, and to fill-in missing data 

points. This methodology is virtually identical to the EPA methodology used for the 2002 NEI (EPA 

2006a). 

We employed a routine that compared each emission release point parameter to a minimum and 

maximum range of values and when that parameter was missing or was found to exist outside of 

that range, we augmented the parameter. We also checked non-fugitive stack parameters for 

internal consistency between: 

 stack height and diameter, and 

 stack diameter, exit gas velocity, and exit gas flow rate. 

When internal consistency was not met, we provided replacement values for the parameters. 

The following steps summarize the process of finding and replacing missing, out-of-range, or 

internally inconsistent stack parameters. 

Step 1: For fugitive emission release points, replace stack parameters 

For fugitive emission release points, we first compared the existing height against the following 

range thought to be representative of the minimum and maximum values allowable for most fugitive 

emission release points. 

 Fugitive Release Height: 0.1 to 100 ft 

If the height was valid, we kept the height and replaced all other stack parameters with the defaulted 

values listed below. If the height was invalid, we replaced all stack parameters with the defaulted 

values. 

 Stack Height: 10 ft 

 Stack Temperature: 72 o

F 

 Stack Diameter: 0.003ft 

 Stack Velocity: 0.0003 ft/sec 

 Stack Flow: 0 cu ft/sec 

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Step 2: For non-fugitive emission release points, find out-of-range or missing stack parameters 

For non-fugitive emission release points, we first compared existing stack parameters against a set 

of the following ranges thought to be representative of the minimum and maximum values allowable 

for most emission release points. 

 Stack Height: 0.1 to 1000 ft 

 Stack Temperature: 50 to 1,800 o

F 

 Stack Diameter: 0.1 to 50 ft 

 Stack Velocity: 0.1 to 560 ft/sec 

 Stack Flow: 0.001 to 1,100,000 ft3

/sec 

First we identified missing or out-of range parameters. Then we evaluated the source category to 

determine if out-of-range parameters were plausible. If any parameter was missing or out-of range, 

the parameter was replaced using the procedures described in Step 4. If all parameters were found 

to exist within the bounds of the emission release point ranges, we proceeded to Step 3. 

Step 3: For non-fugitive emission release points, find inconsistencies in stack parameters 

We determined any inconsistencies in stack parameters by conducting the following two steps. 

A. For stack diameter, we compared the stack diameter to the stack height. For nonfugitive 

emission release points, the stack height may not be less than stack diameter. 

B. We determined the internal consistency between diameter, velocity and flow rate using the 

following equation. 

Stack Flow [cu ft/sec] = (Π [Pi] * (Stack Diameter [ft] / 2) ^ 2) * Stack Velocity [ft/sec] 

If the calculated flow and the reported flow are within 10 % of one another, then internal consistency 

was assumed to be valid. If all parameters were found to exist within the bounds of the emission 

release point ranges in Step 2, and the consistency checks (A) and (B) in Step 3 were satisfied, no 

additional steps were taken. If any parameter was missing or out-of range, or if the parameters failed 

the internal consistency tests, the parameter was replaced using the procedures described in Step 4. 

Step 4: Replace stack parameters for non-fugitive emission release points 

The first step in replacing stack parameters was to determine if there are problems with stack height 

or diameter. Because stack height and diameter are the physical parameters that are most easily 

measured or estimated, when there are problems with these parameters, then the entire set of stack 

parameters are deemed questionable. If either height or diameter were missing or out-of range, or if 

the stack diameter was greater than stack height, then all five parameters were defaulted using 

national default sets of physical parameter data contained in the 2002 NEI Stack Parameter Default 

file (EPA 2006b). No additional steps were taken once all five parameters were defaulted. 

If stack height and diameter did not need replacement, then velocity and flow rate were evaluated 

next. If velocity and flow rate were not internally consistent, we conducted QA on the flow rate to 

determine if it was reported in cubic feet per minute rather than cubic feet per second as required in 

the reporting to EPA. 

We corrected flow rates reported in cubic feet per minute to cubic feet per second and then 

evaluated the flow rate and velocity for internal consistency. If the internal consistency was not met 

for velocity, flow rate, and diameter, Exhibit 6 provides instructions on how we replaced missing, outWV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 871
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of-range values, or internally inconsistent values for velocity and flow rate based on different 

reported scenarios. Velocity and flow rate were augmented either by calculation or the use of 

national defaults. 

Finally, in cases where all five parameters were not defaulted, and velocity and flow rate were 

evaluated and replaced if necessary, temperature was evaluated. If temperature was missing or 

out-of-range, then the temperature was defaulted using national default sets of physical parameter 

data in the order presented below. 

1. SCC match 

2. Facility level SIC Code match 

3. National default for release points, if no SCC or SIC Code match is possible 

Stack parameter QA reports were sent to all data providers. The report contained all of the 

emissions release point records submitted and identifies which parameters were defaulted as a 

result of our QA. S/L agencies were asked to review the defaulted records and revise the records if 

they do not agree with the defaulted values. 

Exhibit 6 - Stack Parameter Data Replacement Matrix (X = Data value present) 

Diameter Velocity Flow Rate Action 

X X X 1. Check that velocity is within range. 

A. If velocity is within range and flow rate does 

not meet internal consistency for diameter, 

velocity and flow rate, then: 

> Calculate flow rate using internal 

consistency formula. 

B. If velocity is not within range, then: 

> Calculate velocity using internal 

consistency formula. 

> Check that calculated velocity is within 

range. If so, then default to calculated 

velocity. 

> If calculated velocity is not within range, 

then default all 5 parameters using national 

default set. 

X - X 1. Calculate velocity using internal consistency 

formula. 

2. Check that calculated velocity is within range. 

A. If calculated velocity is not within range, then: 

> Default all 5 parameters using national 

default sets. 

X X - 1. Check that velocity is within range. 

A. If velocity is within range, then: 

> Calculate flow rate using internal 

consistency formula. 

B. If velocity is not within range, then: 

> Default all 5 parameters using national 

default sets. 

X - - 1. Default velocity using national default sets. 

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Diameter Velocity Flow Rate Action 

2. Calculate flow rate using internal consistency 

formula.

- X X 1. Default all 5 parameters using national default 

sets.

1.6 STATE REVIEW OF INITIAL VERSION 

This section describes changes made to the 2007 SEMAP point source inventory based on S/L 

agency review and comment. The following changes were incorporated to create Version 1.3 of the 

point source inventory. 

1.6.1 Alabama 

A large increase in VOC and PM emissions from 2002 to 2007 was identified during the review of 

Alabama’s initial submittal. Alabama investigated this problem and identified a serious problem in 

their data conversion process. New EM and CE tables were provided in May 2010 to correct this 

problem. The new submittals were subjected to the same QA and PM augmentation processes 

described in previous sections. 

Alabama reviewed the geographic coordinates for the 34 stacks that were flagged as being outside 

of the appropriate county boundaries. No changes were needed – the sources were either located 

off-shore (outside the county boundary) or very close to the edge of the county boundary. 

In response to the QA checks of stack parameters, Alabama changed the emission release type to 

“01” (fugitive sources) for 98 and accepted the default fugitive emission release characteristics. For 

another 71 stacks, Alabama changed the emission release type to “02” (vertical release sources) 

and provided corrected stack parameters. Alabama also provided corrections for a number of 

additional stacks, either by accepting the recommended defaults or providing corrected data. 

1.6.2 Alabama – Jefferson County 

Stack parameter changes were made for fugitive emission release points that were recommended 

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report. 

1.6.3 Florida 

Stack parameter changes were made for fugitive emission release points that were recommended 

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report. 

Florida updated the CAMD-to-NIF crosswalk table to link the CAMD and NIF identifiers. Florida 

updated cases where: 

 the facility/emission unit may likely have been reported as a different facility (two CAMD 

ORIS facilities were combined in Florida’s NIF SI table); 

 the EU did not operate in 2007, which is why it was not included in Florida’s NIF database; or 

 typographical errors caused a mismatch between CAMD and NIF. 

AMEC made the above updates and now all CAMD units have a match in Florida’s NIF database. 

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1.6.4 Georgia 

Georgia specified that 2008 emissions data should be backcasted to 2007 or and 2005 emissions 

data should be projected to 2007. The backcasting of 2008 emissions and projecting of 2005 

emissions was performed in the following manner: 

 Facilities with 2007 emissions do not get changed; 

 For facilities with 2005 and 2008 emissions (but no 2007 emissions), 2007 emissions were 

estimated based on a linear interpolation between facility level 2005 and 2008 emissions on 

a pollutant-by-pollutant basis to calculate facility level 2007 emissions. A scaling factor was 

then calculated as the ratio of reported 2008 emissions to interpolated 2007 emissions, 

which was used to create to scale back 2008 reported emissions to 2007 at the emission 

process level. 

 For facilities with only 2008 data (no 2007 or 2005 data available), we used the SIC growth 

factors from the VISTAS Best&Final inventory to backcast 2008 reported emissions to 2007. 

The VISTAS SIC growth factors were used to calculate a scaling factor which was used to 

scale back 2008 reported emissions to 2007 at the emission process level. 

 For facilities with only 2005 data (no 2007 or 2008 data available), we used the SIC growth 

factors from the VISTAS Best&Final inventory to project 2005 reported emissions to 2007. 

The VISTAS SIC growth factors were used to calculate a scaling factor which was used to 

project 2005 reported emissions to 2007 at the emission process level. 

After the above backcasting and projecting was performed, additional adjustments were made for 

facilities where only 2005 data were available and the facility did not operate in 2007 or operated for 

only part of 2007. Facilities that did not operate in 2007 were removed from the NIF files. For 

facilities that operated for part of 2007, the 2005 emissions were approximated for 2007 by multiply 

the 2005 emissions by a scaling factor of the number of days the facility operated in 2007 divided 

365 days of full year operation. Also, the end date in the NIF EM and PE tables were changed to 

reflect the actual date that the facility ceased operation. These facilities were: 

FIPS PLANTID FACILITY NAME DATE 

SHUTDOWN 

SCALING 

FACTOR 

13159 15900011 Georgia-Pacific Corp Panelboard 15-Aug-07 0.62 

13045 04500008 Southwire Co, Copper Division 7-Mar-07 0.18 

13121 12100364 Ford Motor Co Atlanta Assembly 1-Dec-07 0.92 

13121 12100004 General Shale Brick 28-Mar-07 0.24 

13175 17500047 Victor Forstmann, Inc. 1-Apr-07 0.25 

13081 08100019 Lasco Bathware 6-Nov-07 0.85 

13089 08900031 Siemens Energy & Auto 1-Sep-06 0.00 

13241 24100001 Rabun Apparel, Inc. Not operated in 

2007 0.00 

13261 26100005 Textron Automotive Company 1-Feb-07 0.08 

The following facilities reported emissions data to CAMD but were not in Georgia’s NIF submittal: 

FIPSST FIPSCNTY PLANTID ORISID FACILITY NAME 

13 147 14700021 70454 HARTWELL ENERGY FACILITY 

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FIPSST FIPSCNTY PLANTID ORISID FACILITY NAME 

13 149 14900004 55061 TENASKA GEORGIA 

13 149 14900005 55141 HEARD COUNTY POWER LLC 

13 149 14900006 7917 CHATTAHOOCHEE ENERGY FACILITY 

13 149 14900007 7946 WANSLEY 

13 153 15300040 7348 GEORGIA POWER COMPANY, ROBINS CT 

13 153 15300042 55040 MID GEORGIA COGEN 

13 157 15700034 7765 GEORGIA POWER COMPANY, DAHLBERG 

13 205 20500043 7768 SOWEGA POWER LLC 

13 205 20500044 55304 BACONTON POWER 

13 207 20700030 7829 SMARR ENERGY CENTER 

13 233 23300042 7813 SEWELL CREEK ENERGY 

13 263 26300013 7916 TALBOT COUNTY ENERGY 

13 293 29300027 55267 WEST GEORGIA GENERATING CO 

13 297 29700040 7764 MPC GENERATING 

13 297 29700041 55244 DOYLE GENERATING FACILITY 

13 297 29700042 55128 WALTON COUNTY POWER LLC 

13 303 30300039 55332 WASHINGTON COUNTY 

13 303 30300040 55672 DUKE ENERGY SANDERSVILLE LLC 

AMEC added these facilities and their associated emission units to the NIF tables. All of the units 

are gas-fired turbines. AMEC calculated 2007 emissions for these units in the following manner: 

 NOx – used the CAMD reported 2007 annual NOx emissions 

 SO 

2 – used the CAMD reported 2007 annual SO 2 emissions 

 CO – calculated annual CO emissions using the CAMD reported 2007 annual heat input 

(mmBtu/year) and the AP-42 emission factor of 0.03 lbs/mmBtu 

 PM10-PRI – calculated annual PM10-PRI emissions using the CAMD reported 2007 annual 

heat input (mmBtu/year) and the AP-42 emission factor of 0.0066 lbs/mmBtu 

 PM25-PRI – calculated annual PM25-PRI emissions using the CAMD reported 2007 annual 

heat input (mmBtu/year) and the AP-42 emission factor of 0.0066 lbs/mmBtu 

 VOC – calculated annual VOC emissions using the CAMD reported 2007 annual heat input 

(mmBtu/year) and the AP-42 emission factor of 0.0021 lbs/mmBtu 

These calculations were reviewed and approved by Georgia. 

Stack parameter changes were made for fugitive emission release points that were recommended 

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report. 

1.6.5 Kentucky 

Kentucky compared facility-level emissions in their State database to the emissions in the 2007 

SEMAP inventory. They identified discrepancies at two facilities: (1) NRE Acquisition Co LLC 

(211450019), which appeared to be undercounted by 25.4955 tons of NOx in the draft 2007 SEMAP 

inventory and (2) Chesapeake Applachia LLC (2119500252), which appeared to be undercounted by 

about 76.7157 tons VOC and 6.7362 tons of CO in the SEMAP inventory. These discrepancies 

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were identified and resolved, so that now the Kentucky database and the SEMAP 2007 are in 

agreement. 

Kentucky provided updated latitude and longitude data for 677 stacks that were identified as being 

located outside of the county boundaries. Stack parameter changes for the stack diameter, flow rate, 

and velocity were made for fugitive emission release points that were recommended for change 

based on the QA checks and gap filling process described in Section 1.5.2 of this report. We 

retained Kentucky’s values for stack height and exit gas temperature. 

1.6.6 Kentucky – Jefferson County 

Jefferson County updated the coordinates of emission release points for large and medium-sized 

point sources. Large sources are those with Title V operating permits. Medium-sized sources are 

those with synthetic minor operating permits. Most of these emission release points will match those 

reported in the 2007 National Emissions Inventory (NEI). Many of these coordinates were digitized 

using a geographic information system (GIS) in early April 2010. Others (those showing fewer 

significant digits in the UTM coordinates) were obtained by other means, usually by interpolation on 

USGS 1:24 000 scale paper maps. Generally the ones that were corrected were those that were 

found to be the most inaccurate as seen in the GIS. The 2007 SEMAP inventory was updated with 

this new location information. 

1.6.7 Mississippi 

In preparing the initial version of the 2007 SEMAP point source inventory, AMEC added facilities 

from EPA’s 2005 NEI that were not included in Mississippi’s 2007 submittal. Mississippi reviewed 

the facilities that were added and indicated that much of the data for the 2005 NEI facilities was for 

very small sources, contained dated emissions data, had some double-counting of sources, 

contained data for airports (which are included in the SEMAP nonroad inventory) and did not reliably 

represent emissions in 2007. As a result, Mississippi decided to remove most of the facilities added 

from the 2005 NEI from the 2007 SEMAP inventory. The emissions from these sources will be 

accounted for in the inventories for area and nonroad sectors. 

Mississippi provided updated latitude and longitude data for 15 stacks that were identified as being 

located outside of the county boundaries. 

Mississippi approved the stack parameter changes for the stacks that were recommended for 

change based on the QA checks and gap filling process described in Section 1.5.2 of this report. 

Most of these changes affected fugitive emission sources with a emission release point of “9999”. 

These stacks were updated to change the emission release type to “01 – fugitive” and to use the 

default fugitive emission release stack parameters described in Section 1.5.2. 

Mississippi reviewed the CAMD-to-NIF crosswalk and updated several linkages to correctly map 

CAMD identifiers to NIF. Three facilities (BTEC New Albany ORIS 13213, Natchez ORIS 2052, and 

AP Holdings Southhaven ORIS 55219) are currently shut down and did not operate in 2007. 

Choctaw Gas generation (ORIS 55634), and RRI Energy (ORIS 55706), are newer and were not 

completely represented in Mississippi’s original submittal. Mississippi provided the necessary stack 

data for modeling for both of these facilities. 

1.6.8 North Carolina 

A large increase in VOC emissions from 2002 to 2007 was identified during the review of North 

Carolina’s initial submittal. North Carolina investigated this problem and identified a serious problem 

in their data conversion process. A new spreadsheet table was provided in May 2010 to correct this 

problem. AMEC converted the spreadsheet file a NIF database. The new submittals were 

subjected to the same QA and PM augmentation processes described in previous sections. 

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North Carolina reviewed the geographic coordinates for the stacks that were flagged as being 

outside of the appropriate county boundaries. The new submittal mentioned in the previous 

paragraph contained corrections to the flagged latitude and longitude issues. 

NC has reviewed the recommended stack replacement parameters and agreed to accept all of the 

recommendations based on the SCC code. 

In addition, Duke Energy provided additional corrections for stack parameters for 2007. For the 

Marshall Steam Plant, new FGD stacks were installed in May 2007 (combined stack for Units 1&2), 

March 2007 (Unit 3) and May 2006 (Unit 4). For other plants (Belews Creek, Cliffside, and G.G. 

Allen), new stacks will become operational after 2007. 

1.6.9 North Carolina – Buncombe County 

Buncombe County approved the stack parameter changes for the stacks that were recommended 

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report. 

In a few cases, Buncombe County updated the original stack parameters for certain stacks and 

requested that the updated stack data be used. 

The geographic coordinates were inadvertently truncated (not rounded) to 1/100th of a degree during 

the compilation of the initial SEMAP inventory. This problem was corrected in Version 1.3. 

Buncombe County compared a sampling of the 2007 SEMAP inventory to what they had submitted 

and found them to be in agreement. 

1.6.10 North Carolina – Forsyth County 

Forsyth County reviewed the data in the SEMAP 2007 inventory and emissions data for the more 

significant processes, i.e. the highest emitting sources. The emissions for all pollutants except PM 

for the processes they reviewed matched their data. The PM emissions did not match the data they 

provided data in a few cases. The reason for this difference is due to correcting inconsistencies in 

the reported PM data during the PM augmentation process. For example, the Corn Products 

International facility (ID 3706700732, emission point ES062C, process ID 62C-W had reported PMCON emissions of 11.58 tons but PM10-PRI emissions of only 3.41 tons. Since PM-CON cannot be 

greater than PM10-PRI, the PM10-PRI value was replaced during the PM augmentation process. 

Forsyth County provided the mission facility name (Wake Forest University) for Facility ID 

3706700003. 

The geographic coordinates were incorrect for many facilities. These have been replaced for all 

facilities in Forsyth County. 

1.6.11 North Carolina – Mecklenburg County 

Mecklenburg County approved the stack parameter changes for the stacks that were recommended 

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report. 

1.6.12 South Carolina 

In preparing the initial version of the 2007 SEMAP point source inventory, AMEC added facilities 

from EPA’s 2005 NEI that were not included in South Carolina’s 2007 submittal. South Carolina 

reviewed the facilities that were added and indicated that much of the data for the 2005 NEI facilities 

was for very small sources, contained dated emissions data, had some double-counting of sources, 

contained data for airports (which are included in the SEMAP nonroad inventory) and did not reliably 

represent emissions in 2007. As a result, South Carolina decided to remove many of the facilities 

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added from the 2005 NEI from the 2007 SEMAP inventory because they were either minor sources, 

out of business, or airports. The emissions from these sources will be accounted for in the 

inventories for area and nonroad sectors. 

South Carolina provided updated latitude and longitude data for 14 stacks that were identified as 

being located outside of the county boundaries. Five of these stacks were associated with facilities 

from the 2005 NEI which were removed from the SEMAP inventory. For the remaining stacks that 

were flagged, the facility level latitude and longitude were used to more accurately locate the stack. 

South Carolina approved the stack parameter changes for the stacks that were recommended for 

change based on the QA checks and gap filling process described in Section 1.5.2 of this report. In 

several cases, South Carolina updated the original stack parameters for certain stacks and 

requested that the updated stack data be used. 

South Carolina reviewed the PM augmentation of PM10-PRI and PM2.5-PRI and generally agreed 

with the small increases in the PM10-PRI and PM2.5-PRI emissions resulting from the augmentation 

process. South Carolina expressed a concern about the increases that were made to the certain 

fuel burning SCCs (20100101, 20100201, and 20200201). The reason for the small PM10-PRI and 

PM25-PRI increase for these SCCs was that a few facilities had reported PM10-FIL and PM25-FIL, 

not PM10-PRI and PM25-PRI. Since the PM10-FIL and PM25-FIL were reported, the augmentation 

process calculated a PM-CON value and added it to the PM10-FIL and PM25-FIL values to get the 

revised PM10-PRI and PM25-PRI values. 

South Carolina reviewed the CAMD-to-NIF crosswalk and updated several linkages to correctly map 

CAMD identifiers to NIF. South Carolina also compared the CAMD-reported NOx and SO 

2

emissions to the NIF-reported emissions, and updated the NIF emissions for several coal-fired 

plants with the CAMD emissions after consulting with the affected facilities. 

1.6.13 Tennessee 

In preparing the initial version of the 2007 SEMAP point source inventory, AMEC added facilities 

from EPA’s 2005 NEI that were not included in Tennessee’s 2007 submittal. Tennessee reviewed 

the facilities that were added and indicated that much of the data for the 2005 NEI facilities was for 

very small sources, contained dated emissions data, had some double-counting of sources, 

contained data for airports (which are included in the SEMAP nonroad inventory) and did not reliably 

represent emissions in 2007. As a result, Tennessee decided to remove most of the facilities added 

from the 2005 NEI from the 2007 SEMAP inventory. The emissions from these sources will be 

accounted for in the inventories for area and nonroad sectors. 

Tennessee provided updated 2007 emissions data for 16 facilities that were not in their original 

submittal: 

FIPS Facility 

Identifier Facility Name 

47149 0155 NISSAN NORTH AMERICA, INC. 

47027 0022 HONEST ABE LOG HOMES, INC., ETC. 

47029 0020 SONOCO PRODUCTS COMPANY 

47031 0010 ARNOLD ENGINEERING DEVELOPMENT CENTER 

47031 0067 BATESVILLE MANUFACTURING, INC. 

47031 0113 M-TEK, INC. 

47031 0123 CREATEC CORPORATION 

47047 0080 STABILT AMERICA, INC 

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FIPS Facility 

Identifier Facility Name 

47053 0119 Kongsberg Automotive 

47071 0074 PRAXIS INDUSTRIES 

47077 0060 VOLVO PENTA MARINE PRODUCTS, L.C. 

47113 0020 ARMSTRONG HARDWOOD FLOORING 

47125 0092 NYRSTAR CLARKSVILLE, INC 

47151 0002 HARTCO FLOORING COMPANY 

47151 0051 ARMSTRONG HARDWOOD FLOORING 

47167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION 

Tennessee provided updated latitude and longitude data for 25 stacks that were identified as being 

located outside of the county boundaries. Tennessee also provided changes to the stack 

parameters for 29 stacks. Stack parameter changes were made for fugitive emission release points 

that were recommended for change based on the QA checks and gap filling process described in 

Section 1.5.2 of this report. 

1.6.14 Tennessee – Davidson County 

Davidson County reviewed the draft point source emission inventory and approved the emissions 

contained in it. 

Davidson County approved the stack parameter changes for 723 stacks that were recommended for 

change based on the QA checks and gap filling process described in Section 1.5.2 of this report. In 

several cases, Davidson County provided updated stack parameters for selected stacks. 

1.6.15 Tennessee – Hamilton County 

Stack parameter changes were made for fugitive emission release points that were recommended 

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report. 

Hamilton County provided updated stack latitude and longitude for three facilities that were identified 

as being located outside of the county boundaries. 

1.6.16 Tennessee – Knox County 

Stack parameter changes were made for fugitive emission release points that were recommended 

for change based on the QA checks and gap filling process described in Section 1.5.2 of this report. 

Knox County provided updated stack latitude and longitude for one facility that was identified as 

being located outside of the county boundaries. 

1.6.17 Tennessee – Shelby County 

Shelby County approved the stack parameter changes for 765 stacks that were recommended for 

change based on the QA checks and gap filling process described in Section 1.5.2 of this report. In 

a few cases, Shelby County provided updated stack parameters for selected stacks. 

Hamilton County provided updated stack latitude and longitude for facilities that were flagged as 

being located outside of the county boundaries. 

1.6.18 Virginia 

Virginia provided updated latitude and longitude data for 115 stacks that were identified as being 

located outside of the county boundaries. 

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Virginia approved the stack parameter changes for 540 stacks that were recommended for change 

based on the QA checks and gap filling process described in Section 1.5.2 of this report. The only 

exception was for the Jewel Coke Company (ID 51027-00004, stacks 1 and 3), where Virginia 

requested that the original stack exhaust gas temperatures of 1500 degrees Fahrenheit be retained. 

As part of the development of a 2007 inventory for the Mid-Atlantic and Northeast States directed by 

MARAMA, Virginia developed and approved the 2007 CAMD-to-NIF crosswalk and the 2007 

emission values for all sources. 

1.6.19 West Virginia 

West Virginia approved the stack parameter changes for 540 stacks that were recommended for 

change based on the QA checks and gap filling process described in Section 1.5.2 of this report. 

There were four exceptions (Aker Plastics 5400300026, Gratech International 5403300001, 

Monongahela Power Harrison 5403300015, DuPont Belle 5403900001) where West Virginia 

requested that the original stack parameters for certain stacks be retained. 

West Virginia reviewed the locations for the seven facilities flagged as being outside of the county 

boundaries and provided updated stack latitude and longitude for these facilities. 

West Virginia reviewed the draft emission inventory and confirmed that all point source facilities are 

represented in the inventory, that the PM augmentation procedure produced reasonable results, and 

the 2007 emissions in the SEMAP inventory agreed with the data they submitted. 

West Virginia reviewed the CAMD-to-NIF crosswalk and identified the linkage between CAMD and 

NIF identifiers for the Union Carbide Corporation (5403900003) boilers B25, B26, and B27. West 

Virginia approved all other linkages between CAMD and NIF identifiers. 

1.7 STAKEHOLDER REVIEW 

S/L agencies provided access to Version 1.3 of the 2007 point source inventory and solicited input 

from various stakeholders including EPA, the regulated community, academia, environmental 

groups, and the general public. This section documents the changes made to Version 1.3 based on 

S/L agency review of stakeholder comments as well as any additional updates or corrections 

identified by the S/L agencies. 

1.7.1 Alabama 

The National Lime Association requested consideration of a modification to PM emissions data for 

one of their facilities in Alabama (Unimin Lime Corporation, Calera Plant). The request was 

reviewed by State staff and the suggested correction was justified and made. 

1.7.2 Florida 

Lakeland Electric requested that the SO 

2 and NOx emission values from the EPA CAMD submittal 

be used instead of the values reported to the State. The CAMD represent the emissions more 

accurately that the State submittal for two plants (Plant IDs 1050004 and 1050003). Florida agreed 

to make these changes. 

Tampa Electric reviewed the database and suggested several corrections. Most of the changes are 

due to the installation and operation of the SCR control devices on Big Bend units 1-4. Tampa 

Electric also evaluated filterable and condensable PM emissions for all of its major generating units 

and provided better, unit specific, emission rates for these units where available. Finally, Tampa 

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Electric provided some corrections to stack exhaust gas parameters. Florida agreed to make all of 

these changes. 

Southern Company indicated that the inventory stack data for Crist plant reflects the current 

scrubbed stack parameters, not the operating parameters in 2007. Appropriate stack parameters for 

2007 were submitted and reviewed/approved by Florida. 

1.7.3 Georgia 

Georgia reviewed the emissions values and stack parameters for the Georgia Power facilities in the 

State. Georgia provided updated PM and NH3 emissions data for all Georgia Power facilities. The 

revised PM emission values included condensable emissions which were previously missing from 

the inventory. Georgia also provided updated stack parameters for selected Georgia Power stacks. 

Georgia also identified a number of emission units where the PM2.5 emissions were greater than the 

PM10 emissions. The source of this error was investigated and identified, and revisions were made 

to correct this error. 

1.7.4 Kentucky 

Kentucky identified that the PM point source emissions originally submitted for all Kentucky counties, 

excluding Jefferson County, should be considered as filterable PM emissions. The original submittal 

contained pollutant codes (PM-PRI, PM10-PRI, PM25-PRI) that represent the sum of filterable and 

condensable emissions. These should have been reported as filterable only (PM-FIL, PM10-FIL, 

PM25-FIL). AMEC changed the pollutant codes to represent filterable emissions only, and re-ran 

the PM augmentation process described previously in Section 1.4 to add condensable emissions to 

the filterable emissions. Kentucky reviewed and approved the revised PM emissions, except for a 

few EGUs. Kentucky worked with these utilities in obtaining updated PM emissions data that 

included both filterable and condensable emissions. These changes to the EGU PM emissions are 

discussed further in Section 1.9. 

1.7.5 North Carolina 

Duke Energy indicated that the SCC for Marshall Units 1&2 were 10200202 and 10200502 

(industrial boiler, coal and oil) but should be 10100202 and 10100502 (electric generation boiler, 

coal and oil). Duke Energy requested that the SCC be changed as that will impact how boilers are 

grouped by category for various regulatory and emission projection scenarios. 

1.7.6 Tennessee 

Tennessee identified three facilities (APAC-TN Harrison Construction Division, Dyersburg 

Compressor Station, Kimberly Clark Corporation) that had duplicate entries in the emission 

inventory. AMEC investigated this issue and identified the error. The duplicate entries were 

removed. 

Tennessee also provided updated 2007 emissions data for the CalsonicKansei North America -

Lewisburg Operations facility. 

1.8 IDENTIFICATION OF EGU AND NONEGU POINT SOURCES 

States were asked to classify units in the 2007 SEMAP emissions inventory as either EGU or 

nonEGU for emission projection purposes. Emission projections for EGU point sources are being 

developed by the Eastern Regional Technical Advisory Committee (ERTAC). The emissions from 

point sources classified as nonEGUs will be projected using the methods and data developed by 

SEMAP. 

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Most, but not all, of the units that are required to report hourly emissions to EPA’s Clean Air Markets 

Division (CAMD) are considered to be EGUs. CAMD implements EPA’s rule found in Volume 40 

Part 75 of the Code of Federal Regulations (CFR), which requires an hourly accounting of emissions 

from each affected unit - i.e., sources participating in an emissions cap and trade program under the 

Acid Rain Control Program, the NOx Budget Trading Program, or the Clean Air Interstate Rule. The 

following guidance was provided to States to determine whether a unit that reports to CAMD should 

be classified as an EGU or nonEGU: 

For the ERTAC process, a unit should only be considered EGU if it meets the following criteria: 

 An EGU sells most of the power generated to the electrical grid; 

 An EGU burns mostly commercial fuel. Commercial fuel in this case means natural gas, oil, 

and coal. Wood would not be considered as commercial fuel because some states have 

them as renewable, therefore, to prevent double counting, unless it's already in the CAMD 

database, units that burn wood and other renewable sources (depending on each state's 

own definition) should not be considered as EGU. 

The following units were NOT considered as EGU for the purpose of projection emissions: 

 A unit that generates power for a facility but occasionally sells to the grid; 

 Emergency generators; 

 Distributed generation units. 

S/L agencies were provided with a list of units that report to CAMD as well as a list of units with an 

electric generating unit SCC (1-01-xxx-xx or 2-01-xxx-xx). From these lists, S/L agencies identified 

units that should be classified as EGUs and those that should be classified as nonEGUs. A few 

States also identified units with SCCs beginning with 1-01 or 2-01 that do not report to CAMD but 

which should be classified as EGUs; however, for emission projection purposes these units will be 

processed using the nonEGU projection methodology developed by SEMAP. 

AMEC added a flag to the NIF EP table to identify each unit according to the following classification 

scheme: 

 EGU-CAMD are combustion units that report hourly emissions to the CAMD database and 

have been classified as EGUs by the S/L agency; 

 EGU-nonCAMD are combustion units with SCC starting with 101 or 201 that are not 

contained in CAMD database; 

 nonEGU-CAMD are combustion units that report hourly emissions to the CAMD database 

and have been classified as nonEGUs by the S/L agency; and 

 nonEGU-nonCAMD are all other point sources not classified above. 

The above flags allow for sources to be categorized in different ways for emission projection and 

emission reporting purposes. 

1.9 FINAL S/L AGENCY QA REVIEW 

Two final QA checks were made. The first check was for S/L agencies to verify the PM emissions 

data for coal- and oil-fired units included PM condensable emissions in addition to PM filterable 

emissions. The second check was for S/L agencies to verify the location and emission values for 

certain sources via review of emission bubble plots prepared by another SEMAP contractor. This 

section documents the changes made based on these final QA checks. In addition, the 

documentation was revised to address comments provided by EPA Region 4. 

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1.9.1 Kentucky 

Kentucky coordinated the review of PM emissions with utilities in the Commonwealth and provided 

updated PM condensable emissions for the following units: 

 Duke Energy East Bend (21-015-00029) Unit 2; 

 TVA Shawnee (21-145-00006) Units 1 through 10; 

 TVA Paradise (21-177-00006) Units 1, 2, and 3; and 

 Kentucky Energy Reid/Henderson (21-233-00001) Units H1 and H2 

1.9.2 North Carolina 

Both Duke Energy and Progress Energy submitted information to confirm that the PM2.5-PRI and 

PM10-PRI emission estimates for its facilities do include both filterable and condensable values. 

1.9.3 North Carolina – Forsyth County 

In its original submittal, Forsyth County submitted a mix of 2007 and 2008 emission data. After 

further reviewing the 2007 and 2008 data, Forsyth County identified several revisions to make the 

data more representative of 2007. One facility (VP Buildings, Inc., Plant ID 00488) that shut down in 

2008 was omitted for the initial submittal and was added to the SEMAP 2007 inventory. The only 

other significant change was the addition of the coal boilers at R.J. Reynolds Tobacco Company 

(Plant ID 00039) to the SEMAP 2007 inventory that were shut down in 2008. Some additional 

relatively minor corrections were made as well. 

1.9.4 South Carolina 

South Carolina confirmed that the PM condensable emissions are included in the PM10-PRI and 

PM2.5-PRI data provided for coal- and oil-fired EGUs. 

1.9.5 Virginia 

Virginia confirmed that the PM condensable emissions are included in the PM10-PRI and PM2.5-PRI 

data provided for coal- and oil-fired EGUs. 

1.9.6 West Virginia 

After reviewing the emission density maps and emission bubble plots, West Virginia submitted 

revisions to the geographic coordinates at three facilities (54-009-00012 Impress USA, 54-021-

00001 Columbia Gas Glenville, 54-057-00008 Newpage Corporation). 

1.9.7 Changes for Version 1.9 of the Point Source Inventory 

The information presented above relates to Version 1.8 of the point source inventory. This section 

documents the changes to Version 1.8 of the SEMAP point source emission inventory to create 

Version 1.9. The purpose of these revisions were to resolve significant differences in emissions as 

reported by States in Version 1.8 and the emissions as reported in the Clean Air Market Division’s 

hourly emission database. Each change that was made is identified along with the CAMD and 

SEMAP unit identifiers: 

 CAMD_ID = Plant ORIS / Boiler ID 

 SEMAP_ID = FIPS county code / PlantID / PointID / ProcessID 

Several States have indicated that they would like to the SEMAP inventory to be updated to reflect 

the CAMD NOx and SO 

2 emissions. These changes have not yet been made pending the resolution 

of the potential adjustments to the CAMD emissions to account for overly conservative missing data 

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substitution procedures specified by EPA. Once States review the proposed revisions to the CAMD 

emissions to account for missing data substitution, States will be given the opportunity to specify the 

NOx and SO 

2 emissions to be used in the final SEMAP 2007 inventory. The choices are: 1) retain 

State-supplied emissions; 2) use CAMD emissions as provided in standard EPA data sets; or 3) use 

CAMD emissions as modified by SEMAP to account for overly conservative missing data 

substitution values. 

1.9.7.1 Alabama 

Alabama Power EC Gaston (CAMD_ID = 26 / 1; SEMAP_ID = 01117 / 0005 / 002 / 01) 

 SEMAP NOx changed from 1,292 tons to 3,271.6 tons to match CAMD emissions 

Alabama Power Gorgas (CAMD_ID = 8 / 10; SEMAP_ID = 01127 / 0001 / 008 /01 

 SEMAP NOx changed from 5,117 tons to 5,727.5 tons to match CAMD emissions 

PowerSouth Energy Coop (CAMD_ID = 56 / 2; SEMAP_ID = 01129/ 0001/ 003 / 01 

 SEMAP NOx changed from 4,559 tons to 3,717 tons to match CAMD emissions 

PowerSouth Energy Coop (CAMD_ID = 56 / 3; SEMAP_ID = 01129/ 0001/ 003 / 01 

 SEMAP NOx changed from 4,698 tons to 4,995.5 tons to match CAMD emissions 

1.9.7.2 Alabama – Jefferson County 

No issues identified. 

1.9.7.3 Florida 

TECO Big Bend (CAMD_ID = 645 / BB01; SEMAP_ID = 12057 / 0570039 / 1 / 1) 

 SEMAP NOx changed from 4,507 tons to 10,044 tons to match CAMD emissions 

SEMAP SO 

2 changed from 1,610 tons to 2,999 tons to match CAMD emissions 

TECO Big Bend (CAMD_ID = 645 / BB02; SEMAP_ID = 12057 / 0570039 / 2 / 2) 

 SEMAP NOx changed from 3,889 tons to 10,051 tons to match CAMD emissions 

SEMAP SO 

2 changed from 1,389 tons to 2,717 tons to match CAMD emissions 

TECO Big Bend (CAMD_ID = 645 / BB03; SEMAP_ID = 12057 / 0570039 / 3 / 3) 

 SEMAP NOx changed from 1,571 tons to 3,838 tons to match CAMD emissions 

SEMAP SO 

2 changed from 2,035 tons to 1,773 tons to match CAMD emissions 

TECO Big Bend (CAMD_ID = 645 / BB01; SEMAP_ID = 12057 / 0570039 / 1 / 1) 

 BoilerID in SEMAP EP Table changed from BBO4 to BB04 to match CAMD boiler ID 

 SEMAP NOx changed from 1,183 tons to 1,192 tons to match CAMD emissions 

SEMAP SO 

2 changed from 2,305 tons to 2,414 tons to match CAMD emissions 

1.9.7.4 Georgia 

No changes requested by State. 

1.9.7.5 Kentucky 

Kentucky provided revised SEMAP-to-CAMD mapping for the seven turbines at the KY Utilities 

Brown Station (CAMD_ID 1355 / #5 to #11; SEMAP_ID 21167 / 00001 /023-29). The revised 

mapping for emission point 023-29 is as follows: 

SEMAP 

Process ID 

V_1_8 

CAMD Boiler ID 

Revised V_1_9 

CAMD Boiler ID 

2 5 5 

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SEMAP 

Process ID 

V_1_8 

CAMD Boiler ID 

Revised V_1_9 

CAMD Boiler ID 

3 5 8 

4 6 8 

5 6 9 

6 7 9 

7 7 10 

8 8 10 

9 8 11 

10 9 11 

11 9 6 

12 10 6 

13 10 7 

14 11 7 

1.9.7.6 Kentucky – Jefferson County 

No issues identified. 

1.9.7.7 Mississippi 

No changes requested by State. 

1.9.7.8 North Carolina 

No changes requested by State. 

1.9.7.9 North Carolina – Buncombe County 

No issues identified for Progress Energy – Ashville. 

1.9.7.10 North Carolina – Forsyth County 

No affected facilities in the county. 

1.9.7.11 North Carolina – Mecklenburg County 

No affected facilities in the county. 

1.9.7.12 South Carolina 

SCE&G Urquhart (CAMD_ID = 3295; SEMAP_ID = 45003 / 0080-0011) 

There was an incorrect linkage between the IDs for the combustion turbines. The SEMAP 

NIF EP table was changed to correctly match CTs 4, 5, 6 between the CAMD and SEMAP 

inventories 

CAMD unit URQ4 is now linked to EU11 (previously was linked to EU04 – CT 1) 

CAMD unit URQ5 is now linked to EU12 (previously was linked to EU05 – CT 2) 

CAMD unit URQ6 is now linked to EU13 (previously was linked to EU06 – CT 3) 

Progress Energy Robinson (CAMD_ID = 3250 / 12; SEMAP_ID = 45031 / 0820-0002 / 017 / 3) 

 SEMAP NOx changed from 3.9 tons to 0 tons to match CAMD emissions 

SEMAP SO 

2 changed from 1.183 tons to 0 tons to match CAMD emissions 

Progress Energy Robinson (CAMD_ID = 3250 / 12; SEMAP_ID = 45031 / 0820-0002 / 017 / 4) 

 SEMAP NOx changed from 45 tons to 33.6 tons to match CAMD emissions 

SEMAP SO 

2 changed from 1.178 tons to 1.42 tons to match CAMD emissions 

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Progress Energy Robinson (CAMD_ID = 3250 / 13; SEMAP_ID = 45031 / 0820-0002 / 018 / 3) 

 SEMAP NOx changed from 18.3 tons to 0 tons to match CAMD emissions 

SEMAP SO 

2 changed from 0.847 tons to 0 tons to match CAMD emissions 

Progress Energy Robinson (CAMD_ID = 3250 / 13; SEMAP_ID = 45031 / 0820-0002 / 018 / 4) 

 SEMAP NOx changed from 42.4 tons to 31.31 tons to match CAMD emissions 

SEMAP SO 

2 changed from 1.108 tons to 1.05 tons to match CAMD emissions 

Santee Cooper Rainey (CAMD_ID = 7834 / CT1A; SEMAP_ID = 45007 / 0200-0144 / 001 / 1) 

 SEMAP NOx changed from 218.17 tons to 19.71 tons to match CAMD emissions 

Santee Cooper Rainey (CAMD_ID = 7834 / CT1B; SEMAP_ID = 45007 / 0200-0144 / 001 / 3) 

 SEMAP NOx changed from 218.17 tons to 19.71 tons to match CAMD emissions 

Santee Cooper Rainey (CAMD_ID = 7834 / CT2A; SEMAP_ID = 45007 / 0200-0144 / 002 / 1) 

 SEMAP NOx changed from 33.40 tons to 16.29 tons to match CAMD emissions 

Santee Cooper Rainey (CAMD_ID = 7834 / CT2B; SEMAP_ID = 45007 / 0200-0144 / 002 / 3) 

 SEMAP NOx changed from 32.40 tons to 18.21 tons to match CAMD emissions 

Santee Cooper Rainey (CAMD_ID = 7834 / CT3; SEMAP_ID = 45007 / 0200-0144 / 003 / 1) 

 SEMAP NOx changed from 0.072 tons to 4.4 tons to match CAMD emissions 

Santee Cooper Rainey (CAMD_ID = 7834 / CT4; SEMAP_ID = 45007 / 0200-0144 / 003 / 2) 

 SEMAP NOx changed from 0.060 tons to 5.13 tons to match CAMD emissions 

Santee Cooper Rainey (CAMD_ID = 7834 / CT5; SEMAP_ID = 45007 / 0200-0144 / 003 / 3) 

 SEMAP NOx changed from 0.078 tons to 4.79 tons to match CAMD emissions 

SCE&G Hagood (CAMD_ID = 3285 / HAG4; SEMAP_ID = 45019 / 0560-0029 / 001 / 2) 

 SEMAP NOx changed from 21.1 tons to 31.28 tons to match CAMD emissions 

SEMAP SO 

2 changed from 34.5 tons to 1.22 tons to match CAMD emissions 

1.9.7.13 Tennessee 

U.S. DOE, Y-12 PLANT (CAMD_ID = 880055 / 31&32&34; SEMAP_ID 47001 / 0020 / 002) 

CAMD units 31, 32, and 34 had no match in the SEMAP inventory. Tennessee provided the 

SEMAP identifiers to provide the correct linkage between CAMD and SEMAP. The NIF EP 

table was changed to provide the cross-reference between CAMD and SEMAP identifiers. 

Bowater Calhoun (CAMD_ID = 50956 / 11& 12; SEMAP_ID = 47107 / 0012 / 015) 

CAMD reports two coal-fired boilers #11 and #12. In SEMAP, there is only one emission 

point -015 – that is a coal fired boiler. To improve the match between CAMD and SEMAP, 

new records were created in the SEMAP database to disaggregate emissions from boilers 

#11 and #12 into individual records using the NOx and SO 

2 emissions data provided by 

Tennessee. 

TVA Cumberland (CAMD_ID = 3399 / A1; SEMAP_ID = 47161 / 0011 / 003 / 01) 

The SEMAP inventory reported 15.3 tons of NOx for Auxiliary boiler A1 , which was based on 

allowable emissions and is conservative. For 2007, based on a tested NOx rate of 

0.067lb/mmBtu and fuel usage of 132317 gallons of #2 oil, NOx emissions for Auxiliary boiler 

A1 changed to 0.6 ton. 

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TVA Cumberland (CAMD_ID = 3399 / A2; SEMAP_ID = 47161 / 0011 / 004 / 01) 

The SEMAP inventory reported 15.3 tons of NOx for Auxiliary boiler A2, which was based on 

allowable emissions and is conservative. This unit was not in service in 2007 and does not 

show up in CAMD for 2007. It did not become operational until 2008. Boiler A2 was 

inadvertently included in the 2007 SEMAP emission database submittal. All emissions for 

this unit were changed to 0 for the 2007 SEMAP inventory. 

1.9.7.14 Tennessee – Davidson County (Nashville) 

Eastman Chemical (CAMD_ID = 50481 / 83-23 & 83-24; SEMAP_ID = 47163 / 0003 / 020101) 

In the SEMAP V1_8 inventory, the two boilers #23 and #24 were included as a group with 

boilers #11-22. To improve the match between CAMD and SEMAP, new records were 

created in the SEMAP database to disaggregate emissions from boilers #23 and #24 into 

individual records using the NOx and SO 

2 emissions data provided by Tennessee. 

Eastman Chemical (CAMD_ID = 50481 / 253-25, 253-26, 253-27, 253-28 and 253-29; SEMAP_ID = 

47163 / 0003 / 021520) 

In the SEMAP V1_8 inventory, the five boilers #25 to #29 were grouped together as a single 

emission point. To improve the match between CAMD and SEMAP, new records were 

created in the SEMAP database to disaggregate emissions for each boiler #25 to #29 into 

individual records using the NOx and SO 

2 emissions data provided by Tennessee. 

Eastman Chemical (CAMD_ID = 50481 / 325-30 & 325-31; SEMAP_ID = 47163 / 0003 / 261501) 

In the SEMAP V1_8 inventory, the two boilers #30 and #31 were grouped together as a 

single emission point. To improve the match between CAMD and SEMAP, new records 

were created in the SEMAP database to disaggregate emissions for each boiler #30 to #31 

into individual records using the NOx and SO 

2 emissions data provided by Tennessee. 

1.9.7.15 Tennessee – Hamilton County (Chattanooga) 

No affected facilities in the county. 

1.9.7.16 Tennessee – Knox County (Knoxville) 

No affected facilities in the county. 

1.9.7.17 Tennessee – Shelby County (Memphis) 

No issues identified. 

1.9.7.18 Virginia 

Virginia provided detailed comments on how to create hourly emissions for each unit in CAMD. No 

specific changes were requested to the SEMAP inventory. 

1.9.7.19 West Virginia 

No changes requested by State. 

1.9.8 Changes for Version 1.10a of the Point Source Inventory 

This section documents the changes to Version 1.9 of the SEMAP point source emission inventory 

to create Version 1.10a. The purpose of these revisions were to resolve significant differences in 

emissions as reported by States in Version 1.9 and the CEMs emissions as reported in the Clean Air 

Market Division’s hourly emission database. Each change that was made is identified along with the 

CAMD and SEMAP unit identifiers: 

 CAMD_ID = Plant ORIS / Boiler ID 

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 SEMAP_ID = FIPS county code / PlantID / PointID / ProcessID 

These changes were made because a number of States have indicated that they would like to have 

the SEMAP inventory updated to reflect the CAMD NOx and SO 

2 emissions from CEMS data. 

These changes had not been made in version 1.9 because of potential adjustments to the CAMD 

emissions to account for overly conservative missing data substitution procedures specified by EPA. 

Once States were allowed to review the proposed revisions to the CAMD emissions to account for 

missing data substitution, they were given the opportunity to specify the NOx and SO 

2 emissions to 

be used in the final SEMAP 2007 inventory. The choices were: 1) retain State-supplied emissions; 

2) use CAMD emissions as provided in standard EPA data sets; or 3) use CAMD emissions as 

modified by SEMAP to account for overly conservative missing data substitution values. 

In addition to the changes requested for the CEMS data, there were other changes made as a result 

of consultation with the States. Those changes are listed separately. Finally, a number of emission 

release points were identified as having incorrect latitude/longitude values. The final portion of this 

section details the emission release points that were modified and the new latitude/longitude values. 

The information below identifies those facilities that had their emissions changed as a result of the 

CEMS review. 

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1.9.8.1 Alabama County FIPS 

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ID 

Point 

ID 

Process 

 ID orisid blrid6 

PollutanCode 

01001 Southern Power Company 0010 001 01 7897 1A NOX 01001 Southern Power Company 0010 001 01 7897 1A SO2 01001 Southern Power Company 0010 002 01 7897 1B NOX 01001 Southern Power Company 0010 002 01 7897 1B SO2 01001 Southern Power Company 0010 003 01 7897 2A NOX 01001 Southern Power Company 0010 003 01 7897 2A SO2 01001 Southern Power Company 0010 004 01 7897 2B NOX 01001 Southern Power Company 0010 004 01 7897 2B SO2 01001 Tenaska Alabama II Partners LP 0009 001 01 55440 CTGDB1 NOX 01001 Tenaska Alabama II Partners LP 0009 001 01 55440 CTGDB1 SO2 01001 Tenaska Alabama II Partners LP 0009 002 01 55440 CTGDB2 NOX 01001 Tenaska Alabama II Partners LP 0009 002 01 55440 CTGDB2 SO2 01001 Tenaska Alabama II Partners LP 0009 003 01 55440 CTGDB3 NOX 01001 Tenaska Alabama II Partners LP 0009 003 01 55440 CTGDB3 SO2 01001 Tenaska Alabama Partners LP 0008 001 01 55271 CT1 NOX 01001 Tenaska Alabama Partners LP 0008 001 01 55271 CT1 SO2 01001 Tenaska Alabama Partners LP 0008 002 01 55271 CT2 NOX 01001 Tenaska Alabama Partners LP 0008 002 01 55271 CT2 SO2 01001 Tenaska Alabama Partners LP 0008 003 01 55271 CT3 NOX 01001 Tenaska Alabama Partners LP 0008 003 01 55271 CT3 SO2 01015 Calhoun Power Company I LLC Generating Station 0073 001 01 55409 CT1 NOX 01015 Calhoun Power Company I LLC Generating Station 0073 001 01 55409 CT1 SO2 01015 Calhoun Power Company I LLC Generating Station 0073 002 01 55409 CT2 NOX 01015 Calhoun Power Company I LLC Generating Station 0073 002 01 55409 CT2 SO2 01015 Calhoun Power Company I LLC Generating Station 0073 003 01 55409 CT3 NOX 01015 Calhoun Power Company I LLC Generating Station 0073 003 01 55409 CT3 SO2 01015 Calhoun Power Company I LLC Generating Station 0073 004 01 55409 CT4 NOX 01033 TVA 0010 009 01 47 1 NOX 01033 TVA 0010 009 01 47 1 SO2 01033 TVA 0010 009 01 47 2 NOX 01033 TVA 0010 009 01 47 2 SO2 01033 TVA 0010 009 01 47 3 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID 

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PollutanCode 

01033 TVA 0010 009 01 47 3 SO2 01033 TVA 0010 009 01 47 4 NOX 01033 TVA 0010 009 01 47 4 SO2 01039 PowerSouth Energy Cooperative Inc 0001 002 01 533 **4 NOX 01039 PowerSouth Energy Cooperative Inc 0001 002 01 533 **4 SO2 01039 PowerSouth Energy Cooperative Inc 0001 004 01 533 **V1 NOX 01039 PowerSouth Energy Cooperative Inc 0001 004 01 533 **V1 SO2 01039 PowerSouth Energy Cooperative Inc 0001 005 01 533 **V2 NOX 01039 PowerSouth Energy Cooperative Inc 0001 005 01 533 **V2 SO2 01055 Alabama Power Company 0002 001 01 7 1 NOX 01055 Alabama Power Company 0002 001 01 7 1 SO2 01063 Alabama Power Company 0001 001 01 10 1 NOX 01063 Alabama Power Company 0001 001 01 10 1 SO2 01063 Alabama Power Company 0001 001 01 10 2 NOX 01063 Alabama Power Company 0001 001 01 10 2 SO2 01063 Alabama Power Company 0001 002 01 10 CT2 NOX 01063 Alabama Power Company 0001 002 01 10 CT2 SO2 01063 Alabama Power Company 0001 003 01 10 CT3 NOX 01063 Alabama Power Company 0001 004 01 10 CT4 NOX 01063 Alabama Power Company 0001 005 01 10 CT5 NOX 01063 Alabama Power Company 0001 006 01 10 CT6 NOX 01063 Alabama Power Company 0001 007 01 10 CT7 NOX 01063 Alabama Power Company 0001 007 01 10 CT7 SO2 01063 Alabama Power Company 0001 008 01 10 CT8 NOX 01063 Alabama Power Company 0001 009 01 10 CT9 NOX 01063 Alabama Power Company 0001 010 01 10 CT10 NOX 01071 TVA 0008 001 01 50 1 NOX 01071 TVA 0008 001 01 50 1 SO2 01071 TVA 0008 001 01 50 2 NOX 01071 TVA 0008 001 01 50 2 SO2 01071 TVA 0008 001 01 50 3 NOX 01071 TVA 0008 001 01 50 3 SO2 01071 TVA 0008 001 01 50 4 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID 

Process 

 ID orisid blrid6 

PollutanCode 

01071 TVA 0008 001 01 50 4 SO2 01071 TVA 0008 001 01 50 5 SO2 01071 TVA 0008 001 01 50 6 NOX 01071 TVA 0008 001 01 50 6 SO2 01071 TVA 0008 002 01 50 7 NOX 01071 TVA 0008 002 01 50 7 SO2 01071 TVA 0008 003 01 50 8 NOX 01071 TVA 0008 003 01 50 8 SO2 01073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 101 1 6002 1 NOX 01073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 101 1 6002 1 SO2 01073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 102 1 6002 2 NOX 01073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 102 1 6002 2 SO2 01073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 103 1 6002 3 NOX 01073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 103 1 6002 3 SO2 01073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 104 1 6002 4 NOX 01073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 104 1 6002 4 SO2 01081 Southern Power Company 0036 001 01 7710 1A NOX 01081 Southern Power Company 0036 001 01 7710 1A SO2 01081 Southern Power Company 0036 002 01 7710 1B NOX 01081 Southern Power Company 0036 002 01 7710 1B SO2 01081 Southern Power Company 0036 003 01 7710 2A NOX 01081 Southern Power Company 0036 003 01 7710 2A SO2 01081 Southern Power Company 0036 004 01 7710 2B NOX 01081 Southern Power Company 0036 004 01 7710 2B SO2 01097 Alabama Power Company 1001 001 01 3 1 NOX 01097 Alabama Power Company 1001 001 01 3 1 SO2 01097 Alabama Power Company 1001 001 01 3 2 NOX 01097 Alabama Power Company 1001 001 01 3 2 SO2 01097 Alabama Power Company 1001 001 01 3 3 NOX 01097 Alabama Power Company 1001 001 01 3 3 SO2 01097 Alabama Power Company 1001 002 01 3 4 NOX 01097 Alabama Power Company 1001 002 01 3 4 SO2 01097 Alabama Power Company 1001 003 01 3 5 SO2 WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID 

Process 

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PollutanCode 

01097 Alabama Power Company 1001 005 01 3 6A NOX 01097 Alabama Power Company 1001 005 01 3 6A SO2 01097 Alabama Power Company 1001 006 01 3 6B NOX 01097 Alabama Power Company 1001 006 01 3 6B SO2 01097 Alabama Power Company 1001 007 01 3 7A NOX 01097 Alabama Power Company 1001 007 01 3 7A SO2 01097 Alabama Power Company 1001 008 01 3 7B NOX 01097 Alabama Power Company 1001 008 01 3 7B SO2 01097 Alabama Power Company 8073 001 01 7721 CC1 NOX 01097 Alabama Power Company 8073 001 01 7721 CC1 SO2 01097 Mobile Energy LLC 8066 001 01 55241 COG01 NOX 01103 Decatur Energy Center LLC 0079 001 01 55292 CTG-1 NOX 01103 Decatur Energy Center LLC 0079 001 01 55292 CTG-1 SO2 01103 Decatur Energy Center LLC 0079 002 01 55292 CTG-2 NOX 01103 Decatur Energy Center LLC 0079 002 01 55292 CTG-2 SO2 01103 Decatur Energy Center LLC 0079 003 01 55292 CTG-3 NOX 01103 Decatur Energy Center LLC 0079 003 01 55292 CTG-3 SO2 01103 Morgan Energy Center LLC 0080 001 01 55293 CT-1 NOX 01103 Morgan Energy Center LLC 0080 001 01 55293 CT-1 SO2 01103 Morgan Energy Center LLC 0080 002 01 55293 CT-2 SO2 01103 Morgan Energy Center LLC 0080 003 01 55293 CT-3 NOX 01103 Morgan Energy Center LLC 0080 003 01 55293 CT-3 SO2 01103 Solutia Inc 0010 001 01 880041 Z006 NOX 01103 Solutia Inc 0010 002 01 880041 X053 NOX 01103 Solutia Inc 0010 003 01 880041 X015 NOX 01117 Alabama Power Company 0005 001 01 26 1 NOX 01117 Alabama Power Company 0005 001 01 26 1 SO2 01117 Alabama Power Company 0005 001 01 26 2 NOX 01117 Alabama Power Company 0005 001 01 26 2 SO2 01117 Alabama Power Company 0005 002 01 26 4 NOX 01117 Alabama Power Company 0005 002 01 26 4 SO2 01117 Alabama Power Company 0005 003 01 26 5 NOX 01117 Alabama Power Company 0005 003 01 26 5 SO2 WV SIP Revision: Regional Haze 5-Year Periodic Report 
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PollutanCode 

01127 Alabama Power Company 0001 003 01 8 7 NOX 01127 Alabama Power Company 0001 003 01 8 7 SO2 01127 Alabama Power Company 0001 004 01 8 9 SO2 01129 Alabama Power Company 0018 001 01 7697 CC1 NOX 01129 Alabama Power Company 0018 001 01 7697 CC1 SO2 01129 PowerSouth Energy Cooperative Inc 0001 001 02 56 1 NOX 01129 PowerSouth Energy Cooperative Inc 0001 001 02 56 1 SO2 01129 PowerSouth Energy Cooperative Inc 0001 002 01 56 1 NOX 01129 PowerSouth Energy Cooperative Inc 0001 002 01 56 1 SO2 01129 PowerSouth Energy Cooperative Inc 0001 002 01 56 2 NOX 01129 PowerSouth Energy Cooperative Inc 0001 002 01 56 2 SO2 01129 PowerSouth Energy Cooperative Inc 0001 003 01 56 3 NOX 01129 PowerSouth Energy Cooperative Inc 0001 003 01 56 3 SO2 01129 PowerSouth Energy Cooperative Inc 0012 002 01 7063 **2 NOX 01129 PowerSouth Energy Cooperative Inc 0012 002 01 7063 **2 SO2 01129 PowerSouth Energy Cooperative Inc 0012 003 01 7063 **3 SO2 1.9.8.2 Alabama – Jefferson County No issues identified. 1.9.8.3 Florida County FIPS 

Facility 

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ID 

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ID 

Process 

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Pollutant Code E

12001 CITY OF GAINESVILLE, GRU 0010006 3 1 663 B1 NOX 12001 CITY OF GAINESVILLE, GRU 0010006 3 1 663 B1 SO2 12001 CITY OF GAINESVILLE, GRU 0010006 3 2 663 B1 NOX 12001 CITY OF GAINESVILLE, GRU 0010006 3 2 663 B1 SO2 12001 CITY OF GAINESVILLE, GRU 0010006 5 3 663 B2 NOX 312001 CITY OF GAINESVILLE, GRU 0010006 5 3 663 B2 SO2 712001 CITY OF GAINESVILLE, GRU 0010006 6 1 663 CT3 NOX 12001 CITY OF GAINESVILLE, GRU 0010006 6 1 663 CT3 SO2 12001 FLORIDA POWER CORPORATION D/B/A PROGRESS 0010001 7 2 7345 1 NOX 12001 FLORIDA POWER CORPORATION D/B/A PROGRESS 0010001 7 2 7345 1 SO2 12001 GAINESVILLE REGIONAL UTILITIES 0010005 10 1 664 CC1 NOX 12001 GAINESVILLE REGIONAL UTILITIES 0010005 10 1 664 CC1 SO2 WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 1 NOX 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 1 SO2 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 2 NOX 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 2 SO2 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 1 NOX 212005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 1 SO2 612005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 2 NOX 212005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 2 SO2 812005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 1 NOX 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 1 SO2 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 2 NOX 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 2 SO2 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 1 643 4 NOX 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 1 643 4 SO2 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 2 643 4 NOX 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 2 643 4 SO2 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 1 643 5 NOX 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 1 643 5 SO2 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 2 643 5 NOX 12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 2 643 5 SO2 12009 FLORIDA POWER & LIGHT (PCC) 0090006 1 1 609 PCC1 NOX 112009 FLORIDA POWER & LIGHT (PCC) 0090006 1 1 609 PCC1 SO2 12009 FLORIDA POWER & LIGHT (PCC) 0090006 1 2 609 PCC1 NOX 12009 FLORIDA POWER & LIGHT (PCC) 0090006 1 2 609 PCC1 SO2 112009 FLORIDA POWER & LIGHT (PCC) 0090006 1 6 609 PCC1 NOX 12009 FLORIDA POWER & LIGHT (PCC) 0090006 1 6 609 PCC1 SO2 12009 FLORIDA POWER & LIGHT (PCC) 0090006 2 1 609 PCC2 NOX 112009 FLORIDA POWER & LIGHT (PCC) 0090006 2 1 609 PCC2 SO2 12009 FLORIDA POWER & LIGHT (PCC) 0090006 2 2 609 PCC2 NOX 112009 FLORIDA POWER & LIGHT (PCC) 0090006 2 2 609 PCC2 SO2 212009 FLORIDA POWER & LIGHT (PCC) 0090006 2 6 609 PCC2 NOX 12009 FLORIDA POWER & LIGHT (PCC) 0090006 2 6 609 PCC2 SO2 12009 OLEANDER POWER PROJECT, LP 0090180 1 1 55286 O-1 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12009 OLEANDER POWER PROJECT, LP 0090180 1 1 55286 O-1 SO2 12009 OLEANDER POWER PROJECT, LP 0090180 1 2 55286 O-1 NOX 12009 OLEANDER POWER PROJECT, LP 0090180 1 2 55286 O-1 SO2 12009 OLEANDER POWER PROJECT, LP 0090180 2 1 55286 O-2 NOX 12009 OLEANDER POWER PROJECT, LP 0090180 2 1 55286 O-2 SO2 12009 OLEANDER POWER PROJECT, LP 0090180 2 2 55286 O-2 NOX 12009 OLEANDER POWER PROJECT, LP 0090180 2 2 55286 O-2 SO2 12009 OLEANDER POWER PROJECT, LP 0090180 3 1 55286 O-3 NOX 12009 OLEANDER POWER PROJECT, LP 0090180 3 1 55286 O-3 SO2 12009 OLEANDER POWER PROJECT, LP 0090180 3 2 55286 O-3 NOX 12009 OLEANDER POWER PROJECT, LP 0090180 3 2 55286 O-3 SO2 12009 OLEANDER POWER PROJECT, LP 0090180 4 1 55286 O-4 NOX 12009 OLEANDER POWER PROJECT, LP 0090180 4 1 55286 O-4 SO2 12009 OLEANDER POWER PROJECT, LP 0090180 4 2 55286 O-4 NOX 12009 OLEANDER POWER PROJECT, LP 0090180 4 2 55286 O-4 SO2 12009 ORLANDO UTLITIES COMMISSION 0090008 5 2 683 **C NOX 12009 ORLANDO UTLITIES COMMISSION 0090008 5 2 683 **C SO2 12009 ORLANDO UTLITIES COMMISSION 0090008 6 2 683 **D NOX 12009 ORLANDO UTLITIES COMMISSION 0090008 6 2 683 **D SO2 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 1 NOX 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 1 SO2 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 2 NOX 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 2 SO2 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 1 NOX 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 1 SO2 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 2 NOX 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 2 SO2 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 3 55318 1 SO2 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 3 55318 2 SO2 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 4 55318 2 SO2 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 1 55318 3 NOX 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 1 55318 3 SO2 12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 2 55318 3 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 2 55318 3 SO2 12011 FLORIDA POWER & LIGHT (PFL) 0110037 35 1 613 4GT1 NOX 12011 FLORIDA POWER & LIGHT (PFL) 0110037 35 1 613 4GT1 SO2 12011 FLORIDA POWER & LIGHT (PFL) 0110037 35 2 613 4GT1 NOX 12011 FLORIDA POWER & LIGHT (PFL) 0110037 35 2 613 4GT1 SO2 12011 FLORIDA POWER & LIGHT (PFL) 0110037 36 1 613 4GT2 NOX 12011 FLORIDA POWER & LIGHT (PFL) 0110037 36 1 613 4GT2 SO2 12011 FLORIDA POWER & LIGHT (PFL) 0110037 36 2 613 4GT2 NOX 12011 FLORIDA POWER & LIGHT (PFL) 0110037 36 2 613 4GT2 SO2 12011 FLORIDA POWER & LIGHT (PFL) 0110037 37 2 613 5GT1 NOX 12011 FLORIDA POWER & LIGHT (PFL) 0110037 37 2 613 5GT1 SO2 12011 FLORIDA POWER & LIGHT (PFL) 0110037 38 1 613 5GT2 NOX 12011 FLORIDA POWER & LIGHT (PFL) 0110037 38 1 613 5GT2 SO2 12011 FLORIDA POWER & LIGHT (PPE) 0110036 1 1 617 PPE1 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 1 1 617 PPE1 SO2 12011 FLORIDA POWER & LIGHT (PPE) 0110036 1 2 617 PPE1 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 1 2 617 PPE1 SO2 112011 FLORIDA POWER & LIGHT (PPE) 0110036 1 7 617 PPE1 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 1 7 617 PPE1 SO2 12011 FLORIDA POWER & LIGHT (PPE) 0110036 2 1 617 PPE2 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 2 1 617 PPE2 SO2 12011 FLORIDA POWER & LIGHT (PPE) 0110036 2 2 617 PPE2 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 2 2 617 PPE2 SO2 112011 FLORIDA POWER & LIGHT (PPE) 0110036 2 6 617 PPE2 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 2 6 617 PPE2 SO2 12011 FLORIDA POWER & LIGHT (PPE) 0110036 3 1 617 PPE3 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 3 1 617 PPE3 SO2 12011 FLORIDA POWER & LIGHT (PPE) 0110036 3 2 617 PPE3 NOX 112011 FLORIDA POWER & LIGHT (PPE) 0110036 3 2 617 PPE3 SO2 312011 FLORIDA POWER & LIGHT (PPE) 0110036 3 6 617 PPE3 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 3 6 617 PPE3 SO2 12011 FLORIDA POWER & LIGHT (PPE) 0110036 4 1 617 PPE4 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 4 1 617 PPE4 SO2 WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12011 FLORIDA POWER & LIGHT (PPE) 0110036 4 2 617 PPE4 NOX 212011 FLORIDA POWER & LIGHT (PPE) 0110036 4 2 617 PPE4 SO2 412011 FLORIDA POWER & LIGHT (PPE) 0110036 4 6 617 PPE4 NOX 12011 FLORIDA POWER & LIGHT (PPE) 0110036 4 6 617 PPE4 SO2 12017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 1 3 628 1 NOX 412017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 1 3 628 1 SO2 1612017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 2 4 628 2 NOX 412017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 2 4 628 2 SO2 1912017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 3 2 628 5 NOX 1212017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 3 2 628 5 SO2 2612017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 4 2 628 4 NOX 1412017 FLORIDA POWER CORPORATION D/B/A PROGRESS 0170004 4 2 628 4 SO2 2912027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 1 55422 CT1 NOX 12027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 1 55422 CT1 SO2 12027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 2 55422 CT1 NOX 12027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 2 55422 CT1 SO2 12027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 1 55422 CT2 NOX 12027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 1 55422 CT2 SO2 12027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 2 55422 CT2 NOX 12027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 2 55422 CT2 SO2 12031 JEA 0310045 16 1 207 1 NOX 12031 JEA 0310045 16 1 207 1 SO2 12031 JEA 0310045 16 2 207 1 NOX 12031 JEA 0310045 16 2 207 1 SO2 12031 JEA 0310045 16 3 207 1 NOX 1012031 JEA 0310045 16 3 207 1 SO2 612031 JEA 0310045 17 1 207 2 NOX 12031 JEA 0310045 17 1 207 2 SO2 12031 JEA 0310045 17 2 207 2 NOX 112031 JEA 0310045 17 2 207 2 SO2 312031 JEA 0310045 17 3 207 2 NOX 912031 JEA 0310045 17 3 207 2 SO2 312031 JEA 0310045 26 1 667 2A NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12031 JEA 0310045 26 1 667 2A SO2 12031 JEA 0310045 26 2 667 2A NOX 12031 JEA 0310045 26 2 667 2A SO2 112031 JEA 0310045 26 3 667 2A NOX 12031 JEA 0310045 27 1 667 1A NOX 12031 JEA 0310045 27 1 667 1A SO2 12031 JEA 0310045 27 2 667 1A NOX 12031 JEA 0310045 27 2 667 1A SO2 112031 JEA 0310045 27 3 667 1A NOX 12031 JEA 0310045 3 1 667 3 NOX 12031 JEA 0310045 3 2 667 3 NOX 12031 JEA 0310045 3 2 667 3 SO2 112031 JEA 0310045 3 5 667 3 NOX 12031 JEA 0310047 15 1 666 7 NOX 12031 JEA 0310047 15 2 666 7 NOX 12031 JEA 0310047 15 2 666 7 SO2 12031 JEA 0310485 1 1 7846 1 NOX 12031 JEA 0310485 1 1 7846 1 SO2 12031 JEA 0310485 2 2 7846 2 NOX 12031 JEA 0310485 2 2 7846 2 SO2 12031 JEA 0310485 3 2 7846 3 NOX 12031 JEA 0310485 3 2 7846 3 SO2 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 1 641 6 NOX 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 1 641 6 SO2 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 1 641 7 NOX 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 1 641 7 SO2 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 4 NOX 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 4 SO2 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 5 NOX 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 5 SO2 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 6 NOX 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 6 SO2 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 7 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12033 GULF POWER COMPANY CRIST PLANT 0330045 1 2 641 7 SO2 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 4 NOX 112033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 4 SO2 312033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 5 NOX 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 5 SO2 312033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 6 NOX 212033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 6 SO2 1212033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 7 NOX 112033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 7 SO2 2112033 GULF POWER COMPANY CRIST PLANT 0330045 1 4 641 4 NOX 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 4 641 4 SO2 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 4 641 5 NOX 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 4 641 5 SO2 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 5 641 4 NOX 12033 GULF POWER COMPANY CRIST PLANT 0330045 1 5 641 4 SO2 12049 HARDEE POWER PARTNERS LIMITED 0490015 5 1 50949 CT2B NOX 12049 HARDEE POWER PARTNERS LIMITED 0490015 5 2 50949 CT2B NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 1 7380 1 NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 1 7380 1 SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 2 7380 1 NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 2 7380 1 SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 1 7380 2 NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 1 7380 2 SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 2 7380 2 NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 2 7380 2 SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 5 1 7380 4A NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 5 1 7380 4A SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 5 2 7380 4B NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 5 2 7380 4B SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 6 1 7380 5A NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 6 1 7380 5A SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 6 2 7380 5B NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 6 2 7380 5B SO2 WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 7 1 7380 6A NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 7 1 7380 6A SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 7 2 7380 6B NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 7 2 7380 6B SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 8 1 7380 7A NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 8 1 7380 7A SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 8 2 7380 7B NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 8 2 7380 7B SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 9 1 7380 8A NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 9 1 7380 8A SO2 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 9 2 7380 8B NOX 12049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 9 2 7380 8B SO2 12049 VANDOLAH POWER COMPANY, LLC 0490043 1 1 55415 GT101 NOX 12049 VANDOLAH POWER COMPANY, LLC 0490043 1 1 55415 GT101 SO2 12049 VANDOLAH POWER COMPANY, LLC 0490043 1 2 55415 GT101 NOX 12049 VANDOLAH POWER COMPANY, LLC 0490043 2 1 55415 GT201 NOX 12049 VANDOLAH POWER COMPANY, LLC 0490043 2 1 55415 GT201 SO2 12049 VANDOLAH POWER COMPANY, LLC 0490043 2 2 55415 GT201 NOX 12049 VANDOLAH POWER COMPANY, LLC 0490043 3 1 55415 GT301 NOX 12049 VANDOLAH POWER COMPANY, LLC 0490043 3 1 55415 GT301 SO2 12049 VANDOLAH POWER COMPANY, LLC 0490043 3 2 55415 GT301 NOX 12049 VANDOLAH POWER COMPANY, LLC 0490043 4 1 55415 GT401 NOX 12049 VANDOLAH POWER COMPANY, LLC 0490043 4 1 55415 GT401 SO2 12049 VANDOLAH POWER COMPANY, LLC 0490043 4 2 55415 GT401 NOX 12057 TAMPA ELECTRIC COMPANY 0570039 1 2 645 BB01 NOX 1012057 TAMPA ELECTRIC COMPANY 0570039 1 2 645 BB01 SO2 212057 TAMPA ELECTRIC COMPANY 0570039 2 2 645 BB02 NOX 1012057 TAMPA ELECTRIC COMPANY 0570039 2 2 645 BB02 SO2 212057 TAMPA ELECTRIC COMPANY 0570039 3 2 645 BB03 NOX 312057 TAMPA ELECTRIC COMPANY 0570039 3 2 645 BB03 SO2 112057 TAMPA ELECTRIC COMPANY 0570039 4 2 645 BB04 NOX 112057 TAMPA ELECTRIC COMPANY 0570039 4 2 645 BB04 SO2 212057 TAMPA ELECTRIC COMPANY 0570040 20 1 7873 CT1A NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12057 TAMPA ELECTRIC COMPANY 0570040 20 1 7873 CT1A SO2 12057 TAMPA ELECTRIC COMPANY 0570040 21 1 7873 CT1B NOX 12057 TAMPA ELECTRIC COMPANY 0570040 21 1 7873 CT1B SO2 12057 TAMPA ELECTRIC COMPANY 0570040 22 1 7873 CT1C NOX 12057 TAMPA ELECTRIC COMPANY 0570040 22 1 7873 CT1C SO2 12057 TAMPA ELECTRIC COMPANY 0570040 23 1 7873 CT2A NOX 12057 TAMPA ELECTRIC COMPANY 0570040 23 1 7873 CT2A SO2 12057 TAMPA ELECTRIC COMPANY 0570040 24 1 7873 CT2B NOX 12057 TAMPA ELECTRIC COMPANY 0570040 24 1 7873 CT2B SO2 12057 TAMPA ELECTRIC COMPANY 0570040 25 1 7873 CT2C NOX 12057 TAMPA ELECTRIC COMPANY 0570040 25 1 7873 CT2C SO2 12057 TAMPA ELECTRIC COMPANY 0570040 26 1 7873 CT2D NOX 12057 TAMPA ELECTRIC COMPANY 0570040 26 1 7873 CT2D SO2 12061 CITY OF VERO BEACH 0610029 3 1 693 3 NOX 12061 CITY OF VERO BEACH 0610029 3 1 693 3 SO2 12061 CITY OF VERO BEACH 0610029 4 1 693 4 NOX 12061 CITY OF VERO BEACH 0610029 4 1 693 4 SO2 12061 CITY OF VERO BEACH 0610029 5 1 693 **5 NOX 12061 CITY OF VERO BEACH 0610029 5 1 693 **5 SO2 12061 CITY OF VERO BEACH 0610029 5 2 693 **5 NOX 12061 CITY OF VERO BEACH 0610029 5 2 693 **5 SO2 12063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 1 642 1 NOX 12063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 1 642 1 SO2 12063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 1 642 2 NOX 12063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 1 642 2 SO2 12063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 2 642 1 NOX 12063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 2 642 1 SO2 212063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 2 642 2 NOX 12063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 2 642 2 SO2 212063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 3 642 1 NOX 12063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 3 642 1 SO2 12071 FLORIDA POWER & LIGHT (PFM) 0710002 18 1 612 FMCT2A NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 18 1 612 FMCT2A SO2 WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12071 FLORIDA POWER & LIGHT (PFM) 0710002 19 1 612 FMCT2B NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 19 1 612 FMCT2B SO2 12071 FLORIDA POWER & LIGHT (PFM) 0710002 20 1 612 FMCT2C NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 20 1 612 FMCT2C SO2 12071 FLORIDA POWER & LIGHT (PFM) 0710002 21 1 612 FMCT2D NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 21 1 612 FMCT2D SO2 12071 FLORIDA POWER & LIGHT (PFM) 0710002 22 1 612 FMCT2E NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 22 1 612 FMCT2E SO2 12071 FLORIDA POWER & LIGHT (PFM) 0710002 23 1 612 FMCT2F NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 23 1 612 FMCT2F SO2 12071 FLORIDA POWER & LIGHT (PFM) 0710002 27 1 612 PFM3A NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 27 1 612 PFM3A SO2 12071 FLORIDA POWER & LIGHT (PFM) 0710002 27 2 612 PFM3A NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 27 2 612 PFM3A SO2 12071 FLORIDA POWER & LIGHT (PFM) 0710002 28 1 612 PFM3B NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 28 1 612 PFM3B SO2 12071 FLORIDA POWER & LIGHT (PFM) 0710002 28 2 612 PFM3B NOX 12071 FLORIDA POWER & LIGHT (PFM) 0710002 28 2 612 PFM3B SO2 12073 CITY OF TALLAHASSEE 0730003 1 1 688 1 NOX 12073 CITY OF TALLAHASSEE 0730003 1 1 688 1 SO2 12073 CITY OF TALLAHASSEE 0730003 31 1 688 HC3 NOX 12073 CITY OF TALLAHASSEE 0730003 31 1 688 HC3 SO2 12073 CITY OF TALLAHASSEE 0730003 31 2 688 HC3 NOX 12073 CITY OF TALLAHASSEE 0730003 31 2 688 HC3 SO2 12073 CITY OF TALLAHASSEE 0730003 32 1 688 HC4 NOX 12073 CITY OF TALLAHASSEE 0730003 32 1 688 HC4 SO2 12073 CITY OF TALLAHASSEE 0730003 32 2 688 HC4 NOX 12073 CITY OF TALLAHASSEE 0730003 32 2 688 HC4 SO2 12073 CITY OF TALLAHASSEE 0730003 4 1 688 2 NOX 12073 CITY OF TALLAHASSEE 0730003 4 1 688 2 SO2 12073 CITY OF TALLAHASSEE 0730003 4 2 688 2 NOX 12073 CITY OF TALLAHASSEE 0730003 4 2 688 2 SO2 12081 FLORIDA POWER & LIGHT (PMT) 0810010 1 2 6042 PMT1 NOX 1WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12081 FLORIDA POWER & LIGHT (PMT) 0810010 1 2 6042 PMT1 SO2 612081 FLORIDA POWER & LIGHT (PMT) 0810010 1 4 6042 PMT1 NOX 12081 FLORIDA POWER & LIGHT (PMT) 0810010 1 4 6042 PMT1 SO2 12081 FLORIDA POWER & LIGHT (PMT) 0810010 1 7 6042 PMT1 NOX 12081 FLORIDA POWER & LIGHT (PMT) 0810010 1 7 6042 PMT1 SO2 12081 FLORIDA POWER & LIGHT (PMT) 0810010 2 2 6042 PMT2 NOX 112081 FLORIDA POWER & LIGHT (PMT) 0810010 2 2 6042 PMT2 SO2 512081 FLORIDA POWER & LIGHT (PMT) 0810010 2 3 6042 PMT2 NOX 12081 FLORIDA POWER & LIGHT (PMT) 0810010 2 3 6042 PMT2 SO2 12081 FLORIDA POWER & LIGHT (PMT) 0810010 2 6 6042 PMT2 NOX 12081 FLORIDA POWER & LIGHT (PMT) 0810010 2 6 6042 PMT2 SO2 12081 FLORIDA POWER & LIGHT (PMT) 0810010 5 1 6042 MTCT3A NOX 12081 FLORIDA POWER & LIGHT (PMT) 0810010 5 1 6042 MTCT3A SO2 12081 FLORIDA POWER & LIGHT (PMT) 0810010 6 1 6042 MTCT3B NOX 12081 FLORIDA POWER & LIGHT (PMT) 0810010 6 1 6042 MTCT3B SO2 12081 FLORIDA POWER & LIGHT (PMT) 0810010 7 1 6042 MTCT3C NOX 12081 FLORIDA POWER & LIGHT (PMT) 0810010 7 1 6042 MTCT3C SO2 12081 FLORIDA POWER & LIGHT (PMT) 0810010 8 1 6042 MTCT3D NOX 12081 FLORIDA POWER & LIGHT (PMT) 0810010 8 1 6042 MTCT3D SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 1 1 6043 PMR1 NOX 112085 FLORIDA POWER & LIGHT (PMR) 0850001 1 1 6043 PMR1 SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 1 3 6043 PMR1 NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 1 3 6043 PMR1 SO2 412085 FLORIDA POWER & LIGHT (PMR) 0850001 1 6 6043 PMR1 NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 1 6 6043 PMR1 SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 11 1 6043 PMR8A NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 11 1 6043 PMR8A SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 11 2 6043 PMR8A NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 11 2 6043 PMR8A SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 12 1 6043 PMR8B NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 12 1 6043 PMR8B SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 12 2 6043 PMR8B NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 12 2 6043 PMR8B SO2 WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12085 FLORIDA POWER & LIGHT (PMR) 0850001 17 1 6043 PMR8C NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 17 1 6043 PMR8C SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 17 2 6043 PMR8C NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 17 2 6043 PMR8C SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 18 1 6043 PMR8D NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 18 1 6043 PMR8D SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 18 2 6043 PMR8D NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 18 2 6043 PMR8D SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 2 1 6043 PMR2 NOX 112085 FLORIDA POWER & LIGHT (PMR) 0850001 2 1 6043 PMR2 SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 2 3 6043 PMR2 NOX 112085 FLORIDA POWER & LIGHT (PMR) 0850001 2 3 6043 PMR2 SO2 512085 FLORIDA POWER & LIGHT (PMR) 0850001 2 6 6043 PMR2 NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 2 6 6043 PMR2 SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 3 2 6043 HRSG3A NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 3 2 6043 HRSG3A SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 4 1 6043 HRSG3B NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 4 1 6043 HRSG3B SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 5 2 6043 HRSG4A NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 5 2 6043 HRSG4A SO2 12085 FLORIDA POWER & LIGHT (PMR) 0850001 6 1 6043 HRSG4B NOX 12085 FLORIDA POWER & LIGHT (PMR) 0850001 6 1 6043 HRSG4B SO2 12086 FLORIDA POWER & LIGHT (PCU) 0250001 3 2 610 PCU5 NOX 12086 FLORIDA POWER & LIGHT (PCU) 0250001 3 2 610 PCU5 SO2 12086 FLORIDA POWER & LIGHT (PCU) 0250001 4 2 610 PCU6 NOX 12086 FLORIDA POWER & LIGHT (PCU) 0250001 4 2 610 PCU6 SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 1 1 621 PTP1 NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 1 1 621 PTP1 SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 1 2 621 PTP1 NOX 112086 FLORIDA POWER & LIGHT (PTF) 0250003 1 2 621 PTP1 SO2 412086 FLORIDA POWER & LIGHT (PTF) 0250003 1 5 621 PTP1 NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 1 5 621 PTP1 SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 10 1 621 TPCT5B NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12086 FLORIDA POWER & LIGHT (PTF) 0250003 10 1 621 TPCT5B SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 10 2 621 TPCT5B NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 10 2 621 TPCT5B SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 11 1 621 TPCT5C NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 11 1 621 TPCT5C SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 11 2 621 TPCT5C NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 11 2 621 TPCT5C SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 12 1 621 TPCT5D NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 12 1 621 TPCT5D SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 12 2 621 TPCT5D NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 12 2 621 TPCT5D SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 2 1 621 PTP2 NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 2 1 621 PTP2 SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 2 2 621 PTP2 NOX 112086 FLORIDA POWER & LIGHT (PTF) 0250003 2 2 621 PTP2 SO2 312086 FLORIDA POWER & LIGHT (PTF) 0250003 2 5 621 PTP2 NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 2 5 621 PTP2 SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 9 1 621 TPCT5A NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 9 1 621 TPCT5A SO2 12086 FLORIDA POWER & LIGHT (PTF) 0250003 9 2 621 TPCT5A NOX 12086 FLORIDA POWER & LIGHT (PTF) 0250003 9 2 621 TPCT5A SO2 12087 KEYS ENERGY SERVICES 0870003 11 1 6584 CT4 NOX 12087 KEYS ENERGY SERVICES 0870003 11 1 6584 CT4 SO2 12095 ORLANDO COGEN LIMITED, L.P. 0950203 1 1 54466 1 NOX 12095 ORLANDO COGEN LIMITED, L.P. 0950203 1 1 54466 1 SO2 12095 ORLANDO UTILITIES COMMISSION 0950137 1 2 564 1 NOX 12095 ORLANDO UTILITIES COMMISSION 0950137 1 2 564 1 SO2 12095 ORLANDO UTILITIES COMMISSION 0950137 1 3 564 1 NOX 612095 ORLANDO UTILITIES COMMISSION 0950137 1 3 564 1 SO2 412095 ORLANDO UTILITIES COMMISSION 0950137 1 4 564 1 NOX 12095 ORLANDO UTILITIES COMMISSION 0950137 1 5 564 1 NOX 12095 ORLANDO UTILITIES COMMISSION 0950137 1 5 564 1 SO2 12095 ORLANDO UTILITIES COMMISSION 0950137 2 2 564 2 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12095 ORLANDO UTILITIES COMMISSION 0950137 2 2 564 2 SO2 12095 ORLANDO UTILITIES COMMISSION 0950137 2 3 564 2 NOX 212095 ORLANDO UTILITIES COMMISSION 0950137 2 3 564 2 SO2 112095 ORLANDO UTILITIES COMMISSION 0950137 2 4 564 2 NOX 12095 ORLANDO UTILITIES COMMISSION 0950137 2 4 564 2 SO2 12095 ORLANDO UTILITIES COMMISSION 0950137 2 5 564 2 NOX 12095 ORLANDO UTILITIES COMMISSION 0950137 26 1 55821 25 NOX 12095 ORLANDO UTILITIES COMMISSION 0950137 26 1 55821 25 SO2 12095 ORLANDO UTILITIES COMMISSION 0950137 26 2 55821 25 NOX 12095 ORLANDO UTILITIES COMMISSION 0950137 26 2 55821 25 SO2 12095 ORLANDO UTILITIES COMMISSION 0950137 27 1 55821 26 NOX 12095 ORLANDO UTILITIES COMMISSION 0950137 27 1 55821 26 SO2 12095 ORLANDO UTILITIES COMMISSION 0950137 27 2 55821 26 NOX 12095 ORLANDO UTILITIES COMMISSION 0950137 27 2 55821 26 SO2 12095 WALT DISNEY WORLD COMPANY 0950111 88 1 7254 32432 NOX 12095 WALT DISNEY WORLD COMPANY 0950111 88 1 7254 32432 SO2 12095 WALT DISNEY WORLD COMPANY 0950111 88 2 7254 32432 NOX 12095 WALT DISNEY WORLD COMPANY 0950111 88 2 7254 32432 SO2 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 10 1 8049 **10 NOX 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 10 1 8049 **10 SO2 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 11 1 8049 **11 NOX 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 11 1 8049 **11 SO2 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 18 2 8049 **12 NOX 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 18 2 8049 **12 SO2 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 19 2 8049 **13 NOX 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 19 2 8049 **13 SO2 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 21 2 8049 **14 NOX 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 21 2 8049 **14 SO2 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 7 1 8049 **7 NOX 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 7 1 8049 **7 SO2 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 8 1 8049 **8 NOX 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 8 1 8049 **8 SO2 12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 9 1 8049 **9 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12097 FLORIDA POWER CORPORATION D/B/A PROGRESS 0970014 9 1 8049 **9 SO2 12097 KISSIMMEE UTILITY AUTHORITY 0970043 1 1 7238 **1 NOX 12097 KISSIMMEE UTILITY AUTHORITY 0970043 1 1 7238 **1 SO2 12097 KISSIMMEE UTILITY AUTHORITY 0970043 2 1 7238 2 NOX 12097 KISSIMMEE UTILITY AUTHORITY 0970043 2 1 7238 2 SO2 12097 KISSIMMEE UTILITY AUTHORITY 0970043 3 1 7238 3 NOX 12097 KISSIMMEE UTILITY AUTHORITY 0970043 3 1 7238 3 SO2 12097 RELIANT ENERGY FLORIDA, LLC 0970071 1 1 55192 OSC1 NOX 12097 RELIANT ENERGY FLORIDA, LLC 0970071 1 1 55192 OSC1 SO2 12097 RELIANT ENERGY FLORIDA, LLC 0970071 2 1 55192 OSC2 NOX 12097 RELIANT ENERGY FLORIDA, LLC 0970071 2 1 55192 OSC2 SO2 12097 RELIANT ENERGY FLORIDA, LLC 0970071 3 1 55192 OSC3 NOX 12097 RELIANT ENERGY FLORIDA, LLC 0970071 3 1 55192 OSC3 SO2 12097 RELIANT ENERGY FLORIDA, LLC 0970071 3 2 55192 OSC3 NOX 12097 RELIANT ENERGY FLORIDA, LLC 0970071 3 2 55192 OSC3 SO2 12099 CITY OF LAKE WORTH UTILITIES 0990045 9 1 673 S-3 NOX 12099 CITY OF LAKE WORTH UTILITIES 0990045 9 1 673 S-3 SO2 12099 FLORIDA POWER & LIGHT (PRV) 0990042 3 1 619 PRV3 NOX 12099 FLORIDA POWER & LIGHT (PRV) 0990042 3 1 619 PRV3 SO2 12099 FLORIDA POWER & LIGHT (PRV) 0990042 3 3 619 PRV3 NOX 112099 FLORIDA POWER & LIGHT (PRV) 0990042 3 3 619 PRV3 SO2 212099 FLORIDA POWER & LIGHT (PRV) 0990042 3 7 619 PRV3 NOX 12099 FLORIDA POWER & LIGHT (PRV) 0990042 3 7 619 PRV3 SO2 12099 FLORIDA POWER & LIGHT (PRV) 0990042 4 1 619 PRV4 NOX 12099 FLORIDA POWER & LIGHT (PRV) 0990042 4 1 619 PRV4 SO2 12099 FLORIDA POWER & LIGHT (PRV) 0990042 4 3 619 PRV4 NOX 112099 FLORIDA POWER & LIGHT (PRV) 0990042 4 3 619 PRV4 SO2 212099 FLORIDA POWER & LIGHT (PRV) 0990042 4 7 619 PRV4 NOX 12099 FLORIDA POWER & LIGHT (PRV) 0990042 4 7 619 PRV4 SO2 12101 FLORIDA POWER CORPDBAPROGRESS ENERGY FL 1010017 1 3 8048 1 NOX 312101 FLORIDA POWER CORPDBAPROGRESS ENERGY FL 1010017 1 3 8048 1 SO2 1312101 FLORIDA POWER CORPDBAPROGRESS ENERGY FL 1010017 2 2 8048 2 NOX 312101 FLORIDA POWER CORPDBAPROGRESS ENERGY FL 1010017 2 2 8048 2 SO2 13WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 1 1 55414 GT101 NOX 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 1 1 55414 GT101 SO2 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 1 2 55414 GT101 NOX 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 1 2 55414 GT101 SO2 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 2 1 55414 GT201 NOX 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 2 1 55414 GT201 SO2 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 2 2 55414 GT201 NOX 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 2 2 55414 GT201 SO2 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 3 1 55414 GT301 NOX 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 3 1 55414 GT301 SO2 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 3 2 55414 GT301 NOX 12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 3 2 55414 GT301 SO2 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 1 634 1 NOX 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 1 634 1 SO2 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 2 634 1 NOX 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 2 634 1 SO2 312103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 3 634 1 SO2 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 2 634 2 NOX 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 2 634 2 SO2 212103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 5 634 2 NOX 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 5 634 2 SO2 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 6 634 2 NOX 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 6 634 2 SO2 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 1 634 3 SO2 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 2 634 3 NOX 112103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 2 634 3 SO2 612103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 4 634 3 SO2 12103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 5 634 3 SO2 12105 APP, LP; APEC, LLC; CCFC 1050221 1 1 54658 1 NOX 12105 APP, LP; APEC, LLC; CCFC 1050221 1 1 54658 1 SO2 12105 APP, LP; APEC, LLC; CCFC 1050221 6 1 55833 6 NOX 12105 APP, LP; APEC, LLC; CCFC 1050221 6 1 55833 6 SO2 12105 APP, LP; APEC, LLC; CCFC 1050221 8 1 55412 CT1 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12105 APP, LP; APEC, LLC; CCFC 1050221 8 1 55412 CT1 SO2 12105 APP, LP; APEC, LLC; CCFC 1050221 9 1 55412 CT2 NOX 12105 APP, LP; APEC, LLC; CCFC 1050221 9 1 55412 CT2 SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050223 1 2 7699 1 NOX 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050223 1 2 7699 1 SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 1 1 7302 1A NOX 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 1 1 7302 1A SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 14 1 7302 2A NOX 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 14 1 7302 2A SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 14 2 7302 2A SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 15 1 7302 2B NOX 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 15 1 7302 2B SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 15 2 7302 2B SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 16 1 7302 3A NOX 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 16 1 7302 3A SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 16 2 7302 3A SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 17 1 7302 3B NOX 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 17 1 7302 3B SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 17 2 7302 3B SO2 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 2 1 7302 1B NOX 12105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 2 1 7302 1B SO2 12105 LAKELAND ELECTRIC 1050003 8 1 675 **8 NOX 12105 LAKELAND ELECTRIC 1050003 8 1 675 **8 SO2 12105 LAKELAND ELECTRIC 1050003 8 2 675 **8 NOX 12105 LAKELAND ELECTRIC 1050004 1 1 676 1 NOX 12105 LAKELAND ELECTRIC 1050004 1 1 676 1 SO2 12105 LAKELAND ELECTRIC 1050004 1 2 676 1 NOX 12105 LAKELAND ELECTRIC 1050004 1 2 676 1 SO2 12105 LAKELAND ELECTRIC 1050004 1 3 676 1 NOX 12105 LAKELAND ELECTRIC 1050004 1 3 676 1 SO2 12105 LAKELAND ELECTRIC 1050004 28 2 676 5 NOX 12105 LAKELAND ELECTRIC 1050004 28 2 676 5 SO2 12105 LAKELAND ELECTRIC 1050004 5 1 676 2 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12105 LAKELAND ELECTRIC 1050004 5 1 676 2 SO2 12105 LAKELAND ELECTRIC 1050004 5 2 676 2 NOX 12105 LAKELAND ELECTRIC 1050004 5 2 676 2 SO2 12105 LAKELAND ELECTRIC 1050004 6 3 676 3 NOX 512105 LAKELAND ELECTRIC 1050004 6 3 676 3 SO2 712105 LAKELAND ELECTRIC 1050004 6 4 676 3 NOX 12105 LAKELAND ELECTRIC 1050004 6 4 676 3 SO2 12105 LAKELAND ELECTRIC 1050004 6 9 676 3 NOX 12105 LAKELAND ELECTRIC 1050004 6 9 676 3 SO2 12105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 1 1 54365 1 NOX 12105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 1 1 54365 1 SO2 12105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 2 1 54365 2 NOX 12105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 2 1 54365 2 SO2 12105 POLK POWER PARTNERS, L.P. 1050217 1 1 54426 1 NOX 12105 POLK POWER PARTNERS, L.P. 1050217 1 1 54426 1 SO2 12105 TAMPA ELECTRIC COMPANY 1050233 1 2 7242 **1 NOX 12105 TAMPA ELECTRIC COMPANY 1050233 1 2 7242 **1 SO2 112105 TAMPA ELECTRIC COMPANY 1050233 10 2 7242 **3 NOX 12105 TAMPA ELECTRIC COMPANY 1050233 10 2 7242 **3 SO2 12105 TAMPA ELECTRIC COMPANY 1050233 13 1 7242 **4 NOX 12105 TAMPA ELECTRIC COMPANY 1050233 13 1 7242 **4 SO2 12105 TAMPA ELECTRIC COMPANY 1050233 14 1 7242 **5 NOX 12105 TAMPA ELECTRIC COMPANY 1050233 14 1 7242 **5 SO2 12105 TAMPA ELECTRIC COMPANY 1050233 9 1 7242 **2 NOX 12105 TAMPA ELECTRIC COMPANY 1050233 9 1 7242 **2 SO2 12107 FLORIDA POWER & LIGHT (PPN) 1070014 3 1 6246 HRSG11 NOX 12107 FLORIDA POWER & LIGHT (PPN) 1070014 3 1 6246 HRSG11 SO2 12107 FLORIDA POWER & LIGHT (PPN) 1070014 3 2 6246 HRSG11 NOX 12107 FLORIDA POWER & LIGHT (PPN) 1070014 3 2 6246 HRSG11 SO2 12107 FLORIDA POWER & LIGHT (PPN) 1070014 4 1 6246 HRSG12 NOX 12107 FLORIDA POWER & LIGHT (PPN) 1070014 4 1 6246 HRSG12 SO2 12107 FLORIDA POWER & LIGHT (PPN) 1070014 4 2 6246 HRSG12 NOX 12107 FLORIDA POWER & LIGHT (PPN) 1070014 4 2 6246 HRSG12 SO2 WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12107 FLORIDA POWER & LIGHT (PPN) 1070014 5 1 6246 HRSG21 NOX 12107 FLORIDA POWER & LIGHT (PPN) 1070014 5 1 6246 HRSG21 SO2 12107 FLORIDA POWER & LIGHT (PPN) 1070014 5 2 6246 HRSG21 NOX 12107 FLORIDA POWER & LIGHT (PPN) 1070014 5 2 6246 HRSG21 SO2 12107 FLORIDA POWER & LIGHT (PPN) 1070014 6 1 6246 HRSG22 NOX 12107 FLORIDA POWER & LIGHT (PPN) 1070014 6 1 6246 HRSG22 SO2 12107 FLORIDA POWER & LIGHT (PPN) 1070014 6 2 6246 HRSG22 NOX 12107 FLORIDA POWER & LIGHT (PPN) 1070014 6 2 6246 HRSG22 SO2 12107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 1 136 1 NOX 12107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 1 136 1 SO2 12107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 2 136 1 NOX 812107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 2 136 1 SO2 912107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 3 136 1 NOX 12107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 3 136 1 SO2 12107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 1 136 2 NOX 12107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 1 136 2 SO2 12107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 2 136 2 NOX 912107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 2 136 2 SO2 912107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 3 136 2 NOX 12107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 3 136 2 SO2 12111 FT PIERCE UTILITIES AUTHORITY 1110003 7 1 658 7 NOX 12111 FT PIERCE UTILITIES AUTHORITY 1110003 7 1 658 7 SO2 12111 FT PIERCE UTILITIES AUTHORITY 1110003 8 1 658 8 NOX 12111 FT PIERCE UTILITIES AUTHORITY 1110003 8 1 658 8 SO2 12113 SANTA ROSA ENERGY CENTER, LLC 1130168 1 1 55242 CT-1 NOX 12113 SANTA ROSA ENERGY CENTER, LLC 1130168 1 1 55242 CT-1 SO2 12121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 1 3 638 1 NOX 12121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 1 3 638 1 SO2 12121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 2 3 638 2 NOX 12121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 2 3 638 2 SO2 12121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 3 3 638 3 NOX 12121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 3 3 638 3 SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 1 2 620 PSN3 NOX WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12127 FLORIDA POWER & LIGHT (PSN) 1270009 1 2 620 PSN3 SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 1 3 620 PSN3 NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 1 3 620 PSN3 SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 1 5 620 PSN3 NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 1 5 620 PSN3 SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 10 1 620 SNCT4A NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 10 1 620 SNCT4A SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 11 1 620 SNCT4B NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 11 1 620 SNCT4B SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 12 1 620 SNCT4C NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 12 1 620 SNCT4C SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 13 1 620 SNCT4D NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 13 1 620 SNCT4D SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 14 1 620 SNCT5A NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 14 1 620 SNCT5A SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 15 1 620 SNCT5B NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 15 1 620 SNCT5B SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 16 1 620 SNCT5C NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 16 1 620 SNCT5C SO2 12127 FLORIDA POWER & LIGHT (PSN) 1270009 17 1 620 SNCT5D NOX 12127 FLORIDA POWER & LIGHT (PSN) 1270009 17 1 620 SNCT5D SO2 12127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 15 1 6046 **7 NOX 12127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 15 1 6046 **7 SO2 12127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 16 1 6046 **8 NOX 12127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 16 1 6046 **8 SO2 12127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 17 1 6046 **9 NOX 12127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 17 1 6046 **9 SO2 12127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 18 1 6046 **10 NOX 12127 FLORIDA POWER CORPORATION D/B/A PROGRESS 1270028 18 1 6046 **10 SO2 12129 TALLAHASSEE CITY PURDOM GENERATING STA. 1290001 14 2 689 8 NOX 12129 TALLAHASSEE CITY PURDOM GENERATING STA. 1290001 14 2 689 8 SO2 12129 TALLAHASSEE CITY PURDOM GENERATING STA. 1290001 14 3 689 8 NOX 12129 TALLAHASSEE CITY PURDOM GENERATING STA. 1290001 14 3 689 8 SO2 WV SIP Revision: Regional Haze 5-Year Periodic Report 
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12129 TALLAHASSEE CITY PURDOM GENERATING STA. 1290001 7 1 689 7 NOX 12129 TALLAHASSEE CITY PURDOM GENERATING STA. 1290001 7 1 689 7 SO2 1.9.8.4 Georgia 

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13015 Ga Power Company - Plant Bowen 01500011 S1 1 703 1BLR NOX 3,551.5613015 Ga Power Company - Plant Bowen 01500011 S2 1 703 2BLR NOX 4,843.6213015 Ga Power Company - Plant Bowen 01500011 S3 1 703 3BLR NOX 5,702.3213015 Ga Power Company - Plant Bowen 01500011 S4 1 703 4BLR NOX 4,357.2013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 1 NOX 1,149.0013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 2 NOX 1,033.9413051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 2 SO2 1,878.7713051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 3 NOX 2,049.3013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 3 SO2 3,622.6613051 Ga Power Company - Plant Kraft 05100006 CS1 2 733 4 NOX 80.5713051 Ga Power Company - Plant Kraft 05100006 CS1 2 733 4 SO2 124.1713067 Ga Power Company - Plant McDonough/Atkinson 06700003 ST1M 1 710 MB1 NOX 2,257.2013067 Ga Power Company - Plant McDonough/Atkinson 06700003 ST1M 1 710 MB1 SO2 13,983.3413067 Ga Power Company - Plant McDonough/Atkinson 06700003 ST1M 1 710 MB2 SO2 14,554.9213077 Ga Power Company - Plant Yates 07700001 ST1 1 728 Y2BR NOX 1,528.4613077 Ga Power Company - Plant Yates 07700001 ST1A 1 728 Y1BR NOX 1,426.7113077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y4BR NOX 1,612.0013077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y4BR SO2 9,213.6513077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y5BR NOX 1,432.3713077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y5BR SO2 8,636.7813095 Ga Power Company - Plant Mitchell 09500002 ST3 1 727 3 NOX 1,985.0713103 Effingham County Power, LLC 10300012 S2 CTG2 55406 2 NOX 42.4813103 Ga Power Co Plt Mcintosh 10300003 S1 1 6124 1 NOX 2,092.3913115 Ga Power Company - Plant Hammond 11500003 ST2 1 708 4 NOX 4,176.1813127 Ga Power Company - Plant McManus 12700004 ST01 2 715 1 NOX 18.4813127 Ga Power Company - Plant McManus 12700004 ST01 2 715 2 NOX 27.5113149 Ga Power Company - Plant Wansley 14900001 ST01 1 6052 1 NOX 5,831.9813149 Ga Power Company - Plant Wansley 14900001 ST02 1 6052 2 NOX 8,026.36

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13149 Ga Power Company - Plant Wansley 14900001 ST04 1 6052 6A NOX 37.9513149 Ga Power Company - Plant Wansley 14900001 ST05 1 6052 6B NOX 34.9013149 Ga Power Company - Plant Wansley 14900001 ST06 1 6052 7A NOX 39.0813149 Ga Power Company - Plant Wansley 14900001 ST07 1 6052 7B NOX 40.7113207 Ga Power Company - Plant Scherer 20700008 ST2 1 6257 2 NOX 4,670.3113207 Ga Power Company - Plant Scherer 20700008 ST4 1 6257 4 NOX 4,672.1013237 Ga Power Company - Plant Branch 23700008 ST1 1 709 1 NOX 4,161.1413237 Ga Power Company - Plant Branch 23700008 ST1 1 709 1 SO2 17,707.5913237 Ga Power Company - Plant Branch 23700008 ST1 1 709 2 NOX 4,561.6713237 Ga Power Company - Plant Branch 23700008 ST1 1 709 2 SO2 19,404.3813237 Ga Power Company - Plant Branch 23700008 ST2 1 709 3 SO2 28,422.5513237 Ga Power Company - Plant Branch 23700008 ST2 1 709 4 NOX 6,559.2613237 Ga Power Company - Plant Branch 23700008 ST2 1 709 4 SO2 32,828.1913297 DOYLE GENERATING FACILITY 29700041 41 1 55244 CTG-5 NOX 6.43

1.9.8.5 Kentucky 

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21049 East Ky Power Coop 00003 001 1 1385 1 NOX 473.78521049 East Ky Power Coop 00003 001 1 1385 1 SO2 1,097.57921049 East Ky Power Coop 00003 002 1 1385 2 NOX 482.67421049 East Ky Power Coop 00003 002 1 1385 2 SO2 1,094.58921049 East Ky Power Coop 00003 003 1 1385 3 SO2 2,563.17721127 Kentucky Power Co-Big Sandy Plant 00003 01 1 1353 BSU1 NOX 3,393.82621127 Kentucky Power Co-Big Sandy Plant 00003 01 1 1353 BSU1 SO2 10,636.32421127 Kentucky Power Co-Big Sandy Plant 00003 01 2 1353 BSU1 NOX 0.90821127 Kentucky Power Co-Big Sandy Plant 00003 01 2 1353 BSU1 SO2 0.50021127 Kentucky Power Co-Big Sandy Plant 00003 02 1 1353 BSU2 NOX 11,585.03421127 Kentucky Power Co-Big Sandy Plant 00003 02 1 1353 BSU2 SO2 36,112.38721127 Kentucky Power Co-Big Sandy Plant 00003 02 2 1353 BSU2 NOX 3.13621127 Kentucky Power Co-Big Sandy Plant 00003 02 2 1353 BSU2 SO2 1.72521167 KY Utilities Co - Brown Station 00001 023-29 10 1355 9 NOX 3.78721167 KY Utilities Co - Brown Station 00001 023-29 11 1355 9 NOX 6.19621167 KY Utilities Co - Brown Station 00001 023-29 12 1355 10 NOX 6.268

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21167 KY Utilities Co - Brown Station 00001 023-29 13 1355 10 NOX 0.78321167 KY Utilities Co - Brown Station 00001 023-29 14 1355 11 NOX 4.06421167 KY Utilities Co - Brown Station 00001 023-29 2 1355 5 NOX 10.92321167 KY Utilities Co - Brown Station 00001 023-29 3 1355 5 NOX 0.0121167 KY Utilities Co - Brown Station 00001 023-29 4 1355 6 NOX 19.89421167 KY Utilities Co - Brown Station 00001 023-29 5 1355 6 NOX 0.0621167 KY Utilities Co - Brown Station 00001 023-29 6 1355 7 NOX 71.18021167 KY Utilities Co - Brown Station 00001 023-29 7 1355 7 NOX 0.93921167 KY Utilities Co - Brown Station 00001 023-29 8 1355 8 NOX 19.34621167 KY Utilities Co - Brown Station 00001 023-29 9 1355 8 NOX 0.20821177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 1 1378 1 SO2 11,733.63721177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 2 1378 1 SO2 2.9621177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 3 1378 1 SO2 460.58521177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 4 1378 1 SO2 0.06221177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 5 1378 1 SO2 0.07721177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 1 1378 2 SO2 17,824.13321177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 2 1378 2 SO2 4.49821177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 3 1378 2 SO2 699.65821177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 4 1378 2 SO2 0.10721177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 1 1378 3 SO2 3,761.21221177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 2 1378 3 SO2 0.94921177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 3 1378 3 SO2 147.64021177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 4 1378 3 SO2 0.0521177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 5 1378 3 SO2 0.02421183 Western KY Energy Corp - Wilson Station 00069 EU-01 1 6823 W1 NOX 6,598.15821199 East Ky Power Coop 00005 001 1 1384 1 NOX 765.92521199 East Ky Power Coop 00005 001 1 1384 1 SO2 3,495.66521199 East Ky Power Coop 00005 001 2 1384 1 NOX 777.20321199 East Ky Power Coop 00005 001 2 1384 1 SO2 3,242.4421199 East Ky Power Coop 00005 002 1 1384 2 NOX 1,973.13821199 East Ky Power Coop 00005 002 1 1384 2 SO2 8,877.37421199 East Ky Power Coop 00005 002 2 1384 2 NOX 1,022.56021199 East Ky Power Coop 00005 002 2 1384 2 SO2 4,205.428

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Facility Name 

Facility ID 

Point ID 

Process ID orisid blrid6 

Pollutant Code Emissio

21233 Western KY Energy Corp - Green Station 00052 EU01G1 1 6639 G1 NOX 2,650.90221233 Western KY Energy Corp - Green Station 00052 EU02G2 1 6639 G2 NOX 2,906.24721233 Western KY Energy Corp - Reid HMP&L Station 2 00001 EU01 1 1383 R1 SO2 6,735.59421233 Western KY Energy Corp - Reid HMP&L Station 2 00001 EU02 1 1382 H1 SO2 1,786.96621233 Western KY Energy Corp - Reid HMP&L Station 2 00001 EU03 1 1382 H2 SO2 1,901.457

1.9.8.6 Kentucky – Jefferson County No issues identified. 1.9.8.7 Mississippi No changes requested by State. 1.9.8.8 North Carolina 

County FIPS 

Facility Name 

Facility ID 

Point ID 

Process ID orisid blrid6 

PollutCode 

37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 1 S-1 2727 1 NOX 37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 1 S-1 2727 1 SO2 37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 2 S-2 2727 2 NOX 37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 2 S-2 2727 2 SO2 37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 3 S-3 2727 3 NOX 37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 3 S-3 2727 3 SO2 37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 4 S-4 2727 4 NOX 37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 4 S-4 2727 4 SO2 37071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 10 S-8 2732 10 NOX 37071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 10 S-8 2732 10 SO2 37071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 7 S-5 2732 7 NOX 37071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 7 S-5 2732 7 SO2 37071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 8 S-6 2732 8 NOX 37071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 8 S-6 2732 8 SO2 37071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 9 S-7 2732 9 NOX 37071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 9 S-7 2732 9 SO2 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES1 S-1 2718 1 NOX 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES1 S-1 2718 1 SO2 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES2 S-2 2718 2 NOX 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES2 S-2 2718 2 SO2 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES3 S-3 2718 3 NOX 

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County FIPS 

Facility Name 

Facility ID 

Point ID 

Process ID orisid blrid6 

PollutCode 

37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES3 S-3 2718 3 SO2 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES4 S-4 2718 4 NOX 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES4 S-4 2718 4 SO2 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES5 S-5 2718 5 NOX 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES5 S-5 2718 5 SO2 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES6 S-7 2718 1 NOX 37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES6 S-7 2718 1 SO2 37129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT 1 S-1 2713 1 NOX 37129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT 1 S-1 2713 1 SO2 37129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT 1 S-1 2713 2 NOX 37129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT 1 S-1 2713 2 SO2 37145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1A NOX 37145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1A SO2 37145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1B NOX 37145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1B SO2 37145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3A NOX 37145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3A SO2 37145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3B NOX 37145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3B SO2 37145 Progress Energy - Roxboro Plant 3714500029 EP4 S-4 2712 4B NOX 37145 Progress Energy - Roxboro Plant 3714500029 EP4 S-4 2712 4B SO2 37145 Progress Energy - Roxboro Plant 3714500029 EP4 S-999 2712 4B NOX 37145 Progress Energy - Roxboro Plant 3714500029 EP4 S-999 2712 4B SO2 37145 Progress Energy - Roxboro Plant 3714500029 EP4a S-14 2712 4A NOX 37145 Progress Energy - Roxboro Plant 3714500029 EP4a S-14 2712 4A SO2 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP2 S-2 2723 2 SO2 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3A S-3 2723 3 NOX 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3A S-3 2723 3 SO2 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3B S-4 2723 3 NOX 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3B S-4 2723 3 SO2 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP5 S-6 2723 1 NOX 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP6 S-7 2723 1 NOX 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP6 S-7 2723 1 SO2 

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Facility Name 

Facility ID 

Point ID 

Process ID orisid blrid6 

PollutCode 

37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP9 S-10 2723 1 NOX 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP9 S-10 2723 1 SO2 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 F-1 S-14 2723 2 NOX 37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 F-1 S-14 2723 2 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-11 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-11 55116 CT5 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-999 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-999 55116 CT5 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-12 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-12 55116 CT5 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-999a 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-999a 55116 CT5 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-13 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-13 55116 CT5 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-999b 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-999b 55116 CT5 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-14 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-14 55116 CT5 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-999c 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-999c 55116 CT5 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-15 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-15 55116 CT5 SO2 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-999d 55116 CT5 NOX 37157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-999d 55116 CT5 SO2 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES5 S-2 2720 5 NOX 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES5 S-2 2720 5 SO2 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES6 S-3 2720 6 NOX 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES6 S-3 2720 6 SO2 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 7 NOX 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 7 SO2 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 8 NOX 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 8 SO2 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 9 NOX 

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Point ID 

Process ID orisid blrid6 

PollutCode 

37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 9 SO2 37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9C S-9 2720 5 NOX 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 1 S-1 2721 1 NOX 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 1 S-1 2721 1 SO2 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 2 S-2 2721 2 NOX 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 2 S-2 2721 2 SO2 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 3 S-3 2721 3 NOX 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 3 S-3 2721 3 SO2 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 4 S-4 2721 4 NOX 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 4 S-4 2721 4 SO2 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 1 NOX 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 1 SO2 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 5 NOX 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 5 SO2 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 Misc. S-10 2721 2 NOX 37161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 Misc. S-10 2721 2 SO2 37169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP1 S-1 8042 1 NOX 37169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP1 S-1 8042 1 SO2 37169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP2 S-2 8042 2 NOX 37169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP2 S-2 8042 2 SO2 37169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 F-1 S-12 8042 2 NOX 37169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 F-1 S-12 8042 2 SO2 

1.9.8.9 North Carolina – Buncombe County No affected facilities in the county. 1.9.8.10 North Carolina – Forsyth County No affected facilities in the county. 1.9.8.11 North Carolina – Mecklenburg County No affected facilities in the county. WV SIP Revision: Regional Haze 5-Year Periodic Report 
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1.9.8.12 South Carolina 

County FIPS 

Facility Name 

Facility ID 

Point ID 

Process ID orisid blrid6 

Pollutant Code Emissions 

45021 BROAD RIVER ENERGY LLC 0600-0076 1 1 55166 CT-1 NOX 37.4070 45021 BROAD RIVER ENERGY LLC 0600-0076 1 1 55166 CT-1 SO2 0.6130 45021 BROAD RIVER ENERGY LLC 0600-0076 2 3 55166 CT-2 NOX 27.9370 45021 BROAD RIVER ENERGY LLC 0600-0076 2 3 55166 CT-2 SO2 0.4210 45021 BROAD RIVER ENERGY LLC 0600-0076 3 5 55166 CT-3 NOX 43.5220 45021 BROAD RIVER ENERGY LLC 0600-0076 3 5 55166 CT-3 SO2 0.6590 45021 CHEROKEE COGENERATION 0600-0060 1 1 55043 CCCP1 NOX 26.8170 45021 CHEROKEE COGENERATION 0600-0060 1 1 55043 CCCP1 SO2 0.5540 45053 SCE&G JASPER 1360-0026 1 1 55927 CT01 NOX 30.4640 45053 SCE&G JASPER 1360-0026 1 1 55927 CT01 SO2 1.5710 45053 SCE&G JASPER 1360-0026 2 1 55927 CT02 NOX 37.6330 45053 SCE&G JASPER 1360-0026 2 1 55927 CT02 SO2 2.2380 45053 SCE&G JASPER 1360-0026 3 1 55927 CT03 NOX 33.1860 45053 SCE&G JASPER 1360-0026 3 1 55927 CT03 SO2 1.6040 

1.9.8.13 Tennessee No affected facilities. 1.9.8.14 Tennessee – Davidson County (Nashville) No affected facilities in the county. 1.9.8.15 Tennessee – Hamilton County (Chattanooga) No affected facilities in the county. 1.9.8.16 Tennessee – Knox County (Knoxville) No affected facilities in the county. 1.9.8.17 Tennessee – Shelby County (Memphis) No issues identified. 1.9.8.18 Virginia No issues identified. 1.9.8.19 West Virginia No changes requested by State as a result of the CEMS review. West Virginia did submit revised records for 70 emiPM10-PRI and PM25-PRI. Those records were inserted into the database at the time that the other CEM related WV SIP Revision: Regional Haze 5-Year Periodic Report 
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1.9.8.20 Latitude/Longitude Changes 

Appendix A lists the State/County FIPS code, the State Facility ID, the Name of the Facility, the 

Emission Release point ID and the new Latitude and Longitude for those records that were replaced 

based on the quality assurance of latitude and longitude values performed by GA EPD staff as part 

of the Version 1.10a update. 

1.10 2007 POINT SOURCE EMISSION SUMMARY 

This section presents State-level summaries of the annual point source emissions by pollutant in the 

2007 SEMAP version 1.10a inventory and compares the emissions to the 2002 VISTAS Best and 

Final inventory. For most States and pollutants, point source emissions have decreased from 2002 

to 2007. 

Exhibit 7 shows that CO emissions in the SEMAP region have decreased by about 30 percent 

between 2002 and 2007. Exhibit 8 shows that most of the point source CO emissions (about 

81 percent) come from nonEGUs that are not required to report emissions to CAMD. 

Exhibit 9 shows that NH3 emissions in the SEMAP region have remained about the same in 2002 

and 2007, although NH3 emissions increased substantially in some States while decreasing in 

others. Exhibit 10 shows that most of the point source NH3 emissions (about 90 percent) come from 

nonEGUs that are not required to report emissions to CAMD. 

Exhibit 11 shows that NOx emissions have decreased by about 26 percent between 2002 and 2007. 

All States showed a decrease in NOx emissions from point sources. Exhibit 12 shows that about 69 

percent of the point source NOx emissions come from EGUs that are required to report emissions to 

CAMD. Another 28 percent of the NOx emissions result from nonEGUs that are not required to 

report emissions to CAMD. 

Exhibit 13 shows that PM10-PRI emissions in the SEMAP region have decreased by about 

7 percent between 2002 and 2007, although PM10-PRI emissions increased substantially in some 

States while decreasing in others. Exhibit 14 shows that about 46 percent of the point source PM10-

PRI emissions come from EGUs that are required to report emissions to CAMD. Another 53 percent 

of the PM10-PRI emissions result from nonEGUs that are not required to report emissions to CAMD. 

For PM, the emissions presented in Exhibit 13 show the values initially used for WV based on the 

data submitted as described in section 1.9.8.19. After modeling had already been conducted, WV 

indicated that they believed that the values used in version 1.9 of the inventory were actually correct 

and requested that the emissions be changed. Since modeling had already been performed, SEMAP 

decided to replace the data in the inventory files but did not perform new modeling runs. Appendix B 

shows the differences between the version 1.9 and version 1.10a inventories for the records that WV 

initially asked to be revised. 

Exhibit 15 shows that PM25-PRI emissions in the SEMAP region have decreased by about 

3 percent between 2002 and 2007, although PM25-PRI emissions increased substantially in some 

States while decreasing in others. Exhibit 16 shows that about 45 percent of the point source PM25-

PRI emissions come from EGUs that are required to report emissions to CAMD. Another 54 percent 

of the PM25-PRI emissions result from nonEGUs that are not required to report emissions to CAMD. 

Exhibit 17 shows that SO 

2 emissions in the SEMAP region have decreased by about 15 percent 

between 2002 and 2007. All States except Georgia showed a decrease in SO 

2 emissions. Exhibit 

18 shows that most of the point source SO 

2 emissions (about 87 percent) come from EGUs that are 

required to report emissions to CAMD. Another 11 percent of the SO 

2 emissions result from 

nonEGUs that are not required to report emissions to CAMD. 

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Exhibit 19 shows that VOC emissions in the SEMAP region have decreased by about 21 percent 

between 2002 and 2007. Exhibit 20 shows that nearly all of the point source VOC emissions (about 

97 percent) result from nonEGUs that are not required to report emissions to CAMD. 

The reasons for the differences between 2002 and 2007 are many and vary by State, facility, and 

pollutant. Examples include: 1) new controls added between 2002 and 2007; 2) change in emission 

factors or source test data; 3) inclusion of PM condensables that were not included in 2002; 4) more 

{or less} facilities in 2002 inventory than in 2007 inventory; 5) new sources that came online between 

2002 and 2007; 6) different fuels used in 2007 than in 2002; 7) industry specific economic growth or 

contraction between 2002 and 2007; 8) facility or emission unit closures; and 9) errors in 2002 

inventory. 

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Exhibit 7 – 2002 and 2007 Point Source CO Emissions by State (tons/year) 

STATE 2002 2007 Change 

Alabama 185,550 119,344 -36% 

Florida 139,045 111,280 -20% 

Georgia 140,561 82,547 -41% 

Kentucky 122,555 82,553 -33% 

Mississippi 59,871 40,294 -33% 

North Carolina 64,461 66,811 4% 

South Carolina 63,305 60,375 -5% 

Tennessee 122,348 51,185 -58% 

Virginia 70,688 72,029 2% 

West Virginia 100,220 65,230 -35% 

SEMAP 1,068,604 751,648 -30% 

Exhibit 8 – 2007 Point Source CO Emissions by Category (tons/year) 

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Exhibit 9 – 2002 and 2007 Point Source NH3 Emissions by State (tons/year) 

STATE 2002 2007 Change 

Alabama 2,200 2,191 0% 

Florida 1,657 1,661 0% 

Georgia 3,697 6,046 64% 

Kentucky 1,000 113 -89% 

Mississippi 1,359 1,640 21% 

North Carolina 1,234 1,707 38% 

South Carolina 1,553 1,125 -28% 

Tennessee 1,817 1,429 -21% 

Virginia 3,230 1,830 -43% 

West Virginia 453 366 -19% 

SEMAP 18,200 18,107 -1% 

Exhibit 10 – 2007 Point Source NH3 Emissions by Category (tons/year) 

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Exhibit 11 – 2002 and 2007 Point Source NOx Emissions by State (tons/year) 

STATE 2002 2007 Change 

Alabama 244,348 197,963 -19% 

Florida 302,834 237,473 -22% 

Georgia 196,767 154,041 -22% 

Kentucky 237,209 210,213 -11% 

Mississippi 104,661 98,183 -6% 

North Carolina 196,782 100,379 -49% 

South Carolina 130,394 81,220 -38% 

Tennessee 221,652 144,763 -35% 

Virginia 147,300 112,938 -23% 

West Virginia 277,589 188,629 -32% 

SEMAP 2,059,536 1,525,801 -26% 

Exhibit 12 – 2007 Point Source NOx Emissions by Category (tons/year) 

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Exhibit 13 – 2002 and 2007 Point Source PM10-PRI Emissions by State (tons/year) 

STATE 2002 2007 Change 

Alabama 32,886 34,776 6% 

Florida 57,243 35,796 -37% 

Georgia 32,834 33,214 1% 

Kentucky 21,326 30,678 44% 

Mississippi 21,106 12,368 -41% 

North Carolina 36,592 42,995 17% 

South Carolina 35,542 30,605 -14% 

Tennessee 49,814 27,874 -44% 

Virginia 17,211 19,203 12% 

West Virginia 22,076 35,457 61% 

SEMAP 326,630 302,966 -7% 

Exhibit 14 – 2007 Point Source PM10-PRI Emissions by Category (tons/year) 

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Exhibit 15 – 2002 and 2007 Point Source PM25-PRI Emissions by State (tons/year) 

STATE 2002 2007 Change 

Alabama 23,291 24,930 7% 

Florida 46,148 28,418 -38% 

Georgia 22,401 25,059 12% 

Kentucky 14,173 21,111 49% 

Mississippi 11,044 8,731 -21% 

North Carolina 26,998 33,444 24% 

South Carolina 27,399 23,493 -14% 

Tennessee 39,973 22,144 -45% 

Virginia 12,771 14,875 16% 

West Virginia 15,523 30,552 97% 

SEMAP 239,721 232,756 -3% 

Exhibit 16 – 2007 Point Source PM25-PRI Emissions by Category (tons/year) 

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Exhibit 17 – 2002 and 2007 Point Source SO2 Emissions by State (tons/year) 

STATE 2002 2007 Change 

Alabama 544,309 526,620 -3% 

Florida 518,721 379,590 -27% 

Georgia 568,731 683,358 20% 

Kentucky 518,086 410,414 -21% 

Mississippi 103,388 94,978 -8% 

North Carolina 522,113 420,438 -19% 

South Carolina 259,916 216,125 -17% 

Tennessee 413,755 287,668 -30% 

Virginia 305,106 243,048 -20% 

West Virginia 570,153 428,350 -25% 

SEMAP 4,324,278 3,690,588 -15% 

Exhibit 18 – 2007 Point Source SO2 Emissions by Category (tons/year) 

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Exhibit 19 – 2002 and 2007 Point Source VOC Emissions by State (tons/year) 

STATE 2002 2007 Change 

Alabama 49,332 38,877 -21% 

Florida 40,995 33,683 -18% 

Georgia 34,952 36,717 5% 

Kentucky 46,321 47,679 3% 

Mississippi 43,852 34,587 -21% 

North Carolina 62,170 48,349 -22% 

South Carolina 38,927 29,281 -25% 

Tennessee 85,254 48,103 -44% 

Virginia 43,906 35,618 -19% 

West Virginia 15,775 12,503 -21% 

SEMAP 461,484 365,397 -21% 

Exhibit 20 – 2007 Point Source VOC Emissions by Category (tons/year) 

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 929
Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc. 

AMEC Project No.: 6066-09-0326.02 January 18, 2012 

 79 AMEC 

1.11 DATA FILES 

These files are accessible on the MACTEC ftp site in the following location: 

Address: ftp.mactec.com 

Login ID: externalclient 

Password: sen382 

Folder: /Outgoing/SEMAP Point V_1_10 

NIF 3.0 ACCESS Database with the 8 NIF tables:

SEMAP 2007 Point NIF V_1_10a.zip 

Annual point source files in SMOKE ORL format are being prepared under SEMAP’s emission 

modeling contract. 

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 930
Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc. 

AMEC Project No.: 6066-09-0326.02 January 18, 2012 

 80 AMEC 

1.12 REFERENCES 

Dutch 2005. Steven Dutch, Natural and Applied Sciences, University of Wisconsin - Green Bay. 

Converting UTM to Latitude and Longitude (Or Vice Versa). Downloaded March 2009, last 

updated 19 April 2005. http://www.uwgb.edu/dutchs/UsefulData/UTMFormulas.HTM 

EPA 2004. U.S. Environmental Protection Agency. Basic Format and Content Checker. Version 

Date 052604. Software no longer available on EPA web site. 

EPA 2005. U.S. Environmental Protection Agency. Emissions Inventory Guidance for 

Implementation of Ozone and Particulate Matter National Ambient Air Quality Standards 

(NAAQS) and Regional Haze Regulations. EPA-454/R-05-001. August 2005. 

http://www.epa.gov/ttn/chief/eidocs/eiguid/eiguidfinal_nov2005.pdf 

EPA 2006a. U.S. Environmental Protection Agency. NEI Quality Assurance and Data 

Augmentation for Point Sources. February, 2006. . 

ftp://ftp.epa.gov/EmisInventory/2002finalnei/documentation/point/augmentation_point/20

02nei_qa_augmentation_report0206.pdf 

EPA 2006b. U.S. Environmental Protection Agency. 2002 NEI Stack Parameter Default. 

ftp://ftp.epa.gov/EmisInventory/2002finalnei/documentation/augmentation_point_sector/ .

EPA 2007. U.S. Environmental Protection Agency. Guidance on the Use of Models and Other 

Analyses for Demonstrating Attainment of Air Quality Goals for Ozone, PM2.5, and Regional 

Haze. EPA -454/B-07-002. April 2007. 

http://www.epa.gov/ttn/scram/guidance/guide/final-03-pm-rh-guidance.pdf 

EPA 2009a. U.S. Environmental Protection Agency. Clean Air Markets – Data and Maps Web Site; 

Unit Level Emissions Query for 2007. File downloaded on October 8, 2009. 

http://camddataandmaps.epa.gov/gdm/index.cfm?fuseaction=emissions.wizard 

EPA 2009b. U.S. Environmental Protection Agency. Clean Air Markets – Emissions Data in 

SMOKE Format for 2007. File (hour_unit_2007.zip) downloaded on October 8, 2009. 

http://camddataandmaps.epa.gov/gdm/index.cfm?fuseaction=emissions.prepacksmoke 

EPA 2009c. U.S. Environmental Protection Agency. 2005 National Emissions Inventory Data & 

Documentation. file name: 2005v4CAPHAP_orl_point.zip. June 2009. 

ftp://ftp.epa.gov/EmisInventory/2005v4/2005emis

MARAMA 2006. Mid-Atlantic Regional Air Management Association. Technical Support 

Documentation for 2002 MANE-VU SIP Modeling Inventories, Version 3. November 20, 

2006. http://www.marama.org/technical-center/emissions-inventory/2002-inventory-andprojections/mane-vu-2002-emissions-inventory 

SESARM 2009. Southeastern States Air Resource Managers, Inc. Point Source, On-Road, and 

Fire Base Year, Future Year, and Control Strategy Emissions Inventories – Quality 

Assurance Project Plan. August 2009. 

VISTAS 2007. Visibility Improvement State and Tribal Association of the Southeast. Documentation 

of the Base G 2002 Base Year, 2009, and 2018 Emission Inventories for the Visibility 

Improvement State and Tribal Association of the Southeast. February 2007. 

http://www.vistas-sesarm.org/documents/VISTABF2003-20-2008.pdf 

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 931
Appendix A: Facilities with Updated Latitude and Longitude Information 

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 932
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

1-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

01007 0001 Alabama Pigments Co 001 -87.127001007 0001 Alabama Pigments Co 002 -87.127001007 0001 Alabama Pigments Co 888 -87.127001015 0088 SOUTHERN HERITAGE CASKET COMPANY, INC. 001 -85.930801043 0010 American Proteins Inc 002 -86.809501043 0010 American Proteins Inc 005 -86.809501043 0010 American Proteins Inc 006 -86.809501043 0010 American Proteins Inc 007 -86.809501043 0010 American Proteins Inc 010 -86.809501043 0010 American Proteins Inc 011 -86.809501043 0010 American Proteins Inc 888 -86.809501073 010730078 CLUTCH & BRAKE SPECIALTY CO., INC. 002 -86.786401073 010730167 ERGON TERMINALLING, INC. 004 -87.107901073 010730339 SHELBY CONCRETE, INC. 001 -86.81301073 010730503 LAFARGE BUILDING MATERIALS, BIRMINGHAM PLANT 001 -86.813201093 0014 Glen Allen Rail Inc 002 -87.748501093 0014 Glen Allen Rail Inc 888 -87.748501093 0023 King Kutter Inc 001 -87.820301095 0046 Jackson Paving & Construction Company 888 -86.232901097 0010 ExxonMobil Production Company 001 -88.052201097 0010 ExxonMobil Production Company 002 -88.052201097 0010 ExxonMobil Production Company 003 -88.052201097 0010 ExxonMobil Production Company 004 -88.052201097 0010 ExxonMobil Production Company 005 -88.052201097 0010 ExxonMobil Production Company 006 -88.052201097 0010 ExxonMobil Production Company 007 -88.052201097 0010 ExxonMobil Production Company 008 -88.052201097 0010 ExxonMobil Production Company 010 -88.052201097 0010 ExxonMobil Production Company 011 -88.052201097 0010 ExxonMobil Production Company 012 -88.0522

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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2-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

01097 0010 ExxonMobil Production Company 013 -88.052201097 0010 ExxonMobil Production Company 015 -88.052201097 0010 ExxonMobil Production Company 016 -88.052201097 0010 ExxonMobil Production Company 017 -88.052201097 0010 ExxonMobil Production Company 018 -88.052201097 0010 ExxonMobil Production Company 019 -88.052201097 0010 ExxonMobil Production Company 020 -88.052201097 0010 ExxonMobil Production Company 021 -88.052201097 0010 ExxonMobil Production Company 022 -88.052201097 0010 ExxonMobil Production Company 023 -88.052201097 0010 ExxonMobil Production Company 888 -88.052201097 0012 ExxonMobil Production Company 001 -88.044701097 0012 ExxonMobil Production Company 002 -88.044701097 0012 ExxonMobil Production Company 003 -88.044701097 0012 ExxonMobil Production Company 004 -88.044701097 0012 ExxonMobil Production Company 005 -88.044701097 0012 ExxonMobil Production Company 006 -88.044701097 0012 ExxonMobil Production Company 007 -88.044701097 0012 ExxonMobil Production Company 008 -88.044701097 0012 ExxonMobil Production Company 009 -88.044701097 0013 ExxonMobil Production Company 001 -88.124801097 0013 ExxonMobil Production Company 002 -88.124801097 0013 ExxonMobil Production Company 003 -88.124801097 0013 ExxonMobil Production Company 004 -88.124801097 0013 ExxonMobil Production Company 005 -88.124801097 0013 ExxonMobil Production Company 006 -88.124801097 0013 ExxonMobil Production Company 007 -88.124801097 0013 ExxonMobil Production Company 009 -88.124801097 0013 ExxonMobil Production Company 888 -88.124801097 0016 Shell Exploration & Production Company 001 -88.0773

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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3-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

01097 0016 Shell Exploration & Production Company 002 -88.077301097 0016 Shell Exploration & Production Company 004 -88.077301097 0016 Shell Exploration & Production Company 005 -88.077301097 0016 Shell Exploration & Production Company 006 -88.077301097 0016 Shell Exploration & Production Company 007 -88.077301097 0025 ExxonMobil Production Company 001 -87.952501097 0025 ExxonMobil Production Company 002 -87.952501097 0025 ExxonMobil Production Company 003 -87.952501097 0025 ExxonMobil Production Company 004 -87.952501097 0025 ExxonMobil Production Company 005 -87.952501097 0025 ExxonMobil Production Company 006 -87.952501097 0025 ExxonMobil Production Company 007 -87.952501097 0025 ExxonMobil Production Company 888 -87.952501097 0038 Mobile Abrasives 003 -88.031701097 0038 Mobile Abrasives 888 -88.031701097 2002 Armstrong World Industries Inc 001 -88.05801097 2002 Armstrong World Industries Inc 002 -88.05801097 2002 Armstrong World Industries Inc 003 -88.05801097 2002 Armstrong World Industries Inc 004 -88.05801097 2002 Armstrong World Industries Inc 005 -88.05801097 2002 Armstrong World Industries Inc 006 -88.05801097 2002 Armstrong World Industries Inc 007 -88.05801097 2002 Armstrong World Industries Inc 008 -88.05801097 2002 Armstrong World Industries Inc 009 -88.05801097 2002 Armstrong World Industries Inc 010 -88.05801097 2002 Armstrong World Industries Inc 011 -88.05801097 2002 Armstrong World Industries Inc 013 -88.05801097 2002 Armstrong World Industries Inc 014 -88.05801097 4019 MoBay Storage Hub, Inc 001 -88.225501097 4019 MoBay Storage Hub, Inc 002 -88.2255

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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4-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

01097 4019 MoBay Storage Hub, Inc 003 -88.225501097 6002 Bender Shipbuilding & Repair Co Inc 888 -88.0401097 6007 Alabama Shipyards Inc 001 -88.032501099 S011 Owens Lumber Company 001 -86.981501113 0018 Boral Bricks 001 -84.998201113 0018 Boral Bricks 002 -84.998201113 0018 Boral Bricks 003 -84.998201113 0018 Boral Bricks 005 -84.998201113 0018 Boral Bricks 006 -84.998201113 0018 Boral Bricks 007 -84.998201113 0018 Boral Bricks 888 -84.998201117 0005 Alabama Power Company 001 -86.459801117 0005 Alabama Power Company 002 -86.45701117 0005 Alabama Power Company 004 -86.45701117 0005 Alabama Power Company 888 -86.459801123 0015 Stone's Throw Landfill 888 -85.831501127 0015 S&M Paving Co. 001 -87.609512009 0090051 NASA 69 -80.6512031 0310010 BAPTIST MEDICAL CENTER 14 -81.663712031 0310213 U S NAVAL STATION MAYPORT 33 -81.406312031 0310213 U S NAVAL STATION MAYPORT 34 -81.417512031 0310213 U S NAVAL STATION MAYPORT 37 -81.417512031 0310325 TRANSFLO TERMINAL SERVICES, INC. 1 -81.720012045 0450002 ARIZONA CHEMICAL COMPANY, LLC 13 -85.308312045 0450002 ARIZONA CHEMICAL COMPANY, LLC 15 -85.308312045 0450002 ARIZONA CHEMICAL COMPANY, LLC 16 -85.308312045 0450002 ARIZONA CHEMICAL COMPANY, LLC 17 -85.308312045 0450002 ARIZONA CHEMICAL COMPANY, LLC 5 -85.308312045 0450002 ARIZONA CHEMICAL COMPANY, LLC 6 -85.308312057 0570094 MOSAIC FERTILIZER, LLC 100 -82.407

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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5-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

12057 0570252 CEMEX 2 -82.432512057 0570252 CEMEX 4 -82.432512069 0694822 MIDDLESEX ASPHALT, L.L.C. 2 -81.903812099 0990350 SOUTH FLORIDA WATER MANAGEMENT DISTRICT 1 -80.445712103 1030011 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 5 -82.601612103 1030011 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 6 -82.601612103 1030011 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 7 -82.601612103 1030011 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 8 -82.601612109 1090022 LUHRS CORPORATION 1 -81.321912113 1130040 ODOM FIBERGLASS, INCORPORATED 1 -87.087213015 01500011 Ga Power Company - Plant Bowen S1 -84.913015 01500011 Ga Power Company - Plant Bowen S2 -84.913015 01500011 Ga Power Company - Plant Bowen S3 -84.913015 01500011 Ga Power Company - Plant Bowen S4 -84.913015 01500011 Ga Power Company - Plant Bowen SCT1 -84.913015 01500011 Ga Power Company - Plant Bowen SCT2 -84.913039 03900003 Naval Submarine Base PT01 -81.55313039 03900003 Naval Submarine Base PT02 -81.55313039 03900003 Naval Submarine Base PT03 -81.55313039 03900003 Naval Submarine Base PT04 -81.55313039 03900003 Naval Submarine Base PT05 -81.55313039 03900003 Naval Submarine Base PT06 -81.55313039 03900003 Naval Submarine Base PT07 -81.55313039 03900003 Naval Submarine Base PT08 -81.55313039 03900003 Naval Submarine Base PT09 -81.55313039 03900003 Naval Submarine Base PT10 -81.55313039 03900003 Naval Submarine Base PT11 -81.55313039 03900003 Naval Submarine Base PT12 -81.55313039 03900003 Naval Submarine Base PT13 -81.55313039 03900003 Naval Submarine Base PT14 -81.553

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

13039 03900003 Naval Submarine Base PT15 -81.55313039 03900003 Naval Submarine Base PT16 -81.55313045 04500052 Southwire Company Carrollton Utility Products Plant F722 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN11 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN12 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN13 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN15 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN16 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN17 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN18 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN2 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN3 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN4 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN5 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN6 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant FAN7 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S205 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S280 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S281 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S296 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S297 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S501 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S504 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S507 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S510 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S513 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S516 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S721 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S745 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant S760 -85.0622

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

13045 04500052 Southwire Company Carrollton Utility Products Plant S761 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant SCS12 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant SCS13 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant SCS14 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant SCS5 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant SCS6 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant SCS7 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant SCS8 -85.062213045 04500052 Southwire Company Carrollton Utility Products Plant SCS9 -85.062213049 04900004 West Fraser - Folkston Lumber Mill FOB1 -82.013049 04900004 West Fraser - Folkston Lumber Mill FOB2 -82.013051 05100076 Colonial Terminals, Inc. SB01 -81.11213051 05100076 Colonial Terminals, Inc. SB02 -81.11213051 05100076 Colonial Terminals, Inc. SB03 -81.11213051 05100076 Colonial Terminals, Inc. SD01 -81.11213051 05100076 Colonial Terminals, Inc. SD02 -81.11213051 05100076 Colonial Terminals, Inc. SD03 -81.11213051 05100076 Colonial Terminals, Inc. SD04 -81.11213051 05100076 Colonial Terminals, Inc. SD22 -81.11213051 05100076 Colonial Terminals, Inc. SD91 -81.11213051 05100076 Colonial Terminals, Inc. SM01 -81.11213051 05100076 Colonial Terminals, Inc. SR21 -81.11213051 05100076 Colonial Terminals, Inc. SR22 -81.11213051 05100076 Colonial Terminals, Inc. ST01 -81.11213051 05100076 Colonial Terminals, Inc. ST02 -81.11213051 05100076 Colonial Terminals, Inc. ST03 -81.11213051 05100076 Colonial Terminals, Inc. ST04 -81.11213051 05100076 Colonial Terminals, Inc. ST05 -81.11213051 05100076 Colonial Terminals, Inc. ST06 -81.11213051 05100076 Colonial Terminals, Inc. ST12 -81.112

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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Code

State Fac 

ID Facility Name Release Point ID Long 

13051 05100076 Colonial Terminals, Inc. ST13 -81.11213051 05100076 Colonial Terminals, Inc. SVR4 -81.11213051 05100076 Colonial Terminals, Inc. SVR9 -81.11213051 05100148 ARIZONA CHEMICAL CORP. S1 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S10 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S11 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S12 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S13 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S14 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S2 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S3 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S4 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S5 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S6 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S7 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S8 -81.12213051 05100148 ARIZONA CHEMICAL CORP. S9 -81.12213051 05100152 Savannah Resource Recovery (Montaney) ST01 -81.02713051 05100152 Savannah Resource Recovery (Montaney) ST02 -81.02713063 06300059 Delta Air Lines Inc - Atlanta Station FUG -84.413063 06300059 Delta Air Lines Inc - Atlanta Station S1 -84.413063 06300059 Delta Air Lines Inc - Atlanta Station S2 -84.413063 06300059 Delta Air Lines Inc - Atlanta Station S3 -84.413065 06500005 Bway Manufacturing Inc S0 -82.77313065 06500005 Bway Manufacturing Inc S1 -82.77313065 06500005 Bway Manufacturing Inc S13 -82.77313065 06500005 Bway Manufacturing Inc S15 -82.77313065 06500005 Bway Manufacturing Inc S16 -82.77313065 06500005 Bway Manufacturing Inc S2 -82.77313065 06500005 Bway Manufacturing Inc S20 -82.773

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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Code

State Fac 

ID Facility Name Release Point ID Long 

13065 06500005 Bway Manufacturing Inc S3 -82.77313065 06500005 Bway Manufacturing Inc S9 -82.77313067 06700032 Marathon Petroleum Company LLC - Powder Springs Terminal FUG -84.63013067 06700032 Marathon Petroleum Company LLC - Powder Springs Terminal VCS -84.63013073 07300003 Quebecor World Kri Inc. FUG -82.11713073 07300003 Quebecor World Kri Inc. S1 -82.11713073 07300003 Quebecor World Kri Inc. S10 -82.11713073 07300003 Quebecor World Kri Inc. S11 -82.11713073 07300003 Quebecor World Kri Inc. S12 -82.11713081 08100054 Norbord Georgia Inc S001 -83.80213081 08100054 Norbord Georgia Inc S003 -83.80213081 08100054 Norbord Georgia Inc S004 -83.80213081 08100054 Norbord Georgia Inc S010 -83.80213081 08100054 Norbord Georgia Inc S011 -83.80213081 08100054 Norbord Georgia Inc S012 -83.80213081 08100054 Norbord Georgia Inc S013 -83.80213081 08100054 Norbord Georgia Inc S063 -83.80213089 08900085 Magellan Terminal Holdings, L.P. - Doraville I Terminal FUG -84.269913089 08900085 Magellan Terminal Holdings, L.P. - Doraville I Terminal S1 -84.269913089 08900128 Transmontaigne Terminaling Inc CGLK -84.273913089 08900128 Transmontaigne Terminaling Inc FUG -84.273913089 08900128 Transmontaigne Terminaling Inc ST8501 -84.273913089 08900128 Transmontaigne Terminaling Inc ST8502 -84.273913089 08900128 Transmontaigne Terminaling Inc ST8504 -84.273913089 08900128 Transmontaigne Terminaling Inc ST8505 -84.273913089 08900128 Transmontaigne Terminaling Inc ST8506 -84.273913089 08900128 Transmontaigne Terminaling Inc ST8507 -84.273913089 08900128 Transmontaigne Terminaling Inc ST8509 -84.273913089 08900128 Transmontaigne Terminaling Inc ST8510 -84.273913089 08900128 Transmontaigne Terminaling Inc ST8515 -84.2739

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Code

State Fac 

ID Facility Name Release Point ID Long 

13089 08900128 Transmontaigne Terminaling Inc ST8516 -84.273913089 08900128 Transmontaigne Terminaling Inc STLOAD -84.273913089 08900128 Transmontaigne Terminaling Inc STVCU -84.273913089 08900128 Transmontaigne Terminaling Inc STVRU -84.273913095 09500010 MillerCoors LLC F036 -84.08813095 09500010 MillerCoors LLC S001 -84.08813095 09500010 MillerCoors LLC S003 -84.08813095 09500010 MillerCoors LLC S034 -84.08813099 09900001 Georgia-Pacific Corp Cedar Springs Operation FUG -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation INSIG -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S1 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S10 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S11 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S12 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S13 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S14 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S15 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S16 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S17 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S18 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S19 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S2 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S20 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S21 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S22 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S23 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S24 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S25 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S26 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S27 -85.0954

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State Fac 

ID Facility Name Release Point ID Long 

13099 09900001 Georgia-Pacific Corp Cedar Springs Operation S28 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S29 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S3 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S5 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S6 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S7 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S8 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation S9 -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation VSTACK -85.095413099 09900001 Georgia-Pacific Corp Cedar Springs Operation WTS -85.095413103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) FUG -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S1 -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S10 -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S11 -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S12 -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S2 -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S3 -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S4 -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S6 -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S8 -81.2013103 10300007 Georgia-Pacific Consumer Products Lp (Savannah River Mill) S9 -81.2013115 11500077 Metal Container Corporation 28 -85.0913115 11500077 Metal Container Corporation 30 -85.0913115 11500077 Metal Container Corporation 32 -85.0913115 11500077 Metal Container Corporation 37 -85.0913115 11500077 Metal Container Corporation 44 -85.0913115 11500077 Metal Container Corporation 61 -85.0913115 11500077 Metal Container Corporation FUG -85.0913115 11500077 Metal Container Corporation FUG2 -85.0913121 12100807 Delta Airlines - General Office Facilities S1 -84.423

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

13121 12100807 Delta Airlines - General Office Facilities S2 -84.42313121 12100807 Delta Airlines - General Office Facilities S3 -84.42313121 12100807 Delta Airlines - General Office Facilities S4 -84.42313125 12500001 Thiele Kaolin Co Reedy Creek Div 1 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 16 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 18 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 2 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 21 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 22 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 23 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 27 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 29 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 35 -82.44913125 12500001 Thiele Kaolin Co Reedy Creek Div 4 -82.44913127 12700002 Hercules Inc EAS1 -81.48013127 12700002 Hercules Inc EAS3 -81.48013127 12700002 Hercules Inc EAS4 -81.48013127 12700002 Hercules Inc EAS5 -81.48013127 12700002 Hercules Inc EBS1 -81.48013127 12700002 Hercules Inc FUG -81.48013127 12700002 Hercules Inc HRS4 -81.48013127 12700002 Hercules Inc HRS7 -81.48013127 12700002 Hercules Inc LR02 -81.48013127 12700002 Hercules Inc LRS1 -81.48013127 12700002 Hercules Inc PAS1 -81.48013127 12700002 Hercules Inc PS09 -81.48013127 12700002 Hercules Inc PS10 -81.48013127 12700002 Hercules Inc PXS1 -81.48013127 12700002 Hercules Inc RS1 -81.48013127 12700002 Hercules Inc SAS4 -81.480

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

13127 12700002 Hercules Inc SAS5 -81.48013127 12700002 Hercules Inc SC40 -81.48013127 12700002 Hercules Inc SP06 -81.48013127 12700002 Hercules Inc SPS1 -81.48013127 12700002 Hercules Inc TR08 -81.48013127 12700002 Hercules Inc TRS3 -81.48013127 12700002 Hercules Inc VS03 -81.48013127 12700002 Hercules Inc VSTACK -81.48013127 12700027 Georgia-Pacific Corporation PS1 -81.54513127 12700027 Georgia-Pacific Corporation PS2 -81.54513127 12700027 Georgia-Pacific Corporation PS3 -81.54513127 12700027 Georgia-Pacific Corporation S201 -81.54513127 12700027 Georgia-Pacific Corporation S202 -81.54513127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT C201 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT C301 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT C401 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT C402 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT CDBH -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT GYBH -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU1 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU2 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU3 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU4 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU5 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU6 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KILN -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT PLBH -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT PLOC -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT RMB1 -81.48813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT RMB2 -81.488

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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13127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT RMB3 -81.48813139 13900075 Indalex America Inc FUG1 -83.85513139 13900075 Indalex America Inc PL1 -83.85513139 13900075 Indalex America Inc RTO1 -83.85513175 17500004 SP Newsprint Company, LLC CDBS -82.84413175 17500004 SP Newsprint Company, LLC DI1S -82.84413175 17500004 SP Newsprint Company, LLC DI2S -82.84413175 17500004 SP Newsprint Company, LLC FABAS -82.84413175 17500004 SP Newsprint Company, LLC HRSGS -82.84413175 17500004 SP Newsprint Company, LLC LMSS -82.84413175 17500004 SP Newsprint Company, LLC PB1S -82.84413175 17500004 SP Newsprint Company, LLC PB2S -82.84413175 17500004 SP Newsprint Company, LLC PM1S -82.84413175 17500004 SP Newsprint Company, LLC PM2S -82.84413175 17500004 SP Newsprint Company, LLC SSS -82.84413175 17500004 SP Newsprint Company, LLC WWTPS -82.84413175 17500035 Gilman Paper Co KL01 -83.101513175 17500035 Gilman Paper Co KL02 -83.101513175 17500035 Gilman Paper Co KL03 -83.101513213 21300034 Kgen Murray 1 & 2 LLC AUXB1 -84.918213213 21300034 Kgen Murray 1 & 2 LLC AUXB2 -84.918213213 21300034 Kgen Murray 1 & 2 LLC CT1 -84.918213213 21300034 Kgen Murray 1 & 2 LLC CT2 -84.918213213 21300034 Kgen Murray 1 & 2 LLC CT3 -84.918213213 21300034 Kgen Murray 1 & 2 LLC CT4 -84.918213237 23700010 Rayonier Inc- Eatonton Sawmill DKF1 -83.36013237 23700010 Rayonier Inc- Eatonton Sawmill DKF2 -83.36013237 23700010 Rayonier Inc- Eatonton Sawmill PBS1 -83.36013237 23700010 Rayonier Inc- Eatonton Sawmill PMF1 -83.36013237 23700010 Rayonier Inc- Eatonton Sawmill SM01 -83.360

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

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FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

13245 24500003 DSM Chemicals North America, Inc. FUG -81.9313245 24500003 DSM Chemicals North America, Inc. S002 -81.9313245 24500003 DSM Chemicals North America, Inc. S008 -81.9313245 24500003 DSM Chemicals North America, Inc. S012 -81.9313245 24500003 DSM Chemicals North America, Inc. S014 -81.9313245 24500003 DSM Chemicals North America, Inc. S015 -81.9313245 24500003 DSM Chemicals North America, Inc. S016 -81.9313245 24500003 DSM Chemicals North America, Inc. S017 -81.9313245 24500003 DSM Chemicals North America, Inc. S020 -81.9313245 24500003 DSM Chemicals North America, Inc. S023 -81.9313245 24500003 DSM Chemicals North America, Inc. S029 -81.9313245 24500003 DSM Chemicals North America, Inc. S07A -81.9313245 24500003 DSM Chemicals North America, Inc. S18A -81.9313245 24500003 DSM Chemicals North America, Inc. S24A -81.9313245 24500023 Occidental Chemical Co STK1 -81.98813245 24500023 Occidental Chemical Co STK2 -81.98813245 24500068 Procter & Gamble Manufacturing Co G001 -82.00213245 24500068 Procter & Gamble Manufacturing Co G002 -82.00213245 24500068 Procter & Gamble Manufacturing Co G003 -82.00213245 24500068 Procter & Gamble Manufacturing Co G004 -82.00213245 24500068 Procter & Gamble Manufacturing Co P045 -82.00213245 24500068 Procter & Gamble Manufacturing Co P057 -82.00213245 24500068 Procter & Gamble Manufacturing Co P086 -82.00213261 26100069 Caravelle Powerboats, Inc. 3901 -84.20413261 26100069 Caravelle Powerboats, Inc. 3902 -84.20413261 26100069 Caravelle Powerboats, Inc. 3903 -84.20413261 26100069 Caravelle Powerboats, Inc. 3904 -84.20413261 26100069 Caravelle Powerboats, Inc. 3905 -84.20413261 26100069 Caravelle Powerboats, Inc. 3920 -84.20413261 26100069 Caravelle Powerboats, Inc. 3921 -84.204

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

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ID Facility Name Release Point ID Long 

13261 26100069 Caravelle Powerboats, Inc. 3990 -84.20413261 26100069 Caravelle Powerboats, Inc. ASM -84.20413261 26100069 Caravelle Powerboats, Inc. UPH -84.20413269 26900016 Taylor County LFGTE Power Station S01 -84.38713269 26900016 Taylor County LFGTE Power Station S02 -84.38713269 26900016 Taylor County LFGTE Power Station S03 -84.38713269 26900016 Taylor County LFGTE Power Station S04 -84.38713275 27500008 Hood Industries, Inc. B2 -83.98613275 27500008 Hood Industries, Inc. B3 -83.98613275 27500008 Hood Industries, Inc. B4 -83.98613275 27500008 Hood Industries, Inc. DK1 -83.98613275 27500008 Hood Industries, Inc. DK2 -83.98613275 27500008 Hood Industries, Inc. DK3 -83.98613275 27500008 Hood Industries, Inc. FUG -83.98613275 27500008 Hood Industries, Inc. PMC1 -83.98613275 27500008 Hood Industries, Inc. PMC2 -83.98613313 31300084 Shaw Industries Inc. Plant No.: 4 BS02 -84.96613313 31300084 Shaw Industries Inc. Plant No.: 4 BS03 -84.96613313 31300084 Shaw Industries Inc. Plant No.: 4 BS04 -84.96613313 31300084 Shaw Industries Inc. Plant No.: 4 LS02 -84.96613313 31300084 Shaw Industries Inc. Plant No.: 4 LS03 -84.96621003 00002 Irving Materials Inc 01--02 -86.187821003 00002 Irving Materials Inc 02--02 -86.187821003 00002 Irving Materials Inc 03--02 -86.187821003 00002 Irving Materials Inc 05--02 -86.187821003 00002 Irving Materials Inc 06--02 -86.187821003 00002 Irving Materials Inc 06--03 -86.187821003 00002 Irving Materials Inc 06--04 -86.187821003 00002 Irving Materials Inc 07--01 -86.187821015 00069 Camco Chemical Co 001 -84.6

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

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ID Facility Name Release Point ID Long 

21015 00069 Camco Chemical Co 002 -84.621015 00069 Camco Chemical Co 004 -84.621015 00069 Camco Chemical Co 005 -84.621015 00069 Camco Chemical Co 006 -84.621015 00069 Camco Chemical Co 007 -84.621015 00069 Camco Chemical Co 008 -84.621015 00069 Camco Chemical Co 009 -84.621015 00069 Camco Chemical Co 010 -84.621015 00069 Camco Chemical Co 011 -84.621015 00118 Diversified Structural Composites 002 -84.6221015 00118 Diversified Structural Composites 003 -84.6221015 00118 Diversified Structural Composites 005 -84.6221015 00118 Diversified Structural Composites 006 -84.6221015 00118 Diversified Structural Composites MP11 -84.6221015 00156 Coral Graphic Service Inc 001 -84.621015 00156 Coral Graphic Service Inc 002 -84.621015 00156 Coral Graphic Service Inc 003 -84.621015 00156 Coral Graphic Service Inc 004 -84.621015 00156 Coral Graphic Service Inc 005 -84.621015 00156 Coral Graphic Service Inc 006 -84.621015 00156 Coral Graphic Service Inc 007 -84.621025 00001 The Wells Group LLC 001 -83.40021025 00001 The Wells Group LLC 002 -83.40021025 00001 The Wells Group LLC 003 -83.40021025 00001 The Wells Group LLC 004 -83.40021025 00001 The Wells Group LLC 005 -83.40021025 00001 The Wells Group LLC 006 -83.40021025 00012 Hinkle Contracting Corp - Jackson Plant 001 -83.40021025 00012 Hinkle Contracting Corp - Jackson Plant 002 -83.40021025 00012 Hinkle Contracting Corp - Jackson Plant 003 -83.400

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

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FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

21025 00033 Begley Properties LLC 001 -83.418221025 00033 Begley Properties LLC 002 -83.418221037 00051 Freeport Mcmoran Resource 001 -84.3521037 00051 Freeport Mcmoran Resource 002 -84.3521037 00097 DDA Partnership 001 -84.463621045 00027 TN Gas Pipeline - Dry Creek Transmission Station 001 -85.121045 00027 TN Gas Pipeline - Dry Creek Transmission Station 002 -85.121045 00028 Casey Furniture Mfg, Llc 001 -84.94521045 00028 Casey Furniture Mfg, Llc 002 -84.94521045 00028 Casey Furniture Mfg, Llc 003 -84.94521045 00028 Casey Furniture Mfg, Llc 004 -84.94521045 00028 Casey Furniture Mfg, Llc 005 -84.94521051 00034 Chas Coal LLC - Red Bird Prep Plant 001 -83.53721051 00034 Chas Coal LLC - Red Bird Prep Plant 002 -83.53721051 00034 Chas Coal LLC - Red Bird Prep Plant 003 -83.53721051 00034 Chas Coal LLC - Red Bird Prep Plant 004 -83.53721057 00005 Albany Redi-Mix 001 -85.36821057 00005 Albany Redi-Mix 002 -85.36821057 00005 Albany Redi-Mix 003 -85.36821071 00154 Chesapeake Appalachia LLC - Warco Transmission Station E01 -82.7721071 00154 Chesapeake Appalachia LLC - Warco Transmission Station E02 -82.7721071 00154 Chesapeake Appalachia LLC - Warco Transmission Station E03A -82.7721071 00154 Chesapeake Appalachia LLC - Warco Transmission Station E03B -82.7721071 00158 EQT Gathering LLC - Drift Compressor Station 001 -82.7421071 00158 EQT Gathering LLC - Drift Compressor Station 002 -82.7421071 00159 EQT Gathering LLC - Maytown Compressor Station 001 -82.7821071 00159 EQT Gathering LLC - Maytown Compressor Station 002 -82.7821073 00079 Rogers Group Inc Portable Crush Plant 3 001 -84.821073 00079 Rogers Group Inc Portable Crush Plant 3 002 -84.821073 00079 Rogers Group Inc Portable Crush Plant 3 003 -84.8

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

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State Fac 

ID Facility Name Release Point ID Long 

21073 00079 Rogers Group Inc Portable Crush Plant 3 004 -84.821073 00079 Rogers Group Inc Portable Crush Plant 3 005 -84.821073 00079 Rogers Group Inc Portable Crush Plant 3 006 -84.821073 00079 Rogers Group Inc Portable Crush Plant 3 007 -84.821077 00025 Sterling Ventures LLC 01--01 -84.7521077 00025 Sterling Ventures LLC 01--02 -84.7521077 00025 Sterling Ventures LLC 03--01 -84.7521077 00025 Sterling Ventures LLC 05--01 -84.7521077 00025 Sterling Ventures LLC 05--02 -84.7521077 00025 Sterling Ventures LLC 05--03 -84.7521077 00025 Sterling Ventures LLC 07--01 -84.7521077 00025 Sterling Ventures LLC 17--01 -84.7521077 00025 Sterling Ventures LLC 18--01 -84.7521077 00025 Sterling Ventures LLC 25--01 -84.7521077 00025 Sterling Ventures LLC 26--01 -84.7521077 00025 Sterling Ventures LLC 27--01 -84.7521077 00025 Sterling Ventures LLC 28--01 -84.7521077 00025 Sterling Ventures LLC 28--02 -84.7521077 00025 Sterling Ventures LLC 29--01 -84.7521077 00025 Sterling Ventures LLC 29--02 -84.7521077 00030 IMI South LLC EP0101 -84.8921077 00030 IMI South LLC EP0103 -84.8921077 00030 IMI South LLC EP0104 -84.8921077 00030 IMI South LLC EP-02 -84.8921077 00030 IMI South LLC EP0205 -84.8921077 00030 IMI South LLC EP0206 -84.8921077 00030 IMI South LLC EP0301 -84.8921077 00030 IMI South LLC EP0302 -84.8921077 00030 IMI South LLC EP0402 -84.8921089 00044 Ashland Recovery Inc 001 -82.6

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

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21089 00044 Ashland Recovery Inc 002 -82.621089 00044 Ashland Recovery Inc 003 -82.621089 00044 Ashland Recovery Inc 004 -82.621089 00044 Ashland Recovery Inc 005 -82.621089 00044 Ashland Recovery Inc 006 -82.621089 00044 Ashland Recovery Inc 007 -82.621091 00026 L. R. Chapman (01) -86.821091 00026 L. R. Chapman (02) -86.821091 00026 L. R. Chapman (03) -86.821091 00026 L. R. Chapman (04) -86.821091 00026 L. R. Chapman (05) -86.821091 00026 L. R. Chapman (06) -86.821091 00026 L. R. Chapman (07) -86.821091 00026 L. R. Chapman (08) -86.821091 00026 L. R. Chapman (09) -86.821091 00026 L. R. Chapman (10) -86.821091 00026 L. R. Chapman (11) -86.821091 00026 L. R. Chapman (12) -86.821091 00026 L. R. Chapman (13) -86.821091 00026 L. R. Chapman (14) -86.821091 00026 L. R. Chapman (15) -86.821091 00026 L. R. Chapman (16) -86.821091 00026 L. R. Chapman (17) -86.821091 00026 L. R. Chapman (18) -86.821091 00026 L. R. Chapman (19) -86.821091 00026 L. R. Chapman (20) -86.821091 00026 L. R. Chapman (21) -86.821091 00026 L. R. Chapman (22) -86.821091 00026 L. R. Chapman (23) -86.821091 00026 L. R. Chapman (24) -86.8

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

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21091 00026 L. R. Chapman (25) -86.821091 00026 L. R. Chapman (26) -86.821091 00026 L. R. Chapman (27) -86.821091 00026 L. R. Chapman (28) -86.821091 00026 L. R. Chapman (29) -86.821091 00026 L. R. Chapman (30) -86.821091 00026 L. R. Chapman (31) -86.821091 00026 L. R. Chapman (32) -86.821091 00026 L. R. Chapman (33) -86.821091 00026 L. R. Chapman (34) -86.821091 00026 L. R. Chapman (35) -86.821091 00026 L. R. Chapman (36) -86.821091 00026 L. R. Chapman (37) -86.821091 00026 L. R. Chapman (38) -86.821091 00026 L. R. Chapman (39) -86.821091 00026 L. R. Chapman (40) -86.821091 00026 L. R. Chapman (41) -86.821091 00026 L. R. Chapman (42) -86.821091 00026 L. R. Chapman (43) -86.821091 00026 L. R. Chapman (44) -86.821091 00026 L. R. Chapman (45) -86.821091 00026 L. R. Chapman (46) -86.821091 00026 L. R. Chapman (47) -86.821091 00026 L. R. Chapman (48) -86.821091 00026 L. R. Chapman (49) -86.821091 00026 L. R. Chapman (50) -86.821091 00026 L. R. Chapman (51) -86.821091 00026 L. R. Chapman (52) -86.821101 00139 Kentucky 5 Star Energy LLC FS01 -87.52421101 00139 Kentucky 5 Star Energy LLC FS02 -87.524

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

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21101 00139 Kentucky 5 Star Energy LLC FS03 -87.52421101 00139 Kentucky 5 Star Energy LLC FS04 -87.52421101 00139 Kentucky 5 Star Energy LLC FS05 -87.52421101 00139 Kentucky 5 Star Energy LLC FS06 -87.52421101 00139 Kentucky 5 Star Energy LLC FS07 -87.52421101 00139 Kentucky 5 Star Energy LLC SV01 -87.52421101 00139 Kentucky 5 Star Energy LLC SV02 -87.52421101 00139 Kentucky 5 Star Energy LLC SV03 -87.52421101 00139 Kentucky 5 Star Energy LLC SV04 -87.52421101 00139 Kentucky 5 Star Energy LLC SV05 -87.52421101 00139 Kentucky 5 Star Energy LLC SV06 -87.52421101 00139 Kentucky 5 Star Energy LLC SV07 -87.52421101 00139 Kentucky 5 Star Energy LLC SV08 -87.52421101 00139 Kentucky 5 Star Energy LLC SV09 -87.52421101 00139 Kentucky 5 Star Energy LLC SV10 -87.52421101 00139 Kentucky 5 Star Energy LLC SV11 -87.52421101 00139 Kentucky 5 Star Energy LLC SV12 -87.52421101 00139 Kentucky 5 Star Energy LLC SV13 -87.52421101 00139 Kentucky 5 Star Energy LLC SV1415 -87.52421101 00139 Kentucky 5 Star Energy LLC SV16 -87.52421101 00139 Kentucky 5 Star Energy LLC TK1-5 -87.52421107 00146 Hopkinsville Wood Products 001 -87.6821107 00146 Hopkinsville Wood Products 002 -87.6821107 00156 J-Lok Corp EP-AU- -87.48721107 00156 J-Lok Corp EP-V-1 -87.48721107 00156 J-Lok Corp EP-V-2 -87.48721107 00156 J-Lok Corp EP-V-3 -87.48721117 00165 Laser Graphic Systems 001 -84.627621117 00165 Laser Graphic Systems 002 -84.627621117 00165 Laser Graphic Systems 003 -84.6276

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

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ID Facility Name Release Point ID Long 

21117 00174 BBS Tech Inc EP1 -84.6221117 00176 Alstom Power Inc EP1 -84.6321117 00176 Alstom Power Inc EP2 -84.6321119 00038 Chesapeake Appalachia LLC - Brinkley Transmission Station 001 -82.9421119 00040 Chesapeake Appalachia LLC - Lackey Transmission Station 001 -82.8321119 00041 ICG Knott Co - Raven Coal Preperation Plant Group1 -82.823621119 00041 ICG Knott Co - Raven Coal Preperation Plant Group2 -82.823621119 00041 ICG Knott Co - Raven Coal Preperation Plant Group3 -82.823621121 00032 Gatliff Coal Co - ADA Tipple 5 001 -83.82021121 00032 Gatliff Coal Co - ADA Tipple 5 002 -83.82021121 00032 Gatliff Coal Co - ADA Tipple 5 003 -83.82021125 00084 Admiralty Boats Inc 001 -84.0721125 00084 Admiralty Boats Inc 002 -84.0721125 00084 Admiralty Boats Inc 003 -84.0721125 00084 Admiralty Boats Inc 005 -84.0721125 00084 Admiralty Boats Inc 006 -84.0721125 00106 ABC Automotive Systems Inc EP1-21 -84.03321125 00106 ABC Automotive Systems Inc EP22 -84.03321125 00106 ABC Automotive Systems Inc EP23 -84.03321125 00106 ABC Automotive Systems Inc EP24 -84.03321133 00079 Mountain Enterprises Inc - Cumberland Plant 20 0101 -83.0221133 00079 Mountain Enterprises Inc - Cumberland Plant 20 0201 -83.0221133 00079 Mountain Enterprises Inc - Cumberland Plant 20 0202 -83.0221133 00079 Mountain Enterprises Inc - Cumberland Plant 20 0301 -83.0221135 00013 Mountain Enterprises Inc -Vanceburg Plant 30 001 -83.3421135 00013 Mountain Enterprises Inc -Vanceburg Plant 30 002 -83.3421135 00013 Mountain Enterprises Inc -Vanceburg Plant 30 003 -83.3421141 00020 Hanson Aggregates Midwest LLC - Rockfield Quarry 001 -86.621141 00020 Hanson Aggregates Midwest LLC - Rockfield Quarry 002 -86.621141 00020 Hanson Aggregates Midwest LLC - Rockfield Quarry 003 -86.6

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

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State Fac 

ID Facility Name Release Point ID Long 

21141 00020 Hanson Aggregates Midwest LLC - Rockfield Quarry 004 -86.621141 00020 Hanson Aggregates Midwest LLC - Rockfield Quarry 005 -86.621141 00020 Hanson Aggregates Midwest LLC - Rockfield Quarry 006 -86.621141 00020 Hanson Aggregates Midwest LLC - Rockfield Quarry 007 -86.621141 00020 Hanson Aggregates Midwest LLC - Rockfield Quarry 008 -86.621141 00020 Hanson Aggregates Midwest LLC - Rockfield Quarry 009 -86.621141 00060 Bowling Green Concrete - Rockfield Ready-Mix Plant 001 -86.621179 00034 Heaven Hill Distilleries Inc 001 -85.56021183 00069 Western KY Energy Corp - Wilson Station EU-01 -87.079021183 00069 Western KY Energy Corp - Wilson Station EU-02 -87.079021183 00069 Western KY Energy Corp - Wilson Station EU-03 -87.079021183 00069 Western KY Energy Corp - Wilson Station EU-04 -87.079021183 00069 Western KY Energy Corp - Wilson Station EU-05 -87.079021183 00069 Western KY Energy Corp - Wilson Station IA -87.079021195 00267 EQT Gathering LLC - Rockhouse Compressor Station 01 -82.3221195 00267 EQT Gathering LLC - Rockhouse Compressor Station 02 -82.3221207 00022 Pyles Concrete Inc 001 -85.05921207 00022 Pyles Concrete Inc 002 -85.05921207 00022 Pyles Concrete Inc 003 -85.05921211 00050 LG&E\KU System Control & Data Center 1 -85.3421211 00050 LG&E\KU System Control & Data Center 2 -85.3421213 00029 South Union Elevator 001 -86.6521213 00029 South Union Elevator 002 -86.6521213 00029 South Union Elevator 003 -86.6521213 00029 South Union Elevator 004 -86.6521213 00029 South Union Elevator 005 -86.6521217 00033 TN Gas Pipeline - Station 96 001 -85.3921217 00033 TN Gas Pipeline - Station 96 FUG01 -85.3921217 00035 Ambrake Corp 001 -85.3221217 00035 Ambrake Corp 002 -85.32

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21217 00035 Ambrake Corp 003 -85.3221219 00013 Koppers Industries,Inc 001 -87.1521219 00013 Koppers Industries,Inc 002a -87.1521219 00013 Koppers Industries,Inc 002b -87.1521219 00013 Koppers Industries,Inc 003 -87.1521219 00013 Koppers Industries,Inc 004 -87.1521219 00013 Koppers Industries,Inc 005 -87.1521219 00013 Koppers Industries,Inc 006 -87.1521233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 001 -87.774621233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 002 -87.774621233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 003 -87.774621233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 004 -87.774621233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 005 -87.774637021 0735 Western Animal Disease Diagnostic Laboratory ES-1 -82.537057 3705700265 CEMEX Construction Materials, Atlantic, LLC ES2 -80.0437057 3705700265 CEMEX Construction Materials, Atlantic, LLC ES3 -80.0437057 3705700265 CEMEX Construction Materials, Atlantic, LLC ES4 -80.0437119 134 Rea Contracting, LLC. (069 Arrowood) 1 -80.9245003 0080-0011 SCE&G URQUHART 3 -81.945015 0420-0015 ALUMAX OF SOUTH CAROLINA 1 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 10 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 100 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 101 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 11 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 12 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 122 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 123 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 124 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 13 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 14 -80.05

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ID Facility Name Release Point ID Long 

45015 0420-0015 ALUMAX OF SOUTH CAROLINA 15 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 16 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 17 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 18 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 19 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 2 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 20 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 21 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 22 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 24 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 26 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 27 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 28 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 29 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 3 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 30 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 31 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 32 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 33 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 34 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 35 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 36 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 37 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 38 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 39 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 4 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 40 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 41 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 42 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 43 -80.05

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ID Facility Name Release Point ID Long 

45015 0420-0015 ALUMAX OF SOUTH CAROLINA 44 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 45 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 46 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 47 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 5 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 50 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 51 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 52 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 53 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 54 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 55 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 57 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 58 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 59 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 6 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 60 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 61 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 62 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 63 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 64 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 65 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 66 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 67 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 68 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 69 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 7 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 8 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 80 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 81 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 83 -80.05

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State Fac 

ID Facility Name Release Point ID Long 

45015 0420-0015 ALUMAX OF SOUTH CAROLINA 84 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 85 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 86 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 87 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 9 -80.0545015 0420-0015 ALUMAX OF SOUTH CAROLINA 95 -80.0545015 0420-0094 SEA FOX BOAT COMPANY 1 -80.0245019 0560-0029 SCE&G HAGOOD 1 -79.9645059 1520-0066 FAURECIA INTERIOR SYS USA FOUNTAIN INN 57 -82.1945063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 1 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 10 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 11 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 12 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 13 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 14 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 15 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 16 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 17 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 18 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 19 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 2 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 20 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 21 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 22 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 227 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 3 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 4 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 6 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 7 -81.1545063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 8 -81.15

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ID Facility Name Release Point ID Long 

45063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 9 -81.1545081 1940-0007 SIMPSON LBR CO JOHNSTON LBR MILL 1 -81.8245081 1940-0007 SIMPSON LBR CO JOHNSTON LBR MILL 2 -81.8245081 1940-0007 SIMPSON LBR CO JOHNSTON LBR MILL 6 -81.8245081 1940-0007 SIMPSON LBR CO JOHNSTON LBR MILL 7 -81.8247009 0176 USI, INC. SPB-1 -83.933347009 0176 USI, INC. SPB-2 -83.933347009 0176 USI, INC. SPB-3 -83.933347009 0176 USI, INC. SPB-4 -83.933347009 0176 USI, INC. SPB-5 -83.933347009 0176 USI, INC. SPB-6 -83.933347011 0215 ARCH CHEMICALS, INC. H-12V -84.78347011 0215 ARCH CHEMICALS, INC. H-13E -84.78347011 0215 ARCH CHEMICALS, INC. H-1E -84.78347011 0215 ARCH CHEMICALS, INC. H-2E -84.78347011 0215 ARCH CHEMICALS, INC. H-3E -84.78347011 0215 ARCH CHEMICALS, INC. H-5E -84.78347011 0215 ARCH CHEMICALS, INC. H-7E -84.78347011 0215 ARCH CHEMICALS, INC. H-89BH -84.78347011 0215 ARCH CHEMICALS, INC. H-8BH -84.78347011 0215 ARCH CHEMICALS, INC. H-9BH -84.78347011 0215 ARCH CHEMICALS, INC. H-P10 -84.78347011 0215 ARCH CHEMICALS, INC. H-P11 -84.78347017 0012 NORANDAL USA, INC. 801HD -88.381947017 0012 NORANDAL USA, INC. 801MR -88.381947017 0012 NORANDAL USA, INC. 802HD -88.381947017 0012 NORANDAL USA, INC. 802M -88.381947017 0012 NORANDAL USA, INC. 803HD -88.381947017 0012 NORANDAL USA, INC. 803M -88.381947017 0012 NORANDAL USA, INC. 804HD -88.3819

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47017 0012 NORANDAL USA, INC. 804M -88.381947017 0012 NORANDAL USA, INC. 901H -88.381947017 0012 NORANDAL USA, INC. 901M -88.381947017 0012 NORANDAL USA, INC. 902H -88.381947017 0012 NORANDAL USA, INC. 902M -88.381947017 0012 NORANDAL USA, INC. 903HD -88.381947017 0012 NORANDAL USA, INC. 903M -88.381947017 0012 NORANDAL USA, INC. 904HD -88.381947017 0012 NORANDAL USA, INC. 905MHD -88.381947017 0012 NORANDAL USA, INC. AHON -88.381947017 0012 NORANDAL USA, INC. AHOS -88.381947017 0012 NORANDAL USA, INC. FUG-01 -88.381947017 0012 NORANDAL USA, INC. RM1 -88.381947017 0012 NORANDAL USA, INC. S-05A -88.381947017 0012 NORANDAL USA, INC. S-05B -88.381947017 0012 NORANDAL USA, INC. S-05C -88.381947017 0012 NORANDAL USA, INC. S-05D -88.381947017 0012 NORANDAL USA, INC. S-05E -88.381947017 0012 NORANDAL USA, INC. S-05F -88.381947017 0012 NORANDAL USA, INC. S-05G -88.381947017 0012 NORANDAL USA, INC. S-05H -88.381947017 0012 NORANDAL USA, INC. S-05I -88.381947017 0012 NORANDAL USA, INC. S-05J -88.381947017 0012 NORANDAL USA, INC. S-05K -88.381947017 0012 NORANDAL USA, INC. S-05L -88.381947017 0012 NORANDAL USA, INC. S-08A -88.381947017 0012 NORANDAL USA, INC. S-08B -88.381947017 0012 NORANDAL USA, INC. S-14A -88.381947017 0012 NORANDAL USA, INC. S-14B -88.381947017 0012 NORANDAL USA, INC. S-14C -88.3819

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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State Fac 

ID Facility Name Release Point ID Long 

47017 0012 NORANDAL USA, INC. S-14D -88.381947017 0012 NORANDAL USA, INC. S-19A -88.381947017 0012 NORANDAL USA, INC. S-23A -88.381947017 0012 NORANDAL USA, INC. S-31A -88.381947025 0083 DTR TENNESSEE, INC 001 -83.5647025 0083 DTR TENNESSEE, INC 002 -83.5647025 0083 DTR TENNESSEE, INC 003 -83.5647025 0083 DTR TENNESSEE, INC 004 -83.5647025 0083 DTR TENNESSEE, INC 009 -83.5647025 0083 DTR TENNESSEE, INC 010 -83.5647025 0083 DTR TENNESSEE, INC 011 -83.5647025 0083 DTR TENNESSEE, INC 012 -83.5647041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. 001 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-001 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-002 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-003 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-004 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-006 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-007 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-008 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-009 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-010 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-011 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-012 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-021 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-022 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-024 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-029 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-030 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-031 -85.80324411392

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State Fac 

ID Facility Name Release Point ID Long 

47041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-032 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-033 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-034 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-040 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-041 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-042 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-043 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-048 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-049 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-050 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-051 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-052 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-054 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-055 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-062 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-063 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-064 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-065 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-066 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-067 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-068 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-069 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-082 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-083 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-084 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-085 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-086 -85.8032441139247041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-087 -85.8032441139247043 0079 MASONITE DOOR CORPORATION EP12 -87.33847043 0079 MASONITE DOOR CORPORATION EP6 -87.338

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ID Facility Name Release Point ID Long 

47043 0079 MASONITE DOOR CORPORATION FUG1 -87.33847059 0165 DELFASCO OF TENNESSEE 141-02 -82.77747059 0165 DELFASCO OF TENNESSEE 165-1A -82.77747059 0165 DELFASCO OF TENNESSEE 165-1B -82.77747059 0165 DELFASCO OF TENNESSEE 165-1C -82.77747059 0165 DELFASCO OF TENNESSEE 165-1D -82.77747073 0001 HOLLISTON MILLS, INC. C1A -82.7547073 0001 HOLLISTON MILLS, INC. C1W -82.7547073 0001 HOLLISTON MILLS, INC. E19F -82.7547073 0001 HOLLISTON MILLS, INC. E4F -82.7547073 0001 HOLLISTON MILLS, INC. E53F -82.7547073 0001 HOLLISTON MILLS, INC. E5F -82.7547073 0001 HOLLISTON MILLS, INC. E61F -82.7547073 0001 HOLLISTON MILLS, INC. E9F -82.7547073 0001 HOLLISTON MILLS, INC. F1M -82.7547073 0001 HOLLISTON MILLS, INC. F2M -82.7547073 0001 HOLLISTON MILLS, INC. P10A -82.7547073 0001 HOLLISTON MILLS, INC. P10F -82.7547073 0001 HOLLISTON MILLS, INC. P11A -82.7547073 0001 HOLLISTON MILLS, INC. P11AF -82.7547073 0001 HOLLISTON MILLS, INC. P11F -82.7547073 0001 HOLLISTON MILLS, INC. P12A -82.7547073 0001 HOLLISTON MILLS, INC. P12F -82.7547073 0001 HOLLISTON MILLS, INC. P13F -82.7547073 0001 HOLLISTON MILLS, INC. P14F -82.7547073 0001 HOLLISTON MILLS, INC. P15F -82.7547073 0001 HOLLISTON MILLS, INC. P16F -82.7547073 0001 HOLLISTON MILLS, INC. P17F -82.7547073 0001 HOLLISTON MILLS, INC. P19F -82.7547073 0001 HOLLISTON MILLS, INC. P1A -82.75

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ID Facility Name Release Point ID Long 

47073 0001 HOLLISTON MILLS, INC. P20A -82.7547073 0001 HOLLISTON MILLS, INC. P20F -82.7547073 0001 HOLLISTON MILLS, INC. P21A -82.7547073 0001 HOLLISTON MILLS, INC. P21F -82.7547073 0001 HOLLISTON MILLS, INC. P22F -82.7547073 0001 HOLLISTON MILLS, INC. P23F -82.7547073 0001 HOLLISTON MILLS, INC. P24F -82.7547073 0001 HOLLISTON MILLS, INC. P25F -82.7547073 0001 HOLLISTON MILLS, INC. P26F -82.7547073 0001 HOLLISTON MILLS, INC. P2A -82.7547073 0001 HOLLISTON MILLS, INC. P34F -82.7547073 0001 HOLLISTON MILLS, INC. P35F -82.7547073 0001 HOLLISTON MILLS, INC. P36F -82.7547073 0001 HOLLISTON MILLS, INC. P37F -82.7547073 0001 HOLLISTON MILLS, INC. P38F -82.7547073 0001 HOLLISTON MILLS, INC. P3A -82.7547073 0001 HOLLISTON MILLS, INC. P3F -82.7547073 0001 HOLLISTON MILLS, INC. P43F -82.7547073 0001 HOLLISTON MILLS, INC. P44F -82.7547073 0001 HOLLISTON MILLS, INC. P45F -82.7547073 0001 HOLLISTON MILLS, INC. P46F -82.7547073 0001 HOLLISTON MILLS, INC. P48F -82.7547073 0001 HOLLISTON MILLS, INC. P49F -82.7547073 0001 HOLLISTON MILLS, INC. P4A -82.7547073 0001 HOLLISTON MILLS, INC. P4F -82.7547073 0001 HOLLISTON MILLS, INC. P51F -82.7547073 0001 HOLLISTON MILLS, INC. P58F -82.7547073 0001 HOLLISTON MILLS, INC. P5A -82.7547073 0001 HOLLISTON MILLS, INC. P5AF -82.7547073 0001 HOLLISTON MILLS, INC. P5F -82.75

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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State Fac 

ID Facility Name Release Point ID Long 

47073 0001 HOLLISTON MILLS, INC. P60F -82.7547073 0001 HOLLISTON MILLS, INC. P62F -82.7547073 0001 HOLLISTON MILLS, INC. P63F -82.7547073 0001 HOLLISTON MILLS, INC. P67F -82.7547073 0001 HOLLISTON MILLS, INC. P6A -82.7547073 0001 HOLLISTON MILLS, INC. P6AF -82.7547073 0001 HOLLISTON MILLS, INC. P6F -82.7547073 0001 HOLLISTON MILLS, INC. P7A -82.7547073 0001 HOLLISTON MILLS, INC. P7F -82.7547073 0001 HOLLISTON MILLS, INC. P8A -82.7547073 0001 HOLLISTON MILLS, INC. P8F -82.7547073 0001 HOLLISTON MILLS, INC. P9A -82.7547073 0001 HOLLISTON MILLS, INC. P9F -82.7547075 0039 HAYWOOD COMPANY 9_A -89.2406347075 0039 HAYWOOD COMPANY 9_B -89.2406347075 0039 HAYWOOD COMPANY BIN_10 -89.2406347075 0039 HAYWOOD COMPANY C114 -89.2406347075 0039 HAYWOOD COMPANY C115 -89.2406347075 0039 HAYWOOD COMPANY C116 -89.2406347075 0039 HAYWOOD COMPANY C117 -89.2406347075 0039 HAYWOOD COMPANY C118 -89.2406347075 0039 HAYWOOD COMPANY C119 -89.2406347075 0039 HAYWOOD COMPANY C120 -89.2406347075 0039 HAYWOOD COMPANY C121 -89.2406347075 0039 HAYWOOD COMPANY C122 -89.2406347075 0039 HAYWOOD COMPANY C124 -89.2406347075 0039 HAYWOOD COMPANY C125 -89.2406347075 0039 HAYWOOD COMPANY C126 -89.2406347075 0039 HAYWOOD COMPANY C127 -89.2406347075 0039 HAYWOOD COMPANY C128 -89.24063

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47075 0039 HAYWOOD COMPANY C427 -89.2406347075 0039 HAYWOOD COMPANY C63 -89.2406347075 0039 HAYWOOD COMPANY C64 -89.2406347075 0039 HAYWOOD COMPANY C65 -89.2406347075 0039 HAYWOOD COMPANY C66 -89.2406347075 0039 HAYWOOD COMPANY C67 -89.2406347075 0039 HAYWOOD COMPANY C68 -89.2406347075 0039 HAYWOOD COMPANY C69 -89.2406347075 0039 HAYWOOD COMPANY C70 -89.2406347075 0039 HAYWOOD COMPANY C71 -89.2406347075 0039 HAYWOOD COMPANY C72 -89.2406347075 0039 HAYWOOD COMPANY C73 -89.2406347075 0039 HAYWOOD COMPANY C74 -89.2406347075 0039 HAYWOOD COMPANY C75 -89.2406347075 0039 HAYWOOD COMPANY C76 -89.2406347075 0039 HAYWOOD COMPANY C77 -89.2406347075 0039 HAYWOOD COMPANY C78 -89.2406347075 0039 HAYWOOD COMPANY C79 -89.2406347075 0039 HAYWOOD COMPANY C80 -89.2406347075 0039 HAYWOOD COMPANY C81 -89.2406347075 0039 HAYWOOD COMPANY C82 -89.2406347075 0039 HAYWOOD COMPANY C83 -89.2406347075 0039 HAYWOOD COMPANY C84 -89.2406347075 0039 HAYWOOD COMPANY C85 -89.2406347075 0039 HAYWOOD COMPANY C86 -89.2406347075 0039 HAYWOOD COMPANY C87 -89.2406347075 0039 HAYWOOD COMPANY C88 -89.2406347075 0039 HAYWOOD COMPANY C89 -89.2406347075 0039 HAYWOOD COMPANY C90 -89.2406347075 0039 HAYWOOD COMPANY C91 -89.24063

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47075 0039 HAYWOOD COMPANY CEMENT -89.2406347075 0039 HAYWOOD COMPANY FCM_7 -89.2406347075 0039 HAYWOOD COMPANY FP3_MI -89.2406347075 0039 HAYWOOD COMPANY H196 -89.2406347075 0039 HAYWOOD COMPANY HOSE -89.2406347075 0039 HAYWOOD COMPANY Line10 -89.2406347075 0039 HAYWOOD COMPANY MB1_MI -89.2406347075 0039 HAYWOOD COMPANY MILL_1 -89.2406347075 0039 HAYWOOD COMPANY MILL_2 -89.2406347075 0039 HAYWOOD COMPANY MILL_5 -89.2406347075 0039 HAYWOOD COMPANY MILL_6 -89.2406347075 0039 HAYWOOD COMPANY MILL34 -89.2406347075 0039 HAYWOOD COMPANY N 112 -89.2406347075 0039 HAYWOOD COMPANY N1 -89.2406347075 0039 HAYWOOD COMPANY PRESS1 -89.2406347075 0039 HAYWOOD COMPANY PRESS2 -89.2406347075 0039 HAYWOOD COMPANY PRESS3 -89.2406347075 0039 HAYWOOD COMPANY PRESS4 -89.2406347075 0039 HAYWOOD COMPANY PRESS5 -89.2406347075 0039 HAYWOOD COMPANY PVC_WE -89.2406347075 0039 HAYWOOD COMPANY RE46 -89.2406347075 0039 HAYWOOD COMPANY RE47 -89.2406347075 0039 HAYWOOD COMPANY REXT -89.2406347075 0039 HAYWOOD COMPANY RU_101 -89.2406347075 0039 HAYWOOD COMPANY RU_112 -89.2406347075 0039 HAYWOOD COMPANY RU_23 -89.2406347075 0039 HAYWOOD COMPANY RU_32 -89.2406347075 0039 HAYWOOD COMPANY RU_69 -89.2406347075 0039 HAYWOOD COMPANY RU_70 -89.2406347075 0039 HAYWOOD COMPANY RU_93 -89.24063

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

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ID Facility Name Release Point ID Long 

47075 0039 HAYWOOD COMPANY SILO-1 -89.2406347075 0039 HAYWOOD COMPANY SILO-2 -89.2406347075 0039 HAYWOOD COMPANY SILO-3 -89.2406347075 0039 HAYWOOD COMPANY SILO-4 -89.2406347075 0039 HAYWOOD COMPANY SILO-5 -89.2406347075 0039 HAYWOOD COMPANY SILO-6 -89.2406347075 0039 HAYWOOD COMPANY SILO-7 -89.2406347075 0039 HAYWOOD COMPANY SILO-8 -89.2406347075 0039 HAYWOOD COMPANY UNIT_8 -89.2406347075 0039 HAYWOOD COMPANY UNIT_9 -89.2406347089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

FUG4-1 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

FUG5-1 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-001 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-002 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-003 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-004 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-005 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-006 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-007 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-008 -83.47472190856

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-009 -83.47472190856

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-010 -83.47472190856

47105 0098 MALIBU BOATS WEST, INC. S-G2 -84.329047105 0098 MALIBU BOATS WEST, INC. S-G3 -84.329047109 0055 Masco Bath Company - Main Plant BV-03 -88.39447109 0055 Masco Bath Company - Main Plant BV-04 -88.39447109 0055 Masco Bath Company - Main Plant DC-01 -88.39447109 0055 Masco Bath Company - Main Plant DC-02 -88.39447109 0055 Masco Bath Company - Main Plant DC-04 -88.39447109 0055 Masco Bath Company - Main Plant DC-05 -88.39447109 0055 Masco Bath Company - Main Plant EF-01A -88.39447109 0055 Masco Bath Company - Main Plant EF-01B -88.39447109 0055 Masco Bath Company - Main Plant EF-01C -88.39447109 0055 Masco Bath Company - Main Plant EF-02A -88.39447109 0055 Masco Bath Company - Main Plant EF-02B -88.39447109 0055 Masco Bath Company - Main Plant EF-02C -88.39447109 0055 Masco Bath Company - Main Plant EF-03A -88.39447109 0055 Masco Bath Company - Main Plant EF-03B -88.39447109 0055 Masco Bath Company - Main Plant EF-03C -88.39447109 0055 Masco Bath Company - Main Plant EF-04A -88.39447109 0055 Masco Bath Company - Main Plant EF-04B -88.39447109 0055 Masco Bath Company - Main Plant EF-04C -88.39447109 0055 Masco Bath Company - Main Plant EF-17 -88.39447109 0055 Masco Bath Company - Main Plant EF-18 -88.39447109 0055 Masco Bath Company - Main Plant EF-22 -88.39447109 0055 Masco Bath Company - Main Plant EF-25 -88.39447109 0055 Masco Bath Company - Main Plant EF-26 -88.39447109 0055 Masco Bath Company - Main Plant EF-27 -88.39447109 0055 Masco Bath Company - Main Plant EF-28 -88.39447109 0055 Masco Bath Company - Main Plant EF-29 -88.394

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47109 0055 Masco Bath Company - Main Plant EF-30 -88.39447109 0055 Masco Bath Company - Main Plant EF-31 -88.39447109 0055 Masco Bath Company - Main Plant EF-32 -88.39447109 0055 Masco Bath Company - Main Plant EF-33 -88.39447109 0055 Masco Bath Company - Main Plant EF-34 -88.39447109 0055 Masco Bath Company - Main Plant EF-35 -88.39447109 0055 Masco Bath Company - Main Plant EF-36 -88.39447109 0055 Masco Bath Company - Main Plant EF-37 -88.39447109 0055 Masco Bath Company - Main Plant EF-38 -88.39447109 0055 Masco Bath Company - Main Plant EF-39 -88.39447109 0055 Masco Bath Company - Main Plant EF-40 -88.39447109 0055 Masco Bath Company - Main Plant EF-41 -88.39447109 0055 Masco Bath Company - Main Plant EF-42 -88.39447109 0055 Masco Bath Company - Main Plant EF-B1A -88.39447109 0055 Masco Bath Company - Main Plant EF-B1B -88.39447109 0055 Masco Bath Company - Main Plant EF-B1C -88.39447109 0055 Masco Bath Company - Main Plant EF-BV1 -88.39447109 0055 Masco Bath Company - Main Plant EF-BV2 -88.39447109 0055 Masco Bath Company - Main Plant EF-C1A -88.39447109 0055 Masco Bath Company - Main Plant EF-C1B -88.39447109 0055 Masco Bath Company - Main Plant EF-C1C -88.39447109 0055 Masco Bath Company - Main Plant GC-02A -88.39447109 0055 Masco Bath Company - Main Plant GC-03A -88.39447109 0055 Masco Bath Company - Main Plant GC-04A -88.39447109 0055 Masco Bath Company - Main Plant GC-05A -88.39447109 0055 Masco Bath Company - Main Plant GC-06A -88.39447109 0055 Masco Bath Company - Main Plant GEF-01 -88.39447109 0055 Masco Bath Company - Main Plant S-01-8 -88.39447109 0055 Masco Bath Company - Main Plant S-09 -88.39447109 0055 Masco Bath Company - Main Plant S-11 -88.394

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47117 0013 ROGERS GROUP, INC S-001A -86.7746061086647117 0013 ROGERS GROUP, INC S-001B -86.7746061086647119 0132 SATURN CORPORATION FUG110 -86.963847119 0132 SATURN CORPORATION FUG126 -86.963847119 0132 SATURN CORPORATION FUG130 -86.963847119 0132 SATURN CORPORATION FUG133 -86.963847119 0132 SATURN CORPORATION FUG136 -86.963847119 0132 SATURN CORPORATION FUG145 -86.963847119 0132 SATURN CORPORATION S-1022 -86.963847119 0132 SATURN CORPORATION S-1042 -86.963847119 0132 SATURN CORPORATION S-1044 -86.963847119 0132 SATURN CORPORATION S-1122 -86.963847119 0132 SATURN CORPORATION S-1142 -86.963847119 0132 SATURN CORPORATION S-1144 -86.963847119 0132 SATURN CORPORATION S-120 -86.963847119 0132 SATURN CORPORATION S-121 -86.963847119 0132 SATURN CORPORATION S-123 -86.963847119 0132 SATURN CORPORATION S-124 -86.963847119 0132 SATURN CORPORATION S-1242 -86.963847119 0132 SATURN CORPORATION S-1244 -86.963847119 0132 SATURN CORPORATION S-125 -86.963847119 0132 SATURN CORPORATION S-127 -86.963847119 0132 SATURN CORPORATION S-128 -86.963847119 0132 SATURN CORPORATION S-131 -86.963847119 0132 SATURN CORPORATION S-132 -86.963847119 0132 SATURN CORPORATION S-1322 -86.963847119 0132 SATURN CORPORATION S-1342 -86.963847119 0132 SATURN CORPORATION S-1344 -86.963847119 0132 SATURN CORPORATION S-1422 -86.963847119 0132 SATURN CORPORATION S-144 -86.9638

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47119 0132 SATURN CORPORATION S-1442 -86.963847119 0132 SATURN CORPORATION S-1444 -86.963847119 0132 SATURN CORPORATION S-1542 -86.963847119 0132 SATURN CORPORATION S-1544 -86.963847119 0132 SATURN CORPORATION S-1644 -86.963847119 0132 SATURN CORPORATION S-1722 -86.963847119 0132 SATURN CORPORATION S-1822 -86.963847119 0132 SATURN CORPORATION S-1922 -86.963847119 0132 SATURN CORPORATION S-2022 -86.963847119 0132 SATURN CORPORATION S-2122 -86.963847119 0132 SATURN CORPORATION S-224 -86.963847119 0132 SATURN CORPORATION S-225 -86.963847119 0132 SATURN CORPORATION S-227 -86.963847119 0132 SATURN CORPORATION S-228 -86.963847119 0132 SATURN CORPORATION S-231 -86.963847119 0132 SATURN CORPORATION S-232 -86.963847119 0132 SATURN CORPORATION S-2422 -86.963847119 0132 SATURN CORPORATION S-244 -86.963847119 0132 SATURN CORPORATION S-2522 -86.963847119 0132 SATURN CORPORATION S-324 -86.963847119 0132 SATURN CORPORATION S-325 -86.963847119 0132 SATURN CORPORATION S-328 -86.963847119 0132 SATURN CORPORATION S-331 -86.963847119 0132 SATURN CORPORATION S-332 -86.963847119 0132 SATURN CORPORATION S-344 -86.963847119 0132 SATURN CORPORATION S-425 -86.963847119 0132 SATURN CORPORATION S-428 -86.963847119 0132 SATURN CORPORATION S-431 -86.963847119 0132 SATURN CORPORATION S-432 -86.963847119 0132 SATURN CORPORATION S-444 -86.9638

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47119 0132 SATURN CORPORATION S-523 -86.963847119 0132 SATURN CORPORATION S-531 -86.963847119 0132 SATURN CORPORATION S-532 -86.963847119 0132 SATURN CORPORATION S-542 -86.963847119 0132 SATURN CORPORATION S-544 -86.963847119 0132 SATURN CORPORATION S-621 -86.963847119 0132 SATURN CORPORATION S-623 -86.963847119 0132 SATURN CORPORATION S-624 -86.963847119 0132 SATURN CORPORATION S-625 -86.963847119 0132 SATURN CORPORATION S-631 -86.963847119 0132 SATURN CORPORATION S-632 -86.963847119 0132 SATURN CORPORATION S-644 -86.963847119 0132 SATURN CORPORATION S-721 -86.963847119 0132 SATURN CORPORATION S-723 -86.963847119 0132 SATURN CORPORATION S-724 -86.963847119 0132 SATURN CORPORATION S-731 -86.963847119 0132 SATURN CORPORATION S-744 -86.963847119 0132 SATURN CORPORATION S-821 -86.963847119 0132 SATURN CORPORATION S-823 -86.963847119 0132 SATURN CORPORATION S-824 -86.963847119 0132 SATURN CORPORATION S-831 -86.963847119 0132 SATURN CORPORATION S-844 -86.963847119 0132 SATURN CORPORATION S-922 -86.963847119 0132 SATURN CORPORATION S-924 -86.963847119 0132 SATURN CORPORATION S-942 -86.963847119 0132 SATURN CORPORATION S-944 -86.963847123 0089 SEA RAY BOATS, INC. TEL01 -84.265547123 0089 SEA RAY BOATS, INC. TEL02 -84.265547123 0089 SEA RAY BOATS, INC. TEL03 -84.265547123 0089 SEA RAY BOATS, INC. TEL05 -84.2655

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47123 0089 SEA RAY BOATS, INC. TEL06 -84.265547123 0089 SEA RAY BOATS, INC. TEL07 -84.265547123 0089 SEA RAY BOATS, INC. TEL08 -84.265547123 0089 SEA RAY BOATS, INC. TEL09 -84.265547123 0089 SEA RAY BOATS, INC. TEL10 -84.265547123 0089 SEA RAY BOATS, INC. TEL11 -84.265547123 0089 SEA RAY BOATS, INC. TEL12 -84.265547123 0089 SEA RAY BOATS, INC. TEL13 -84.265547123 0089 SEA RAY BOATS, INC. TEL14 -84.265547123 0089 SEA RAY BOATS, INC. TEL15 -84.265547123 0089 SEA RAY BOATS, INC. TEL16 -84.265547123 0089 SEA RAY BOATS, INC. TEL17 -84.265547123 0089 SEA RAY BOATS, INC. TEL18 -84.265547123 0089 SEA RAY BOATS, INC. TEL19 -84.265547123 0089 SEA RAY BOATS, INC. TEL20 -84.265547123 0089 SEA RAY BOATS, INC. TEL21 -84.265547123 0089 SEA RAY BOATS, INC. TEL22 -84.265547123 0089 SEA RAY BOATS, INC. TEL23 -84.265547123 0089 SEA RAY BOATS, INC. TEL24 -84.265547123 0089 SEA RAY BOATS, INC. TEL25 -84.265547123 0089 SEA RAY BOATS, INC. TEL26 -84.265547123 0089 SEA RAY BOATS, INC. TEL27 -84.265547123 0089 SEA RAY BOATS, INC. TEL28 -84.265547123 0089 SEA RAY BOATS, INC. TEL29 -84.265547123 0089 SEA RAY BOATS, INC. TEL30 -84.265547123 0089 SEA RAY BOATS, INC. TEL31 -84.265547123 0089 SEA RAY BOATS, INC. TEL32 -84.265547123 0089 SEA RAY BOATS, INC. TEL33 -84.265547123 0089 SEA RAY BOATS, INC. TEL34 -84.265547123 0089 SEA RAY BOATS, INC. TEL35 -84.2655

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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ID Facility Name Release Point ID Long 

47123 0089 SEA RAY BOATS, INC. TEL36 -84.265547123 0089 SEA RAY BOATS, INC. TEL37 -84.265547123 0089 SEA RAY BOATS, INC. TEL38 -84.265547123 0089 SEA RAY BOATS, INC. TEL39 -84.265547123 0089 SEA RAY BOATS, INC. TEL40 -84.265547123 0089 SEA RAY BOATS, INC. TEL41 -84.265547123 0089 SEA RAY BOATS, INC. TEL42 -84.265547123 0089 SEA RAY BOATS, INC. TEL44 -84.265547123 0089 SEA RAY BOATS, INC. TEL46 -84.265547123 0089 SEA RAY BOATS, INC. TEL48 -84.265547123 0089 SEA RAY BOATS, INC. TEL49 -84.265547123 0089 SEA RAY BOATS, INC. TEL50 -84.265547123 0096 TENNESSEE WATERCRAFT INC. EP-1 -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-2A -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-2B -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-3A -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-3B -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-3C -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-3D -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-4A -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-4B -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-4C -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-4D -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-4E -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-4F -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-4G -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-4H -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-5A -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-5B -84.25447123 0096 TENNESSEE WATERCRAFT INC. EP-5C -84.254

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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47123 0096 TENNESSEE WATERCRAFT INC. EP-5D -84.25447123 0096 TENNESSEE WATERCRAFT INC. ES-2 -84.25447147 0055 ELECTROLUX MAJOR APPLICANCES NORTH AMERICA S-026 -86.87047147 0055 ELECTROLUX MAJOR APPLICANCES NORTH AMERICA S-028 -86.87047147 0055 ELECTROLUX MAJOR APPLICANCES NORTH AMERICA S-041 -86.87047149 0155 NISSAN NORTH AMERICA, INC. FUG-22 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. FUG-93 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. FUG-97 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. NG65 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S1P107 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S1P109 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S1P19 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S1P26 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S1P4 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S1P41 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S1P6 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S1P61 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P1 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P10 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P16 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P23 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P27 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P37 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P4 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P54 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P55 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S2P6 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S3P10 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. S3P12 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. SO05 -86.4923143386

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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State Fac 

ID Facility Name Release Point ID Long 

47149 0155 NISSAN NORTH AMERICA, INC. SOB3 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. SOS3 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. SPP3 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. SPP4 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. TC1 -86.492314338647149 0155 NISSAN NORTH AMERICA, INC. TC23 -86.492314338647149 0172 STRATOS (JAVELIN_2 BOATS) 65978 -86.382547149 0172 STRATOS (JAVELIN_2 BOATS) 65979 -86.382547149 0172 STRATOS (JAVELIN_2 BOATS) 65980 -86.382547149 0172 STRATOS (JAVELIN_2 BOATS) S-014 -86.382547153 0034 TECUMSEH PRODUCTS CO. S-001 -85.378847153 0034 TECUMSEH PRODUCTS CO. S-002 -85.378847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A01 -86.55847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A02 -86.55847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A03 -86.55847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A04 -86.558747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A05 -86.558747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A06 -86.558747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A07 -86.558747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A08 -86.558747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A09 -86.558747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C01 -86.55747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C02 -86.55747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C03 -86.55747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C04 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C05 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C06 -86.55747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C07 -86.55747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C08 -86.55747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87D01 -86.5577

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

48-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

47165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87D02 -86.557747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87D03 -86.557747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87E01 -86.55747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87E02 -86.55747167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION PT-3 -89.6247167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION PT-4 -89.6247167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION PT-5 -89.6247167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION REECO1 -89.6247167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION REECO2 -89.6251001 00012 A and N Electric Cooperative - Tangier Island 1 -7551001 61414 Old Dominion Electric Cooperative - UNIT 9 1 51001 61415 Old Dominion Electric Cooperative - UNIT 10 1 51003 00099 Virginia Industries for the Blind 1 -78.473051019 00001 Rubatex International LLC 1 -79.551027 11159 Equitable Production Co-Hurricane 2 -8251031 00006 Babcock & Wilcox Nuclear Operations Group Inc 21 -79.0551065 00001 Dominion - Bremo Power Station 1 -78.2851075 00030 INGENCO - Rockville Plant 1 -77.664051081 00001 Emporia Foundry Incorporated 1 -77.533551081 00011 Belding Hausman Inc - Weldon Mill 1 -77.557951081 00020 Georgia Pacific Wood Products - Emporia - Plywood 1 -77.524651085 00042 Bear Island Paper Company LLC 17 -77.438851095 00023 HRSD - Williamsburg Sewage Treatment Plant 1 -76.62951101 00001 Stone Container Enterprises dba Smurfit-Stone Cont 1 -76.8051101 00004 West Point Veneer LLC 1 -76.807051101 00021 Old Dominion Grain 1 -76.81551101 00023 Augusta Wood Products LC - Sawmill 1 -76.833851101 00027 West Point Chips Incorporated 1 -76.8051121 00006 Alliant Techsystems Inc 2 -80.54151121 00091 Thermasteel Corporation 1 -80.566

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

49-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

51133 00013 Waller, R P Oil BP 1 -76.251153 00002 Dominion - Possum Point Power Station 10 -77.280851153 00011 Prince William Hospital Corporation 5 -77.485051153 00021 LOCKHEED MARTIN MANASSAS 11 -77.551153 00814 BAE Systems 1 -77.497051153 00889 Architect of the Capitol 2 -77.513251161 00011 Adams Construction Co - Rockydale 1 -79.9451161 00015 Double Envelope Company 1 -79.9551165 00069 Adams Construction Company 1 -78.741551165 00106 Transprint USA Inc 1 -78.900051179 00020 FBI Academy 1 -77.290251191 00044 Universal Fibers Inc. 1 -82.1051195 00089 P M Terminals Inc -Buck Oil Co 1 -82.351515 00038 Wheelabrator Abrasives Incorporated 21 -79.55351520 00018 Strongwell Corporation/Bristol Division 6 -82.1751620 00011 Franklin City - Electric Dept - Mechanic Street 1 -76.919751640 00002 Turman Hardwood Flooring Inc. 5 -80.9351650 00007 US Air Force Base Langley 15 -76.3551650 00011 US Department of Veterans Affairs Medical Ctr 1 -76.3351650 00093 Bethel Landfill (USA Waste of Virginia) 1 -76.426351683 00003 Glen-Gery Corporation - Capitol Plant 1 -77.5051683 00090 City of Manassas/VMEA 1 -77.508051690 00050 Southern Finishing 1 -79.854651700 00013 Northrop Grumman Shipbuilding Incorporated 28 -76.435551700 00071 Kinder Morgan Bulk Terminals - Pier IX 1 -76.432751710 00009 Ford Motor Company Norfolk Plant 6 -76.252851710 00068 U S Gypsum Co 1 -76.285651710 00113 J H Miles & Company Incorporated 1 -76.305551710 00249 Lyon Shipyard, Incorporated - Brown Ave 1 -76.27251710 00251 Lyon Shipyard Incorporated - Sealift Drydock 1 -76.2650

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

50-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

51740 00037 Fleet & Industrial Supply Center 1 -76.375051760 00098 Kinder Morgan Southeast Terminals-Rchmd Terminal 10 -77.426851760 00399 Spruance Genco LLC 1 -77.426851760 00489 Motiva Enterprises LLC-Richmond Terminal 1 -77.445351810 00013 US Navy - Joint Expeditionary Base - Little Creek 1 -76.1451810 00034 HRSD Chesapeake-Elizabeth Sewage Treatment Plant 1 -76.164754029 5402900001 ARCELORMITTAL WEIRTON INC. 107 -80.6054029 5402900001 ARCELORMITTAL WEIRTON INC. 108 -80.6054029 5402900001 ARCELORMITTAL WEIRTON INC. 109 -80.6054029 5402900001 ARCELORMITTAL WEIRTON INC. 111 -80.6054029 5402900001 ARCELORMITTAL WEIRTON INC. 112 -80.60

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Appendix B: Comparison of Original EGU Emissions Prepared by AMEC (V_1_10) with 

Emissions Prepared by WV DAQ (v_1_10a) 

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 983
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

1-B 

Facility Name 

State 

County 

FIPS 

State Facility 

Identifier 

Emission 

Unit ID 

Process 

ID SCC 

Pollutant 

Code 

E

Appalachian Power - John E Amos Plant 

54079 5407900006 001 1 10100202 PM10-PRI 

Appalachian Power - John E Amos Plant 

54079 5407900006 001 1 10100202 PM25-PRI 

Appalachian Power - John E Amos Plant 

54079 5407900006 002 1 10100202 PM10-PRI 

Appalachian Power - John E Amos Plant 

54079 5407900006 002 1 10100202 PM25-PRI 

Appalachian Power - John E Amos Plant 

54079 5407900006 003 1 10100202 PM10-PRI 

Appalachian Power - John E Amos Plant 

54079 5407900006 003 1 10100202 PM25-PRI 

Appalachian Power - Kanawha River Plant 

54039 5403900006 001 1 10100202 PM10-PRI 

Appalachian Power - Kanawha River Plant 

54039 5403900006 001 1 10100202 PM25-PRI 

Appalachian Power - Kanawha River Plant 

54039 5403900006 002 1 10100202 PM10-PRI 

Appalachian Power - Kanawha River Plant 

54039 5403900006 002 1 10100202 PM25-PRI 

Appalachian Power - Mountaineer Plant 

54053 5405300009 001 1 10100202 PM10-PRI 

Appalachian Power - Mountaineer Plant 

54053 5405300009 001 1 10100202 PM25-PRI 

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 001 1 10100202 PM10-PRI 

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 001 1 10100202 PM25-PRI 

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 002 1 10100202 PM10-PRI 

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 002 1 10100202 PM25-PRI 

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 003 1 10100202 PM10-PRI 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

2-B 

Facility Name 

State 

County 

FIPS 

State Facility 

Identifier 

Emission 

Unit ID 

Process 

ID SCC 

Pollutant 

Code 

E

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 003 1 10100202 PM25-PRI 

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 004 1 10100202 PM10-PRI 

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 004 1 10100202 PM25-PRI 

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 005 1 10100202 PM10-PRI 

Appalachian Power Co.-Philip Sporn Plant 

54053 5405300001 005 1 10100202 PM25-PRI 

Monongahela Power Co - Albright P.S. 

54077 5407700001 001 1 10100202 PM10-PRI 

Monongahela Power Co - Albright P.S. 

54077 5407700001 001 1 10100202 PM25-PRI 

Monongahela Power Co - Albright P.S. 

54077 5407700001 002 1 10100202 PM10-PRI 

Monongahela Power Co - Albright P.S. 

54077 5407700001 002 1 10100202 PM25-PRI 

Monongahela Power Co - Albright P.S. 

54077 5407700001 003 1 10100212 PM10-PRI 

Monongahela Power Co - Albright P.S. 

54077 5407700001 003 1 10100212 PM25-PRI 

Monongahela Power Co. - Rivesville Ps 

54049 5404900009 001 1 10100202 PM10-PRI 

Monongahela Power Co. - Rivesville Ps 

54049 5404900009 001 1 10100202 PM25-PRI 

Monongahela Power Co. - Rivesville Ps 

54049 5404900009 002 1 10100202 PM10-PRI 

Monongahela Power Co. - Rivesville Ps 

54049 5404900009 002 1 10100202 PM25-PRI 

Monongahela Power Co.- Fort Martin Power 

54061 5406100001 001 1 10100212 PM10-PRI 

Monongahela Power Co.- Fort Martin Power 

54061 5406100001 001 1 10100212 PM25-PRI 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

3-B 

Facility Name 

State 

County 

FIPS 

State Facility 

Identifier 

Emission 

Unit ID 

Process 

ID SCC 

Pollutant 

Code 

E

Monongahela Power Co.- Fort Martin Power 

54061 5406100001 002 1 10100202 PM10-PRI 

Monongahela Power Co.- Fort Martin Power 

54061 5406100001 002 1 10100202 PM25-PRI 

Monongahela Power Co.-Willow Island 

54073 5407300004 001 1 10100202 PM10-PRI 

Monongahela Power Co.-Willow Island 

54073 5407300004 001 1 10100202 PM25-PRI 

Monongahela Power Co.-Willow Island 

54073 5407300004 002 1 10100203 PM10-PRI 

Monongahela Power Co.-Willow Island 

54073 5407300004 002 1 10100203 PM25-PRI 

Monongahela Power CoHarrison 54033 5403300015 001 1 10100202 PM10-PRI Monongahela Power CoHarrison 54033 5403300015 001 1 10100202 PM25-PRI Monongahela Power CoHarrison 54033 5403300015 002 1 10100202 PM10-PRI Monongahela Power CoHarrison 54033 5403300015 002 1 10100202 PM25-PRI Monongahela Power CoHarrison 54033 5403300015 003 1 10100202 PM10-PRI Monongahela Power CoHarrison 54033 5403300015 003 1 10100202 PM25-PRI Monongahela Power CoPleasants Power Sta 54073 5407300005 001 1 10100202 PM10-PRI Monongahela Power CoPleasants Power Sta 54073 5407300005 001 1 10100202 PM25-PRI Monongahela Power CoPleasants Power Sta 54073 5407300005 002 1 10100202 PM10-PRI Monongahela Power CoPleasants Power Sta 54073 5407300005 002 1 10100202 PM25-PRI Mount Storm Power Station 54023 5402300003 001 1 10100212 PM10-PRI Mount Storm Power Station 54023 5402300003 001 1 10100212 PM25-PRI 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

4-B 

Facility Name 

State 

County 

FIPS 

State Facility 

Identifier 

Emission 

Unit ID 

Process 

ID SCC 

Pollutant 

Code 

E

Mount Storm Power Station 54023 5402300003 002 1 10100212 PM10-PRI Mount Storm Power Station 54023 5402300003 002 1 10100212 PM25-PRI Mount Storm Power Station 54023 5402300003 003 1 10100212 PM10-PRI Mount Storm Power Station 54023 5402300003 003 1 10100212 PM25-PRI North Branch Power Station 

54023 5402300014 001 1 10100217 PM10-PRI 

North Branch Power Station 

54023 5402300014 001 1 10100217 PM25-PRI 

North Branch Power Station 

54023 5402300014 002 1 10100217 PM10-PRI 

North Branch Power Station 

54023 5402300014 002 1 10100217 PM25-PRI 

Ohio Power - Kammer Plant 

54051 5405100006 001 1 10100203 PM10-PRI 

Ohio Power - Kammer Plant 

54051 5405100006 001 1 10100203 PM25-PRI 

Ohio Power - Kammer Plant 

54051 5405100006 002 1 10100203 PM10-PRI 

Ohio Power - Kammer Plant 

54051 5405100006 002 1 10100203 PM25-PRI 

Ohio Power - Kammer Plant 

54051 5405100006 003 1 10100203 PM10-PRI 

Ohio Power - Kammer Plant 

54051 5405100006 003 1 10100203 PM25-PRI 

Ohio Power - Mitchell Plant 54051 5405100005 001 1 10100202 PM10-PRI Ohio Power - Mitchell Plant 54051 5405100005 001 1 10100202 PM25-PRI Ohio Power - Mitchell Plant 54051 5405100005 002 1 10100202 PM10-PRI Ohio Power - Mitchell Plant 54051 5405100005 002 1 10100202 PM25-PRI 

Notes: v_1_10 values based on PM augmentation by AMEC of PM filterable data provided by WV DAQv_1_10a values calculated from emission factors ba

emissions to CAMD 2002 heat inputs. Those factors were applied to 2007 CAMD heat inputs. 

 At the time WV DAQ requested that its data replace the original AMEC data, DAQ believed that the same methodology was necessary between its 2

2007 SEMAP inventory. That belief later turned out to be incorrect. Therefore, the SEMAP 2007 inventory that was modeled reflectsdifferent methodused for the other SEMAP states. 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
AREA AND NONROAD 2007 BASE YEAR INVENTORIES

REVISED FINAL REPORT

Contract No. S-2009-06-01 

January 2012 

Prepared for: 

Ronald C. Methier 

Southeastern States Air Resource Managers, Inc. 

526 Forest Parkway, Suite F 

Forest Park, GA 30297-6140 

Prepared by: 

TranSystems Corporation 

3622 Lyckan Parkway, Suite 2005 

Durham, NC 27707 

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 988
[This page intentionally left blank.]

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 989
January 2012 

Final Report iii

CONTENTS 

Page 

TABLES ........................................................................................................................................................................ iv

FIGURES ...................................................................................................................................................................... iv

I. INTRODUCTION .................................................................................................................................................. 1

II. STATIONARY AREA SOURCE INVENTORY ...................................................................................................... 3

A. AGENCY SUPPLIED INVENTORY DATA .................................................................................................. 3

B. DEVELOPMENT OF TRANSYSTEMS DEFAULT 2007 AREA SOURCE INVENTORY ............................ 5

1. 2008 Nonpoint Source NEI .............................................................................................................. 5

a. Adjustment of NEI Data to Reflect 2007 Activity Levels ............................................................... 11

b. Adjustment of NEI Data to Remove Activity Reflected in the Point Source Inventory .................. 11

2. Estimation of Area Source Emissions from Industrial and Commercial/Institutional Fuel 

 Combustion ................................................................................................................................... 16

a. Total ICI Energy Consumption ..................................................................................................... 18

b. Stationary Source Energy Consumption ...................................................................................... 18

c. Non-Fuel Energy Consumption .................................................................................................... 22

d. Emission Factors ......................................................................................................................... 23

e. Coal Sulfur and Ash Content ....................................................................................................... 25

f. County Allocation Data ................................................................................................................ 27

3. Estimation of Area Source Emissions from Residential Wood Combustion .................................. 29

4. Estimation of Area Source Emissions from Gasoline Service Stations/Stage I ............................. 34

C. INVENTORY SUPPLEMENTATION/FINAL DATA MERGING ................................................................. 34

D. QA/QC PROCEDURES ............................................................................................................................ 39

III. 2007 NONROAD MOBILE SOURCE INVENTORY ................................................................................................ 40

A. NONROAD MODEL CATEGORIES .......................................................................................................... 40

B. AIRCRAFT ................................................................................................................................................ 42

C. COMMERCIAL MARINE VESSELS .......................................................................................................... 43

D. LOCOMOTIVES ........................................................................................................................................ 47

E. QA/QC PROCEDURES ............................................................................................................................ 48

IV. EMISSIONS SUMMARIES ................................................................................................................................. 51

A. STATIONARY AREA SOURCE EMISSIONS ........................................................................................... 51

B. NONROAD MOBILE SOURCE EMISSIONS ............................................................................................ 56

V. REFERENCES ................................................................................................................................................... 61

APPENDIX A. POINT SOURCE SUBTRACTION PROCEDURE DETAILS ....................................................... A-1

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 990
January 2012 

Final Report iv

TABLES 

Table II-1. Overview of Area Source Inventory Components by State/Local Agency ................................................... 4

Table II-2. 2008 NEI Area Source Categories for Which EPA Has Developed Emission Estimates ............................. 6

Table II-3. Methods for Updating 2008 NEI Estimates that Are Not Based on 2007 Emissions Activity ..................... 12

Table II-4. Throughput-Based Area Source Emission Adjustments ............................................................................ 16

Table II.5. ICI Fuel Combustion Area Source Classification Codes ............................................................................ 17

Table II-6. LPG Nonroad Mobile Source Classification Codes .................................................................................... 19

Table II-7. Assumptions Used to Estimate Industrial Sector Stationary Source Distillate Fuel Consumption ............. 22

Table II-8. Assumptions Used to Estimate Commercial/Institutional Sector Stationary Source 

Distillate Fuel Consumption ......................................................................................................................................... 22

Table II-9. Industrial Sector Energy Consumption from Non-Fuel Uses...................................................................... 23

Table II-10. Criteria Pollutant Emission Factors for ICI Combustion Area Source Categories .................................... 24

Table II-11. Bituminous/Subbituminous Coal Sulfur Content for 2007 ICI Combustion .............................................. 26

Table II-12. Anthracite Coal Ash and Sulfur Content for 2007 ICI Combustion ........................................................... 26

Table II-13. Summary of Data Carried Forward/Grown From 2002 NEI ..................................................................... 36

Table II-14. Area Source Inventory Data Source Codes ............................................................................................. 39

Table III-1. Summary of 2007 NCD Tables and State Comments............................................................................... 41

Table III-2. Aircraft Source Classification Codes ......................................................................................................... 42

Table III-3. Summary of State Updates to Aircraft Category Emissions ...................................................................... 43

Table III-4. Category 1 & CMV Growth Factors, by Pollutant ...................................................................................... 44

Table III-5. Category 3 CMV Growth Factors, by State and SCC ............................................................................... 45

Table III-6. Summary of State Updates to Commercial Marine Category Emissions .................................................. 46

Table III-7. Summary of State Updates to Locomotive Category Emissions ............................................................... 49

Table III-8. Data Source Codes Used for Final 2007 Nonroad Mobile Emission Estimates ........................................ 50

Table IV-1. Final 2007 SESARM Area Source Emissions by Major Sector ................................................................ 51

Table IV-2. Final 2007 Area Source Emission Estimates by State ............................................................................. 52

Table IV-3. Final 2007 Combustion Emission Estimates by State .............................................................................. 53

Table IV-4. Final 2007 Solvent Emission Estimates by State ..................................................................................... 54

Table IV-5. Final 2007 Fugitive Dust Emission Estimates by State ............................................................................ 55

Table IV-6. Final 2007 All Other Area Source Emission Estimates by State............................................................... 56

Table IV-7. Final 2007 SESARM Nonroad Source Emissions by Major Sector .......................................................... 57

Table IV-8. Final 2007 NONROAD Model Emission Estimates by State .................................................................... 57

Table IV-9. Final 2007 Aircraft Emission Estimates by State ...................................................................................... 58

Table IV-10. Final 2007 Commercial Marine Vessel Emission Estimates by State ..................................................... 59

Table IV-11. Final 2007 Locomotive Emission Estimates by State ............................................................................. 60

Table A-1. Industrial Fuel Combustion Crosswalk for Point Source Subtractions. .................................................... A-3

Table A-2. Commercial/Institutional Fuel Combustion Crosswalk for Point Source Subtractions ........................... A-12

Table A-3. Construction Crosswalk for Point Source Subtractions ......................................................................... A-15

Table A-4. Publicly Owned Treatment Works Crosswalk for Point Source Subtractions ........................................ A-16

Table A-5. Solvent Utilization Crosswalk for Point Source Subtractions ................................................................. A-17

Table A-6. Gasoline Distribution Crosswalk for Point Source Subtractions ............................................................ A-32

Table A-7. Mining and Quarrying Crosswalk for Point Source Subtraction ............................................................. A-38

Table A-8. Agriculture Production Crosswalk for Livestock ..................................................................................... A-41

FIGURES 

Figure 1. Decision Tree for Assigning Regional Average (Default) or National Urban Appliance Profile .................... 31

Figure 2. Decision Tree for Assigning Average (Default), Urban, or Rural Burn Profiles ............................................ 33

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 991
January 2012 

1 Final Report

I. INTRODUCTION 

TranSystems is supporting the Southeastern States Air Resource Managers, Inc. (SESARM) in the Southeastern 

Modeling, Analysis, and Planning (SEMAP) project that is funded by the same ten states originally involved in the 

Visibility Improvement – State and Tribal Association of the Southeast (VISTAS) project. The SEMAP project 

addresses the next phase of ozone, fine particle, and regional haze assessment obligations of the SESARM member 

states. The SEMAP project is designed to produce technical analyses to aid the participating agencies in developing 

State Implementation Plans (SIPs) required by the Clean Air Act. 

In June 2010, TranSystems developed a set of “final” 2007 area and nonroad source base year inventory emission 

estimates (Pechan, 2010). These estimates are reported by county and source classification code (SCC), and were 

developed using data from a number of sources: 

• State/Local (S/L) agency emissions data; 

• 2007 year emissions data compiled from running EPA’s NONROAD model with a combination of EPA 

default and S/L agency-supplied inputs; 

• 2007 area source emissions estimated by TranSystems, generally developed using the emissions 

estimation procedures used to prepare EPA’s draft 2008 National Emissions Inventory (NEI);1

• 2007 industrial and commercial/institutional (ICI) fuel combustion emission estimates developed by 

TranSystems; 

• 2008 commercial marine vessel and aircraft emission estimates from EPA’s draft 2008 NEI, modified by 

TranSystems to reflect 2007 activity levels; 

• 2007 switchyard and Class I line-haul locomotive estimates provided by the Eastern Regional Technical 

Advisory Committee (ERTAC); and 

• 2008 ERTAC Class II/III line-haul locomotive emission estimates, modified by TranSystems to reflect 2007 

activity levels. 

Because EPA had not developed draft 2008 NEI emission estimates for Agricultural Tilling, Mining and Quarrying, 

and Pesticide Application at the time that the final area/nonroad source inventory was prepared, the final area source 

inventory also incorporated guidance from S/L agencies as to whether to incorporate emission estimates carried 

forward or grown2

 from EPA’s 2002 area source NEI for these source categories. For ICI fuel combustion and other 

NEI source categories for which draft emission estimates reflected total emissions activity, it was necessary for 

TranSystems to perform point source subtractions to develop estimates of the emissions from area sources. These 

point source subtractions were performed using version 1.3 of the 2007 SEMAP point source inventory.

Since the final area source inventory was prepared in June 2010, SESARM requested that TranSystems incorporate 

additional S/L agency feedback into a revised final area source inventory. This feedback included direction to use 

updated agency emissions data, and to revise/remove other emission estimates. In the latter case, feedback 

included direction to replace S/L agency estimates with TranSystems defaults, and to remove emission estimates for 

specific fire source categories: Open Burning of Land Clearing Debris; Agricultural Field Burning; Forest Wildfire; 

and Prescribed Burning (these source categories are covered by a separate fire inventory developed by a different 

SESARM contractor).3

 For two source categories, Residential Wood Combustion and Stage I Gasoline Service 

Stations, SESARM directed TranSystems to develop new emission estimates reflecting changes to some of the 

inputs that had been used to develop the 2008 area source NEI emission estimates. In addition, SESARM directed 

 

1 2008 NEI methods rely on Eastern Regional Technical Advisory Committee (ERTAC) methods when available.

2

 Based on direction from S/L agencies, some 2002 NEI emission estimates were projected to 2007 using emission activity 

growth factors from Version 5.0 of the Economic Growth Analysis System (EGAS) (EPA, 2010).

3

In the case of Open Burning of Land Clearing Debris and Agricultural Field Burning, TranSystems provided the contractor 

(AMEC) with a file containing the final area source inventory’s emission estimates.

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 992
January 2012 

2 Final Report

TranSystems to re-perform the point source subtractions using an updated version (1.10a) of the SEMAP 2007 point 

source inventory. 4, 5

 

Changes to the final nonroad mobile source inventory were relatively modest, with the only major change relating to 

the development of updated NONROAD model emission estimates for Virginia using a new set of Reid vapor

pressure (RVP) values provided by the State.

The following sections provide additional details on the inventory development process. The major topics that are 

discussed are: 

• How TranSystems identified source categories and/or pollutants that may have been missing from the S/L 

agency supplied data; 

• How TranSystems integrated data from the various emission data sources (i.e., S/L agencies, TranSystems 

defaults, ERTAC, and 2008 and 2002 NEI); and 

• How TranSystems quality assured the integrated emissions inventory. 

The balance of this report is organized as follows. Section II describes the development of the stationary area source 

sector inventory. The development of the nonroad mobile source sector inventory is described in Section III. 

Section IV presents the area and nonroad source emission summaries for the final 2007 base year inventory for the 

SEMAP project. Section V presents the references that were consulted in preparing the revised final inventory. 

 

4 As requested, TranSystems performed the point source subtractions for Georgia at the State-level (per Georgia’s earlier 

direction, the final inventory had performed these subtractions at the county-level). 

5

It should be noted that although EPA recently developed emissions estimates for Agricultural Tilling, Mining and Quarrying, and 

Pesticide Application, and also incorporated revisions to the draft NEI emission estimates for Open Burning of Household Waste 

(2610030000) and Yard Waste (2610000100 and 2610000400), and Fugitive Dust from Paved Roads (2294000000), SESARM 

elected not to incorporate these updates into the revised final area source inventory.

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 993
January 2012 

3 Final Report

II. STATIONARY AREA SOURCE INVENTORY 

TranSystems developed the revised final 2007 base year area source inventory for the SEMAP project from a 

combination of six sources: 

1) S/L agency supplied area source emissions data; 

2) TranSystems 2007 area source emission estimates developed using the emission estimation methods from 

the 2008 NEI with adjustments to reflect 2007 emissions activity and to subtract point source emissions; 

3) TranSystems 2007 industrial and commercial/institutional fuel combustion area source emission estimates

specifically developed for the SESARM states; 

4) TranSystems 2007 emission estimates for gasoline service stations/stage I unloading; 

5) TranSystems 2007 emission estimates using EPA’s residential wood combustion tool with SESARMidentified modifications, and 

6) Area source emission estimates carried forward or grown from EPA’s 2002 nonpoint source NEI. 

Table II-1 summarizes how these data sources were merged to create a comprehensive stationary area source 

inventory for jurisdictions covered by the SEMAP project. The following sections provide more specifics on the 

contents of each of these data sources and how they were combined into the final 2007 area source inventory. 

A. AGENCY SUPPLIED INVENTORY DATA 

TranSystems commenced area source inventory development work by providing S/L agencies with a Technical 

Memorandum documenting the emission estimation methods and data TranSystems was using to develop the U.S. 

Environmental Protection Agency (EPA)’s 2008 nonpoint source NEI (Pechan, 2009a). The purpose of this 

memorandum was to provide agencies with information to: (1) review and comment on the methods/data, and 

(2) assist agencies in evaluating the merits of the NEI methods/data relative to any S/L area source inventory 

development efforts. State and local agencies were then provided with several months to compile and transmit area 

source emissions data to TranSystems. 

Two state agencies (North Carolina and Virginia) and two local agencies (Jefferson County, Kentucky and Davidson 

County, Tennessee) provided area source data for the draft area source inventory (two additional local agencies 

provided data for the final area source inventory – Knox County and Shelby County, Tennessee). After receiving 

these S/L agency data, TranSystems compared the source classification code (SCC) and pollutant coverage of these 

submittals against the SCCs/pollutants in the 2007 emissions data that TranSystems was developing for this project 

(hereafter referred to as the “TranSystems default inventory”). 

To assist in obtaining direction from SESARM agencies on how to merge the data from these sources, TranSystems 

first identified the SCC/pollutant combinations in the TranSystems default inventory that matched to S/L agency data. 

Next, TranSystems reviewed remaining S/L agency SCC/pollutant combinations against TranSystems defaults to 

identify whether it may be possible that these emissions were covered in the TranSystems default inventory under 

different SCCs. TranSystems then developed a list of potential indirect matches between the two data sets for 

agency review. This list was compiled in an Excel worksheet. Next, TranSystems developed a separate worksheet 

that listed SCC/pollutant combinations in the S/L supplied area source inventory that we were unable to either directly 

or indirectly match to combinations in the TranSystems default inventory. A list of SCC/pollutant combinations in the 

TranSystems default inventory that we were unable to directly or indirectly match to combinations in the S/L agency 

inventory was also prepared in a separate worksheet. Finally, TranSystems developed a worksheet that contained 

all S/L agency inventory SCC/pollutant combinations with emissions equal to “0.” The above worksheets were saved 

in a single Excel workbook for each Agency. In addition to these workbooks, TranSystems transmitted a Word 

document identifying questions on how two merge the two data sets (e.g., where S/L agency emissions are reported 

as zero, should TranSystems replace any of these with emissions from the TranSystems default inventory?). After 

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 994
4 

Table II-1. Overview of Area Source Inventory Components by State/Local Agency 

Alabama Florida Georgia 

KentuckyJefferson 

County 

KentuckyRest of State Mississippi North Carolina South Carolina 

TennesseeDavidson 

County 

TennesseeKnox County

TennesseeShelby 

County 

Agency 

Contact 

Lisa 

Cole/Tracy 

Anderson 

Kelly Stevens Byeong Kim Craig Butler Martin Luther Elliott Bickerstaff Phyllis Jones Carla Bedenbaugh John Finke Steve McDaniel Chris Boyd 

Source of 

Emissions 

Data 

Combination of Agency data 

and TranSystems defaults, supplemented 

with categories from 2002 NEI 

grown using EGAS 

TranSystems

defaults, supplemented 

with categories 

from 2002 NEI (combination of EGAS and carry forward) 

TranSystems

defaults, supplemented with categories from 2005 GA Consolidated Emissions Reporting Rule (CERR) submittal grown using EGAS 

Combination of 

Agency data 

and TranSystems defaults. 

TranSystems

defaults, supplemented 

with categories 

from 2002 NEI grown using EGAS 

TranSystems

defaults, supplemented 

with categories 

from 2002 NEI (combination of EGAS and carry forward) 

Combination 

of Agency data and TranSystems defaults. 

TranSystems

defaults, supplemented with categories 

from 2002 NEI 

grown using EGAS 

Combination 

of Agency data and TranSystemsdefaults. 

Combination 

of Agency data and TranSystems defaults, supplemented with categories from 2002 NEI(emissions carried forward) 

Agency data 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
January 2012 

5 Final Report

reviewing S/L agency responses to these questions, TranSystems transmitted any follow-up questions that were 

necessary to clarify S/L agency guidance. 

B. DEVELOPMENT OF TRANSYSTEMS DEFAULT 2007 AREA SOURCE INVENTORY 

TranSystems created a default 2007 area source inventory that included all of the source categories covered by the 

2008 nonpoint source NEI as of early 2010. For all these source categories except industrial and 

commercial/institutional (ICI) fuel combustion, stage I gasoline service stations, and residential wood combustion, 

TranSystems either directly incorporated emissions data from the 2008 nonpoint source NEI (when the NEI

represented use of 2007 emissions activity data), or recalculated the NEI emission estimates to reflect 2007 activity 

levels (when the NEI reflected 2006 or 2008 activity levels) and/or removed the emissions associated with activity 

reflected in the point source inventory. As of early 2010, the 2008 nonpoint source NEI had only developed ICI fuel 

combustion emissions activity estimates, not emission estimates. Because of their potential importance and the 

availability of methodological improvements, TranSystems utilized an emissions estimation method for ICI fuel 

combustion that incorporated a few refinements to the NEI method. For stage I gasoline service stations, we 

developed emission estimates for this project using the NEI methods in combination with inputs reviewed and 

approved by S/L agencies. For residential wood combustion (RWC), TranSystems updated the emission estimates 

by running EPA’s RWC emissions estimation tool with updates to the tool’s wood consumption and wood-burning 

appliance profile/allocation assumptions. The following section discusses how information from the 2008 nonpoint 

source NEI was used in this project. The subsequent sections provide details on the methods used to estimate 

emissions from ICI fuel combustion, stage I gasoline service stations, and residential wood combustion. 

1. 2008 Nonpoint Source NEI 

TranSystems supported EPA efforts to develop the 2008 nonpoint source NEI. Because of data availability issues, 

the 2008 NEI is comprised of data of various vintages (2006-2008). Table II-2 provides documentation of the 2008 

nonpoint source NEI, which is as follows: 

(1) Source Category – identifies the name of each general source category covered. 

(2) Source Classification Code(s) – lists the SCCs that are inventoried. 

(3) Source Classification Code Description – provides a description of each SCC. 

(4) Link to Emission Calculation Documentation – provides links to the detailed documentation of the NEI 

methods;6

(5) Link to Emission Calculation Workbook – provides a link to the draft 2008 NEI emissions or activity data; 

(6) Year of Activity Data – identifies the year represented by the emissions activity data; and 

(7) Point Source Component – signifies whether a portion of the source category’s emissions may be included 

within the point source inventory. 

When work commenced on the revised final base year inventory in late 2011, TranSystems notified SESARM of the 

availability of 2008 NEI emission estimates for the following additional area source categories: Agricultural Tilling, 

Mining and Quarrying, and Pesticide Application. SESARM directed TranSystems not to incorporate the 2008 NEI 

emission estimates for these categories. In lieu of such updates, the SEMAP emission estimates for these source 

categories reflect direction from S/L agencies as to whether to incorporate estimates based on emissions reported in 

the 2002 NEI. In such cases where these categories were identified for inclusion, agencies also provided direction 

as to whether the 2002 NEI emissions should be carried forward to represent 2007 emissions, or projected to 2007 

using growth factors from the Economic Growth Analysis Systems (EGAS).

 

6 Left clicking on the hyperlink while simultaneously pressing the control key allows one to open or save the documentation/data 

of interest. The complete list of material can be accessed at: http://projects.pechan.com/EPA/Non-Point_Emission_Estimates/. 

Note that in some cases, this documentation reflects revisions that EPA incorporated after the NEI data were compiled for this 

project: SESARM opted not to incorporate NEI revisions for Open Burning of Household Waste (2610030000) and Yard Waste 

(2610000100 and 2610000400), and Fugitive Dust from Paved Roads (2294000000). 

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 996
6 

Table II-2. 2008 NEI Area Source Categories for Which EPA Has Developed Emission Estimates 

Source Category Source Classification Code(s) Source Classification Code Description Link to Emission Calculation Documentation Link to Emission Calc

Workbook 

Agriculture Production – Livestock 28050nnnnn Livestock Agriculture_Production_Livestock_28050 nnnnn_Documentation.zip Agriculture_Production_Liv

50nnnnn_Emissions

Asphalt Paving 

2461021000 Cutback Asphalt Asphalt_Paving_Cutback_2461021000_ Documentation.zip Asphalt_Paving_Cutback_2

_Emissions.zip 

2461022000 Emulsified Asphalt Asphalt_Paving_Emulsified_2461022000 _Documentation.zip Asphalt_Paving_Emulsified

00_Emissions.zi

Aviation Gasoline 

Distribution: Stage I 2501080050 Aviation Gasoline: Stage I Aviation_Gasoline_Distribution_Stage_I_ 2501080050_Documentation.zip Aviation_Gasoline_Distribu

_I_2501080050_Emiss

Aviation Gasoline 

Distribution: Stage II 2501080100 Aviation Gasoline: Stage II Aviation_Gasoline_Distribution_Stage_II_ 2501080100_Documentation.zip Aviation_Gasoline_Distribu

_II_2501080100_Emiss

Commercial Cooking 2302002nnn 2302003nnn Commercial Cooking Commercial_Cooking_2302002nnn_Doc umentation.zip Commercial_Cooking_230

missions.zip 

Construction Dust 

2311010000 Residential Construction Residential_Construction_2311010000_ Documentation.zip Residential_Construction_2

_Emissions.zip 

2311020000 Non-Residential Construction

Non- Residential_Construction_2311020000_

Documentation.zip

Non- Residential_Construction_2

_Emissions.zip

2311030000 Road Construction Road_Construction_2311030000_Docum entation.zip Road_Construction_23110

ssions.zip 

Fertilizer Application 28017000nn Fertilizer Application Fertilizer_Application_28017000nn_Docu mentation.zip Fertilizer_Application_280

missions.zip 

Gasoline Distribution 

(SEMAP emissions were 

developed for Stage I 

Gasoline Service Station 

Unloading using NEI 

methods with S/L agency 

approved inputs) 

25010110nn

25010120nn Portable Fuel Containers Portable_Fuel_Containers_25010110nn_ 25010120nn_Documentation.zip Portable_Fuel_Containers_

n_25010120nn_Emiss

2501050120 Gasoline Distribution Stage I; Bulk Terminals Gasoline_Distribution_Stage_I_Documen tation.zip Gasoline_Distribution_Stag

erminals_2501050120_Em

2501055120 Gasoline Distribution Stage I; Bulk Plants Gasoline_Distribution_Stage_I_Documen tation.zip Gasoline_Distribution_Stag

lants_2501055120_Emis

250106005n 

Gasoline Distribution Stage I; 

Gasoline Service Station 

Unloading 

Gasoline_Distribution_Stage_I_Documen

tation.zip

Gasoline_Distribution_Stag

e_Station_Unloading_250

missions.zip

WV SIP Revision: Regional Haze 5-Year Periodic Report 
7 

Source Category Source Classification Code(s) Source Classification Code Description Link to Emission Calculation Documentation Link to Emission Calc

Workbook 

2501060100 Gasoline Distribution Stage II; Gasoline Service Stations Gasoline_Distribution_Stage_II_Docume ntation.zip Gasoline_Distribution_Stag

ne_Service_Stations_2501

missions.zip 

2501060201 

Gasoline Distribution Stage I; 

Underground storage tank, 

breathing and emptying 

Gasoline_Distribution_Stage_I_Documen

tation.zip

Gasoline_Distribution_Stag

reathing_and_Emptying_25

CAP_Emissions.z

2505030120 Gasoline Distribution Stage I; Tank Trucks in Transit Gasoline_Distribution_Stage_I_Documen tation.zip Gasoline_Distribution_Stag

Trucks_in_Transit_250503

sions.zip 

2505040120 Gasoline Distribution Stage I; Pipelines Gasoline_Distribution_Stage_I_Documen tation.zip Gasoline_Distribution_Stag

es_2505040120_CAP_Em

Open Burning 

(NEI emissions for Open 

Burning of Land Clearing 

Debris were transmitted to 

AMEC for incorporation into 

SEMAP’s fire inventory) 

2610000100 Open Burning - Yard Waste - Leaves Open_Burning_Yard_Waste_Leaf_26100 00100_and_Brush_2610000400_Docum entation.zip Open_Burning_Yard_Wast

000100_Emissions

2610000400 Open Burning - Yard Waste - Brush Open_Burning_Yard_Waste_Leaf_26100 00100_and_Brush_2610000400_Docum entation.zip Open_Burning_Yard_Was

61000400_Emission

2610000500 Open Burning - Land Clearing Debris Open_Burning_Land_Clearing_Debris_2 610000500_Documentation.zip Open_Burning_Land_Clea

_2610000500_Emissio

2610030000 Open Burning - Household Waste Open_Burning_MSW_2610030000_Docu mentation.zip Open_Burning_MSW_261

missions.zip 

Paved and Unpaved Roads

2294000000 Paved Road Dust Paved_Roads_2294000000_Documentat ion.zip Paved_Roads_229400000

s.zip 

2296000000 Unpaved Road Dust Unpaved_Roads_2296000000_Documen tation.zip Unpaved_Roads_2296000

ons.zip 

Publicly Owned Treatment 

Works (POTW) 2630020000 Publicly Owned Treatment Works (POTW) Publicly_Owned_Treatment_Works_2630 020000_Documentation.zip Publicly_Owned_Treatmen

30020000_Emission

Residential Heating 

(SEMAP Residential Wood 

Combustion/Wax Firelog 

emissions were calculated 

using NEI’s RWC Tool with 

SESARM-revised inputs) 

2104001000 Residential Anthracite Coal Residential_Coal_2104001000_2104002 000_Documentation.zip Residential_Coal_2104001

02000_Emissions.

2104002000 Residential Bituminous Coal Residential_Coal_2104001000_2104002 000_Documentation.zip Residential_Coal_2104001

02000_Emissions.

2104004000 Residential Distillate Oil Residential_Distillate_Fuel_2104004000_ Documentation.zip Residential_Distillate_Fuel

00_Emissions.zi

WV SIP Revision: Regional Haze 5-Year Periodic Report 
8 

Source Category Source Classification Code(s) Source Classification Code Description Link to Emission Calculation Documentation Link to Emission Calc

Workbook 

2104006000 Residential Natural Gas Residential_Natural_Gas_2104006000_ Documentation.zip Residential_Natural_Gas_2

_Emissions.zip 

2104007000 Residential LPG Residential_LPG_2104007000_Documen tation.zip Residential_LPG_2104007

ons.zip 

2104008nnn 2104009000 

Residential Wood 

Combustion and Wax 

Firelogs 

Residential_Wood_Combustion_Docume

ntation.zip RWC_2008_Toolv4.1_Feb0

2104011000 Residential Kerosene Residential_Kerosene_2104011000_Doc umentation.zip Residential_Kerosene_210

missions.zip 

Solvent Usage - Surface 

Coatings 

2401001000 Architectural Coatings Solvent_Utilization_Documentation.zip Surface_Coating_Architect

g_2401001000_Emiss

2401005000 Automobile Refinishing Solvent_Utilization_Documentation.zip Surface_Coating_Automob

ing_2401005000_Emiss

2401008000 Traffic Paints Solvent_Utilization_Documentation.zip Surface_Coating_Traffic_P

1008000_Emissions

2401015000 Factory Finished Wood Solvent_Utilization_Documentation.zip Surface_Coating_Factory_

ood_2401015000_Emis

2401020000 Wood Furniture and Fixtures Solvent_Utilization_Documentation.zip Surface_Coating_Wood_F

d_Fixtures_401020000_Em

2401025000 Metal Furniture Solvent_Utilization_Documentation.zip Surface_Coating_Metal_Fu

1025000_Emissions

2401030000 Paper, Film and Foil Solvent_Utilization_Documentation.zip Surface_Coating_Paper_F

l_2401030000_Emissi

2401040000 Metal Cans Solvent_Utilization_Documentation.zip Surface_Coating_Metal_C

_2401040000_Emissio

2401045000 Metal Sheet, Strip and Coils Solvent_Utilization_Documentation.zip Surface_Coating_Metal_S

Coil_2401045000_Emis

2401055000 Machinery and Equipment Solvent_Utilization_Documentation.zip Surface_Coating_Machiner

ipment_2401055000_Em

2401060000 Appliances Solvent_Utilization_Documentation.zip Surface_Coating_Applianc

0000_Emissions.z

WV SIP Revision: Regional Haze 5-Year Periodic Report 
9 

Source Category Source Classification Code(s) Source Classification Code Description Link to Emission Calculation Documentation Link to Emission Calc

Workbook 

2401065000 Electronic and Other Electrical Coatings Solvent_Utilization_Documentation.zip Surface_Coating_Electron

er_Electrical_Coatings_24

Emissions.zip 

2401070000 Motor Vehicles Solvent_Utilization_Documentation.zip Surface_Coating_Motor_Ve

1070000_Emissions

2401075000 Aircraft Solvent_Utilization_Documentation.zip Surface_Coating_Aircraft_2

_Emissions.zip 

2401080000 Marine coatings Solvent_Utilization_Documentation.zip Surface_Coating_Marine_C

01080000_Emission

2401085000 Railroads Solvent_Utilization_Documentation.zip Surface_Coating_Railroad_

0_Emissions.zip 

2401090000 Misc. Manufacturing Solvent_Utilization_Documentation.zip Surface_Coating_Misc_Ma

_2401090000_Emissio

2401100000 Industrial Maintenance Coatings Solvent_Utilization_Documentation.zip Surface_Coating_Industrial

ce_Coating_2401100000_E

p 

2401200000 Other Special Purpose Coatings Solvent_Utilization_Documentation.zip Surface_Coating_Other_S

ose_Coating_2401200000_

zip 

Solvent Usage - Other 

2415000000 Cleaning Products: Industrial and Institutional Solvent_Utilization_Documentation.zip Cleaning_Products_Industr

titutional_2415000000_Em

2420000000 Dry Cleaning Solvent_Utilization_Documentation.zip Dry_Cleaning_2420000000

.zip 

2425000000 Graphic Arts Solvent_Utilization_Documentation.zip Graphic_Arts_2425000000

.zip 

2460100000 

Consumer & Commercial - 

Personal Care Products 

(Cosmetics and Toiletries) 

Solvent_Utilization_Documentation.zip

Consumer_Solven

Personal_Care_Products_(

and_Toiletries)_24601000

ns.zip

2460200000 Consumer & Commercial - Household Cleaning Products Solvent_Utilization_Documentation.zip Consumer_Solven

Household_Cleaning_Prod

00000_Emissions.

2460400000 Consumer & Commercial - Automotive Aftermarket Solvent_Utilization_Documentation.zip Consumer_SolventsAutom

market_2460400000_Em

WV SIP Revision: Regional Haze 5-Year Periodic Report 
10 

Source Category Source Classification Code(s) Source Classification Code Description Link to Emission Calculation Documentation Link to Emission Calc

Workbook 

2460500000 

Consumer & Commercial - Coatings and Related 

Products 

Solvent_Utilization_Documentation.zip

Consumer_SolventsCoatin

ated_Products_246050000

s.zip

2460600000 Consumer & Commercial - Adhesives and Sealants Solvent_Utilization_Documentation.zip Consumer_Solven

Adhesives_and_Sealants_

0_Emissions.zip 

2460800000 Consumer & Commercial - FIFRA Regulated Products Solvent_Utilization_Documentation.zip Consumer_Solvents_FIFR

d_Products_2460800000_

2460900000 Consumer & Commercial - Misc. Products Solvent_Utilization_Documentation.zip Consumer_Solven

Misc_Products_246090000

s.zip 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
January 2012 

11 Final Report

a. Adjustment of NEI Data to Reflect 2007 Activity Levels

7

When the 2008 nonpoint source NEI reflected 2007 activity data, TranSystems incorporated the 2008 NEI emission 

estimates as the default SEMAP area source inventory. When a source category’s NEI data reflected 2006 or 2008 

emissions activity data, TranSystems updated the NEI estimates to reflect 2007 emission activity levels. Table II-3 

documents these specific adjustments. 

For many area source categories, emissions activity data are not available at the county-level. In these cases, 

county-level emissions are estimated using two sets of activity data: one set reflecting state or regional-level 

emissions activity (e.g., volume of natural gas consumed by the residential sector in each state), and the other set 

representing data that are used to allocate emissions activity to the county-level (e.g., number of houses using 

natural gas as the primary heating fuel in each county). Specifically, the “Backcasting or Forecasting Methodology” 

column in Table II-3 presents the approach used to update emissions activity data to represent 2007, and the 

“County Allocation Method” column identifies the approach used to update the county allocation data. As noted in 

Table II-3, all county allocation data were not updated to 2007. These data were not updated because of the level-ofeffort that would be involved, and the fact that these data are generally not expected to differ significantly from yearto-year. 

b. Adjustment of NEI Data to Remove Activity Reflected in the Point Source Inventory 

To prevent double-counting of emissions in the stationary point source and area source emissions inventories, it was 

necessary to perform point source subtractions on some of the source categories in the TranSystems default area 

source inventory. To facilitate the point source subtractions, TranSystems prepared crosswalks that link area SCCs 

to point SCCs. These crosswalks are presented in Appendix A. The general point source subtraction approach 

consisted of the following steps: 

1. Compile 2007 point source emissions and control efficiency data provided by each state for the applicable 

point SCCs. 

2. Identify potential quality assurance issues for S/L agency review; 

3. Revise control efficiency data to incorporate S/L agency comments; 

4. Back-calculate 2007 uncontrolled point source emissions from reported emissions and control efficiency

data -- e.g., 40 tpy of controlled NOx emissions and 80 percent control efficiency = 50 tpy of uncontrolled 

NOx emissions. 

5. Sum the emissions for each record from step 4 to the state-level to yield state total uncontrolled point 

source emissions by pollutant. 

6. For each pollutant and state, compute the fraction of total 2007 state-level emissions in the 2007 

TranSystems default inventory represented by area sources (using step 5 total point source uncontrolled

emissions). 

7. Multiply the emission estimates in the draft base year inventory by the appropriate percentages in step 6 to 

yield area source emissions. 

TranSystems performed the point source subtractions at the state- rather than county-level because of the 

uncertainty associated with the NEI county emission allocations in that actual county-level emissions activity data are 

generally not available (i.e., a surrogate indicator such as employment is typically used to allocate state-level activity 

to counties).8

 Although the final inventory reflected Georgia’s request to perform Georgia’s point source subtractions 

at the county-level, Georgia’s revised final inventory reflects subtractions at the state-level.

 

7

In addition, TranSystems incorporated silt content inputs provided by Alabama for updated NEI-based emissions estimation 

calculations used for the residential and nonresidential construction dust categories (SCCs 2311010000 and 2311020000). 

8 Efforts to perform subtractions at the county-level commonly result in negative emission estimates. 

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 1002
12 

Table II-3. Methods for Updating 2008 NEI Estimates that Are Not Based on 2007 Emissions Activity 

Source Category 

Source 

Classification 

Code(s) 

Source Classification Code 

Description 

Year of 

Activity 

Data 

Backcasting or Forecasting 

Methodology 

Is Update 

Actual 

Activity 

Data? 

Geographic 

Resolution of 

Backcast/ Forecast 

Data County 

Asphalt Paving 

2461021000 Cutback Asphalt 2008 Recalculated using 2007 asphalt usage Yes State Allocated usin

2461022000 Emulsified Asphalt 2008 Recalculated using 2007 asphalt usage Yes State Allocated usin

Aviation Gasoline 

Distribution: Stage I 2501080050 Aviation Gasoline: Stage I 2008 Recalculated using 2007 AvGas consumption Yes National 

Allocated to d

AvGas consu

Petroleum Adthen to countydata for gene

Aviation Gasoline 

Distribution: Stage II 2501080100 Aviation Gasoline: Stage II 2008 Recalculated using 2007 AvGas consumption Yes National 

Allocated to d

AvGas consu

Petroleum Adthen to countydata for gene

Commercial Cooking 2302002nnn 2302003nnn Commercial Cooking 2008 Recalculated using 2007 population estimates Yes County 

Construction Dust 

2311010000 Residential Construction 2008 

Recalculated surface soil estimate 

using new privately owned housing units started in 2007 (all other activity data reflects 2007) 

Yes Regional Allocated to c

housing units 

2311020000 Non-Residential Construction 2008 Recalculated using 2007 value of construction put in place Yes National Did not revise 

(based on 200construction e

2311030000 Road Construction 2006 Recalculated using 2007 FHWA capital outlays Yes State NEI county al

building starts

Gasoline Distribution 

25010110nn

25010120nn Portable Fuel Containers 2008 Estimated 2007 using a linear fit between 2002 and 2010 emissions N/A County This is the sa

estimate 2008 

2501050120 Gasoline Distribution Stage I; Bulk Terminals 2008 Recalculated using 2007 national volume of wholesale gasoline supplied Yes National 

Allocated to s

refinery, bulk plant stocks oto county-leveBusiness Patt42471 

2501055120 Gasoline Distribution Stage I; Bulk Plants 2008 Recalculated using EIA's estimate of 2007 finished motor gasoline supplied No National Allocated to c

County Busincode 42471 

2501060100 Gasoline Distribution Stage II; 2008 Applied county-level VMT ratio: Yes County 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
13 

Source Category 

Source 

Classification 

Code(s) 

Source Classification Code 

Description 

Year of 

Activity 

Data 

Backcasting or Forecasting 

Methodology 

Is Update 

Actual 

Activity 

Data? 

Geographic 

Resolution of 

Backcast/ Forecast 

Data County 

Gasoline Service Stations VMT from 2007 NMIM run : VMT 

from 2008 NMIM run* 

2501060201 

Gasoline Distribution Stage I; 

Underground storage tank, 

breathing and emptying 

2008 

Applied county-level CO2 

emissions ratio: CO2 emissions from 2007 NMIM run : CO2 emissions from 2008 NMIM run 

No County 

2505030120 Gasoline Distribution Stage I; Tank Trucks in Transit 2008 

Applied county-level CO2 

emissions ratio: CO2 emissions from 2007 NMIM run : CO2 emissions from 2008 NMIM run 

No County 

2505040120 Gasoline Distribution Stage 1; Pipelines 2008 Recalculated using 2007 national volume of wholesale gasoline supplied Yes National 

Allocated to P

finished motopipeline in eato county-leveBusiness Patt42471 

Open Burning 

2610000100 Open Burning - Yard Waste - Leaves 2008 Recalculated using 2007 population estimate Yes County 

2610000400 Open Burning - Yard Waste - Brush 2008 Recalculated using 2007 population estimate Yes County 2610030000 Open Burning - Household Waste 2008 Recalculated using 2007 population estimate Yes County 

Publicly Owned 

Treatment Works 

(POTW) 

2630020000 Publicly Owned Treatment Works (POTW) 2008 

Estimated 2007 using a linear fit 

between 2004 and 2010 POTW flow rates. Allocate to county-level using 2007 population. 

Yes National 

This is the sa

estimate 2008 

Allocated to c

population es

Residential Heating 

2104001000 Residential Anthracite Coal 2006 

Recalculated using 2007 coal 

consumption data and 2007 ratio of anthracite to bituminous coal consumption 

Yes State County alloca

Census data 

2104002000 Residential Bituminous Coal 2006 

Recalculated using 2007 coal 

consumption data and 2007 ratio of anthracite to bituminous coal consumption 

Yes State County alloca

Census data 

2104004000 Residential Distillate Oil 2006 Recalculated using 2007 distillate oil consumption Yes State County alloca

Census data 

2104006000 Residential Natural Gas 2006 Recalculated using 2007 natural gas consumption Yes State County alloca

Census data 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
14 

Source Category 

Source 

Classification 

Code(s) 

Source Classification Code 

Description 

Year of 

Activity 

Data 

Backcasting or Forecasting 

Methodology 

Is Update 

Actual 

Activity 

Data? 

Geographic 

Resolution of 

Backcast/ Forecast 

Data County 

2104007000 Residential LPG 2006 Recalculated using 2007 LPG consumption Yes State County alloca

Census data 

2104011000 Residential Kerosene 2006 Recalculated using 2007 kerosene consumption Yes State County alloca

Census data 

Solvent Usage - 

Surface Coatings 

2401001000 Architectural Coatings 2008 Recalculated using 2007 population estimate Yes County 

2401005000 Automobile Refinishing 2006 Recalculated using 2007 employment data Yes County 2401015000 Factory Finished Wood 2006 Recalculated using 2007 employment data Yes County 2401020000 Wood Furniture and Fixtures 2006 Recalculated using 2007 employment data Yes County 2401025000 Metal Furniture 2006 Recalculated using 2007 employment data Yes County 2401030000 Paper, Film and Foil 2006 Recalculated using 2007 employment data Yes County 2401040000 Metal Cans 2006 Recalculated using 2007 employment data Yes County 2401045000 Metal Sheet, Strip and Coils 2006 Recalculated using 2007 employment data Yes County 2401055000 Machinery and Equipment 2006 Recalculated using 2007 employment data Yes County 2401060000 Appliances 2006 Recalculated using 2007 employment data Yes County 2401065000 Electronic and Other Electrical Coatings 2006 Recalculated using 2007 employment data Yes County 2401070000 Motor Vehicles 2006 Recalculated using 2007 employment data Yes County 2401075000 Aircraft 2006 Recalculated using 2007 employment data Yes County 2401080000 Marine coatings 2006 Recalculated using 2007 employment data Yes County 2401085000 Railroads 2006 Recalculated using 2007 employment data Yes County 2401090000 Misc. Manufacturing 2006 Recalculated using 2007 employment data Yes County 2401100000 Industrial Maintenance Coatings 2008 Recalculated using 2007 population estimate Yes County 

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Source Category 

Source 

Classification 

Code(s) 

Source Classification Code 

Description 

Year of 

Activity 

Data 

Backcasting or Forecasting 

Methodology 

Is Update 

Actual 

Activity 

Data? 

Geographic 

Resolution of 

Backcast/ Forecast 

Data County 

2401200000 Other Special Purpose Coatings 2008 Recalculated using 2007 population estimate Yes County 

Solvent Usage - Other

2415000000 Cleaning Products: Industrial and Institutional 2006 Recalculated using 2007 employment data Yes County 2420000000 Dry Cleaning 2006 Recalculated using 2007 employment data Yes County 2425000000 Graphic Arts 2006 Recalculated using 2007 employment data Yes County 2460100000 

Consumer & Commercial - Personal Care Products 

(Cosmetics and Toiletries) 

2008 Recalculated using 2007 population estimate Yes County 

2460200000 Consumer & Commercial - Household Cleaning Products 2008 Recalculated using 2007 population estimate Yes County 2460400000 Consumer & Commercial - Automotive Aftermarket 2008 Recalculated using 2007 population estimate Yes County 2460500000 Consumer & Commercial - Coatings and Related Products 2008 Recalculated using 2007 population estimate Yes County 2460600000 Consumer & Commercial - Adhesives and Sealants 2008 Recalculated using 2007 population estimate Yes County 2460800000 Consumer & Commercial - FIFRA Regulated Products 2008 Recalculated using 2007 population estimate Yes County 2460900000 Consumer & Commercial - Misc. Products 2008 Recalculated using 2007 population estimate Yes County 

*Note that Stage II gasoline refueling VOC emissions were revised from the emissions reported in the final version of the 2007 SEMAP inventory, using updated 2007/2008 VMT adjustment factor ratiothe 2007 VMT data that was used as input to MOVES onroad mobile source emissions modeling runs. 

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As a final step, TranSystems set post-subtraction PM2.5-PRI emissions equal to PM10-PRI emissions in cases 

where the initial post-subtraction emissions indicated that PM2.5-PRI emissions were greater than PM10-PRI 

emissions. 

Because of the inconsistent reporting of throughput data in the SEMAP point source inventory, throughput data were 

used in the point source subtraction procedure in only a limited number of cases. These cases are listed below in 

Table II-4. For these areas/SCCs, all pollutants’ total emissions are adjusted by the same percentage. For a few 

area source categories, it was necessary to incorporate source category-specific point source subtraction 

procedures. Appendix A summarizes the specific point source subtraction approaches for these source categories. 

Table II-4. Throughput-Based Area Source Emission Adjustments 

Area SCC Area Source % 

Jefferson County, KY 2102008000 95.66 

South Carolina 

2102002000 25.35 

2102004000 0.00 

2102005000 0.00 

2102006000 21.33 

2102007000 0.00 

2102008000 43.40 

2103004000 93.14 

2103006000 94.10 

2103007000 99.84 

Knox County, TN 

2102006000 76.71 

2103006000 99.13 

Tennessee - Rest of 

State 

2103008000 49.36 

2401015000 94.40 

2. Estimation of Area Source Emissions from Industrial and Commercial/Institutional Fuel Combustion 

In early 2010, the 2008 NEI data for the ICI fuel combustion categories represented total emission activity estimates, 

rather than area source emission estimates. Because emission estimates were not available and because of the 

relative importance of this category, TranSystems recommended that 2007 ICI combustion area source emission 

estimates be developed as part of this project. This section documents the emission inventory development 

methodology that TranSystems used in preparing 2007 year ICI fuel combustion area source emission estimates for 

the SESARM states. The following are elements of the methodology that provide improvements over the 2008 NEI 

methodology: 

• Obtained Industrial and Commercial/Institutional energy consumption by fuel type and SESARM state for 

the year 2007 from the Energy Information Administration (EIA)’s State Energy Data System (SEDS) – the

2008 NEI used 2006 year data; 

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• Obtained geographic- and year-specific estimates of non-fuel use consumption of industrial energy from the 

2006 Manufacturing Energy Consumption Survey (MECS) – the 2008 NEI used data from the 2002 MECS 

survey; 

• Applied a county allocation procedure that reflects the energy-intensity of each industrial sector – the 2008 

NEI methods only reflect the number of employees in each sector; and 

• Updated SO2 emission factors to reflect coal sulfur content estimates for coal used in the industrial sector in 

2007 – a recent review of industrial coal sulfur content values concluded that the NEI values are based on 

unrepresentative data (Pechan, 2009b). 

Table II-5 identifies the SCCs for which TranSystems prepared ICI fuel combustion area source emission estimates. 

The key data inputs in the emissions estimation methodology are: 

1. Total Industrial and total Commercial/Institutional energy consumption by fuel type and SESARM state for 

the year 2007; 

2. Estimates of the percentage of total ICI distillate fuel and liquefied petroleum gas (LPG) consumption from 

stationary sources; 

3. Industrial energy consumption used for non-fuel purposes by fuel type and state in 2006; 

4. ICI energy consumption by fuel type for point sources by SESARM state in year 2007; 

5. Emission factors relating emission rates to volume of energy consumed by fuel type for the ICI sectors; 

6. Sulfur content of coal consumed in the ICI sectors by state in year 2007; 

7. County-level Industrial sector energy consumption estimates by state for year 2007; and 

8. County-level Commercial/Institutional sector employment by state for the year 2006.9

Table II.5. ICI Fuel Combustion Area Source Classification Codes 

SCC DESCRIPTION

2102001000Stationary Source Fuel Combustion; Industrial; Anthracite Coal; Total: All Boiler Types

2102002000Stationary Source Fuel Combustion; Industrial; Bituminous/Subbituminous Coal; Total: All Boiler Types

2102004000Stationary Source Fuel Combustion; Industrial; Distillate Oil; Total: Boilers and IC Engines

2102005000Stationary Source Fuel Combustion; Industrial; Residual Oil; Total: All Boiler Types

2102006000Stationary Source Fuel Combustion; Industrial; Natural Gas; Total: Boilers and IC Engines

2102007000Stationary Source Fuel Combustion; Industrial; Liquid Petroleum Gas; Total: All Boiler Types

2102008000Stationary Source Fuel Combustion; Industrial; Wood; Total: All Boiler Types

2102011000Stationary Source Fuel Combustion; Industrial; Kerosene; Total: All Boiler Types

2103001000Stationary Source Fuel Combustion; Commercial/Institutional; Anthracite Coal; Total: All Boiler Types

2103002000Stationary Source Fuel Combustion; Commercial/Institutional; Bituminous/Subbituminous Coal; Total: All Boiler Types

2103004000Stationary Source Fuel Combustion; Commercial/Institutional; Distillate Oil; Total: Boilers and IC Engines

2103005000Stationary Source Fuel Combustion; Commercial/Institutional; Residual Oil; Total: All Boiler Types

2103006000Stationary Source Fuel Combustion; Commercial/Institutional; Natural Gas; Total: Boilers and IC Engines

2103007000Stationary Source Fuel Combustion; Commercial/Institutional; Liquid Petroleum Gas; Total: All Combustor Types

2103008000Stationary Source Fuel Combustion; Commercial/Institutional; Wood; Total: All Boiler Types

2103011000Stationary Source Fuel Combustion; Commercial/Institutional; Kerosene; Total: All Combustor Types

 

9

 To conserve project resources, Pechan relied on 2006 employment data compiled in support of the 2008 NEI rather than 

develop 2007 employment data (note that year-to-year county employment proportions are expected to remain relatively 

constant). 

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The following sections describe the methodology/data source(s) for developing each of these data inputs, and the 

source(s) of information for each of these data elements. In selecting the information sources for each of these data 

elements, TranSystems evaluated the completeness, representativeness, comparability, and accuracy criteria 

identified in the Quality Assurance Project Plan (QAPP) for this project. For example, information sources that 

provide data specific to the source category/geography/inventory period were selected over those that were less 

specific. 

a. Total ICI Energy Consumption 

For total Industrial and total Commercial/Institutional energy consumption by fuel type/state, TranSystems primarily 

used the same source that EPA uses in developing ICI combustion emission estimates for the NEI –EIA’s SEDS 

(EIA, 2009a). The SEDS provides total energy consumption estimates by sector, state, fuel type, and year. To 

facilitate use with the criteria pollutant emission factors, TranSystems compiled the SEDS energy consumption data 

in both sets of units provided by the EIA: physical units and British thermal units (Btus). For estimates of industrial 

distillate consumption, TranSystems relied on estimates reported in EIA’s “Fuel Oil and Kerosene Sales” (EIA, 

2009b). This source is preferred over the SEDS data because it provides additional sectoral detail that is needed to 

perform the stationary source energy consumption adjustments described below. 

b. Stationary Source Energy Consumption 

To avoid double-counting with energy consumption accounted for in mobile source inventories, it was necessary to 

adjust 2007 year SEDS distillate and LPG consumption estimates for mobile source fuel consumption. For LPG, the 

adjustments account for energy consumption reflected in the nonroad mobile sector. The adjustments were 

performed by subtracting estimated proportions of total Industrial sector and Commercial sector consumption 

computed from a national NONROAD model run. TranSystems compiled national LPG consumption estimates for 

relevant SCCs from a 2006 run of EPA’s NONROAD model (a 2006 run was performed in support of the NEI—it is 

not anticipated that the percentages differ considerably between 2006 and 2007). Table II-6 identifies a complete list 

of nonroad SCCs associated with Industrial and Commercial sector LPG. The shaded entries in this table indicate 

where NONROAD reports LPG consumption. This procedure estimates that nonroad mobile sources account for 9 

percent of Industrial sector, and 18 percent of Commercial sector LPG consumption. The SEDS LPG consumption 

estimates for each state/sector were adjusted downward using these percentages. 

For distillate oil, it was necessary to remove energy consumption reflected in onroad/nonroad mobile source emission 

inventories. To facilitate this step, TranSystems used more detailed distillate fuel consumption estimates reported in 

EIA’s “Fuel Oil and Kerosene Sales,” and stationary source fuel consumption percentage assumptions used in the 

regulatory impact analysis for EPA’s nonroad diesel emissions rulemaking (EPA, 2003a). Table II-7 displays the 

assumptions that were applied to the state-level Industrial sector distillate fuel consumption estimates reported in 

“Fuel Oil and Kerosene Sales” to estimate Industrial sector stationary source consumption. Table II-8 identifies the 

assumptions that were applied to estimate total stationary source Commercial/Institutional sector consumption. 

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Table II-6. LPG Nonroad Mobile Source Classification Codes 

SCC Description_2 Description_3 Description_4 

Industrial Sector

2267002000 LPG Construction and Mining Equipment All 2267002003 LPG Construction and Mining Equipment Pavers 2267002006 LPG Construction and Mining Equipment Tampers/Rammers 2267002009 LPG Construction and Mining Equipment Plate Compactors 2267002015 LPG Construction and Mining Equipment Rollers 2267002018 LPG Construction and Mining Equipment Scrapers 2267002021 LPG Construction and Mining Equipment Paving Equipment 2267002024 LPG Construction and Mining Equipment Surfacing Equipment 2267002027 LPG Construction and Mining Equipment Signal Boards/Light Plants 2267002030 LPG Construction and Mining Equipment Trenchers 2267002033 LPG Construction and Mining Equipment Bore/Drill Rigs 2267002036 LPG Construction and Mining Equipment Excavators 2267002039 LPG Construction and Mining Equipment Concrete/Industrial Saws 2267002042 LPG Construction and Mining Equipment Cement and Mortar Mixers 2267002045 LPG Construction and Mining Equipment Cranes 2267002048 LPG Construction and Mining Equipment Graders 2267002051 LPG Construction and Mining Equipment Off-highway Trucks 2267002054 LPG Construction and Mining Equipment Crushing/Processing Equi2267002057 LPG Construction and Mining Equipment Rough Terrain Forklifts 2267002060 LPG Construction and Mining Equipment Rubber Tire Loaders 2267002063 LPG Construction and Mining Equipment Rubber Tire Tractors/Doze2267002066 LPG Construction and Mining Equipment Tractors/Loaders/Backhoe2267002069 LPG Construction and Mining Equipment Crawler Tractor/Dozers 2267002072 LPG Construction and Mining Equipment Skid Steer Loaders 2267002075 LPG Construction and Mining Equipment Off-Highway Tractors 2267002078 LPG Construction and Mining Equipment Dumpers/Tenders 2267002081 LPG Construction and Mining Equipment Other Construction Equipm2267003000 LPG Industrial Equipment All 2267003010 LPG Industrial Equipment Aerial Lifts 2267003020 LPG Industrial Equipment Forklifts 2267003030 LPG Industrial Equipment Sweepers/Scrubbers 2267003040 LPG Industrial Equipment Other General Industrial E

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SCC Description_2 Description_3 Description_4 

2267003050 LPG Industrial Equipment Other Material Handling Eq2267003060 LPG Industrial Equipment AC\Refrigeration 2267003070 LPG Industrial Equipment Terminal Tractors 2267005000 LPG Agricultural Equipment All 2267005010 LPG Agricultural Equipment 2-Wheel Tractors 2267005015 LPG Agricultural Equipment Agricultural Tractors 2267005020 LPG Agricultural Equipment Combines 2267005025 LPG Agricultural Equipment Balers 2267005030 LPG Agricultural Equipment Agricultural Mowers 2267005035 LPG Agricultural Equipment Sprayers 2267005040 LPG Agricultural Equipment Tillers >6 HP 2267005045 LPG Agricultural Equipment Swathers 2267005050 LPG Agricultural Equipment Hydro-power Units 2267005055 LPG Agricultural Equipment Other Agricultural Equipme2267005060 LPG Agricultural Equipment Irrigation Sets 2267007000 LPG Logging Equipment All 2267007005 LPG Logging Equipment Chain Saws > 6 HP 2267007010 LPG Logging Equipment Shredders > 6 HP 2267007015 LPG Logging Equipment Forest Eqp – Feller/Bunch2267009000 LPG Underground Mining Equipment All 2267009010 LPG Underground Mining Equipment Other Underground Mining 2267010000 LPG Industrial Equipment All 2267010010 LPG Industrial Equipment Other Oil Field Equipment 

Commercial Sector

2267004011 LPG Lawn and Garden Equipment Lawn Mowers (Commercia2267004016 LPG Lawn and Garden Equipment Rotary Tillers < 6 HP (Com2267004021 LPG Lawn and Garden Equipment Chain Saws < 6 HP (Comm2267004026 LPG Lawn and Garden Equipment Trimmers/Edgers/Brush C2267004031 LPG Lawn and Garden Equipment Leafblowers/Vacuums (Co2267004036 LPG Lawn and Garden Equipment Snowblowers (Commercia2267004041 LPG Lawn and Garden Equipment Rear Engine Riding Mowe2267004046 LPG Lawn and Garden Equipment Front Mowers (Commercia2267004051 LPG Lawn and Garden Equipment Shredders < 6 HP (Comm2267004056 LPG Lawn and Garden Equipment Lawn and Garden Tractors 2267004061 LPG Lawn and Garden Equipment Wood Splitters (Commerci2267004066 LPG Lawn and Garden Equipment Chippers/Stump Grinders 

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SCC Description_2 Description_3 Description_4 

2267004071 LPG Lawn and Garden Equipment Turf Equipment (Commerc2267004076 LPG Lawn and Garden Equipment Other Lawn and Garden E2267006000 LPG Commercial Equipment All 2267006005 LPG Commercial Equipment Generator Sets 2267006010 LPG Commercial Equipment Pumps 2267006015 LPG Commercial Equipment Air Compressors 2267006020 LPG Commercial Equipment Gas Compressors 2267006025 LPG Commercial Equipment Welders 2267006030 LPG Commercial Equipment Pressure Washers 2267006035 LPG Commercial Equipment Hydro-power Units 2267008000 LPG Airport Ground Support Equipment All 2267008005 LPG Airport Ground Support Equipment Airport Ground Support Eq

Note: EPA’s NONROAD model reports emissions/fuel consumption for the shaded entries. 

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Table II-7. Assumptions Used to Estimate Industrial Sector Stationary Source Distillate Fuel Consumption 

Sector Distillate Fuel Type 

% of Total 

Consumption from 

Stationary Sources 

Industrial No. 1 Distillate Fuel Oil 60

No. 2 Distillate Fuel Oil 100

No. 2 Distillate/Low and High Sulfur Diesel 15a

No. 4 Distillate Fuel Oil 100

Farm Diesel 0

Other Distillate Fuel Oil 100

Off-Highway

(Construction and Other) 

Distillate Fuel Oil 5

Oil Company Distillate Fuel Oil 50

a

 This value differs from the 0 percent assumption adopted in EPA’s nonroad diesel emissions rulemaking because it is 

known that some diesel fuel is used by stationary sources (a 15 percent value was selected for use as an approximate 

mid-point of a potential range of 8 to 24 percent stationary source use computed from a review of national data from the 

EIA’s Manufacturing Energy Consumption Survey and “Fuel Oil and Kerosene Sales”). 

Table II-8. Assumptions Used to Estimate Commercial/Institutional Sector Stationary Source 

Distillate Fuel Consumption 

Sector Distillate Fuel Type 

% of Total Consumption 

from Stationary Sources

Commercial No. 1 Distillate Fuel Oil 80

No. 2 Distillate Fuel Oil 100

No. 2 Distillate/Ultra-Low, Low, and High Sulfur Diesel 0

a

No. 4 Distillate Fuel Oil 100

a

 A very small portion of total commercial/institutional diesel is actually consumed by point sources (SCC 203001xx). 

c. Non-Fuel Energy Consumption 

Some Industrial sector energy is consumed for non-fuel purposes. For example, natural gas is used as a feedstock 

in chemical manufacturing plants and to make nitrogenous fertilizer, and LPG is used to create intermediate products 

that are made into plastics. To estimate the volume of fuel that is associated with ICI combustion, it is necessary to 

subtract the volume of fuel consumption for non-energy uses from the volume of total fuel consumption. The EPA’s 

State Inventory Tool (SIT) provides national defaults representing the percentage of total Industrial fuel consumption 

from non-energy uses. These default values have an additional limitation beyond their lack of geographic detail - 

they represent the EIA’s definition of the Industrial sector, which includes fuel use that is accounted for in other 

inventory source categories (e.g., Farm, Mining, Construction, and Commercial sectors fuel use that is accounted for 

in the nonroad inventory). Because of these limitations, TranSystems used regional non-fuel use percentages 

computed from energy consumption data from the EIA’s 2006 Manufacturing Energy Consumption Survey (MECS) 

for all fuel types (EIA, 2009c). 

There are two reasons why MECS provides a more representative data set for use in this project: (1) MECS 

provides data specific to the region of interest; and (2) MECS focuses solely on the Manufacturing sector. The latter 

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characteristic is particularly important for fuel types which consume significant amounts of non-Manufacturing sector 

energy that is already included elsewhere (e.g., distillate fuel used by the Construction sector, which is included in 

the nonroad inventory). The MECS non-fuel consumption data treat coal that is used to produce coke as a feedstock 

(Lorenz, 2009). However, available data indicate that only four of the SESARM states produce coke (Alabama, 

Kentucky, Virginia, West Virginia; EIA, 2008a) and coke combustion is not included in the area source emissions 

inventory. Because of this, TranSystems estimated the percent energy consumption from non-fuel use for SESARM 

states without coke plants by subtracting the coal used in the primary metals industrial subsector (NAICS code 331*) 

from the MECS coal dataset. More than 97 percent of coking coal is ultimately consumed in this subsector (Lorenz, 

2009). Table II-9 presents the non-fuel use percentages by type of energy. 

Table II-9. Industrial Sector Energy Consumption from Non-Fuel Uses 

Energy Type 

2006 MECS % Energy Consumption from Non-Fuel Use

South1 National

Residual 30% 20%

Distillate 12% 12%

Natural Gas 11% 7%

LPG/NGL 99% 97%

Coal (excludes coking coal) 9% 6%

Sources: EIA, 2009c and Lorenz, 2009. 

1

 All SESARM states are in the South region. 

d. Emission Factors 

Table II-10 presents the criteria pollutant emission factors that TranSystems used in calculating ICI combustion area 

source emissions. Except as noted below, all criteria air pollutant emission factors are from an EPA database used 

to prepare the 2008 nonpoint source NEI (Huntley, 2009).10 Wood combustion emission factors are from AP-42

(EPA, 2003b). Because there are no NH3 emission factors for ICI fuel combustion available in the 2008 NEI 

emission factor database, AP-42, or EPA’s WebFIRE, TranSystems used emission factors reported in an NH3 

emissions Emission Inventory Improvement Program (EIIP) guidance document (Pechan, 2004).

 

10 All criteria pollutant emission factors were rounded to two decimal places. 

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Table II-10. Criteria Pollutant Emission Factors for ICI Combustion Area Source Categories 

SCC Description 

Emission 

Factor Units1 VOC NOx CO SO2 PM2.5-FIL PM10-FI

2102001000 Industrial Anthracite Coal lb/ton 0.3 9 0.6 39 * S% 0.48 * A% 1.1 * A2102002000 Industrial Bitum/Subbitum Coal lb/ton 0.05 11 5 38 * S% 1.4 2102004000 Industrial Distillate Oil lb/1000 gal 0.2 20 5 142 * S% 0.25 

2102005000 Industrial Residual Oil lb/1000 gal 0.28 55 5 157 * S% 4.67 * (1.12 * S% + 0.37) 7.17 * (1.1

S% + 0.3

2102006000 Industrial Natural Gas lb/MMcf 5.5 100 84 0.6 0.11 02102007000 Industrial LPG 2 lb/1000 bbl 21.9 398 502 2.39 0.438 0.72102008000 Industrial Wood 3 lb/MMBtu 0.017 0.22 0.6 0.025 0.43 02102011000 Industrial Kerosene lb/1000 gal 0.19 19.29 4.82 142 * S% 0.24 0.2103001000 Comm/Inst Anthracite Coal lb/ton 0.3 9 0.6 39 * S% 0.48 * A% 1.1 * A2103002000 Comm/Inst Bitum/Subbitum Coal lb/ton 0.05 11 5 38 * S% 1.4 2103004000 Comm/Inst Distillate Oil lb/1000 gal 0.34 20 5 142 * S% 0.83 1.

2103005000 Comm/Inst Residual Oil lb/1000 gal 1.13 55 5 157 * S% 1.92 * (1.12 * S% + 0.37) 5.17 * (1.1

S% + 0.3

2103006000 Comm/Inst Natural Gas lb/MMcf 5.5 100 84 0.6 0.11 02103007000 Comm/Inst LPG lb/1000 bbl 21.9 398 502 2.39 0.438 0.72103008000 Comm/Inst Wood 3 lb/MMBtu 0.017 0.22 0.6 0.025 0.43 02103011000 Comm/Inst Kerosene lb/1000 gal 0.33 19.29 4.82 142 * S% 0.8 1.

Source: Unless otherwise noted, 2008 nonpoint source NEI (Huntley, 2009). Notes: 1 lb = pound; ton = short ton; gal = gallon; MMcf = million cubic feet; MMBtu = million British thermal units; bbl = barrels; S = sulfur content; A = ash 

 content 2 Emission factors from Commercial/Institutional LPG. 3 Emission factors from AP-42, Section 1.6, Wood Residue Combustion in Boilers (EPA, 2003b). 

4 Emission factor from Pechan, 2004 (converted from lb/ton using 0.08 ton/MMBtu for Industrial sector and 0.0625 ton/MMBtu for Commercial sector). 

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With a few notable exceptions, the 2008 NEI emission factors are the same as those used for the 2002 NEI.11 The 

PM emission factors for natural gas and LPG combustion are the major exceptions. Because the 2002 emission 

factors were deemed too high because of artifact formation in the test method (method 202) during stack testing, 

EPA developed a set of SCC-specific adjustment factors to apply to the 2002 NEI to better reflect PM emissions from 

these fuels.12 In preparation for the 2008 NEI, EPA developed revised natural gas PM emission factors by applying 

these adjustment factors to the 2002 NEI emission factors. Revised emission factors for LPG were computed by 

applying appropriate conversion factors to the updated natural gas emission factors. 

e. Coal Sulfur and Ash Content 

For a recent ICI combustion area source inventory project for the Central Regional Air Planning Association 

(CENRAP), TranSystems evaluated the reliability of various data sources for coal sulfur content to be used to 

estimate emissions in that project. TranSystems evaluated five potential data sources: 

1. 2002 CENRAP state point source inventories; 

2. U.S. Geological Survey (USGS)’s U.S. Coal Quality Database; 

3. Energy Information Administration (EIA)’s “Cost and Quality of Fuels for Electric Plants 2002 and 2003.” 

4. EIA’s “EIA-423 - Monthly Nonutility Fuel Receipts and Fuel Quality Data, 2002;” and 

5. EIA’s “Quarterly Coal Report, January–March 2003.” 

TranSystems evaluated these coal sulfur content data sources with respect to two specific criteria identified in the 

QAPP for this project: representativeness and accuracy. Based on these evaluations, TranSystems used the 

average sulfur content data from EIA’s “Quarterly Coal Report” to estimate the sulfur content of both Industrial and 

Commercial/Institutional sector bituminous/subbituminous coal in each SESARM state (EIA, 2008b). Even though 

this source does not report whether the coal is bituminous/subbituminous or anthracite, it is appropriate to treat the 

values for this source as representative of bituminous/subbituminous coal because anthracite accounts for only a 

very small proportion of coal consumption in SESARM states. 

Due to the lack of available data for anthracite coal, TranSystems used the average ash content (13.38 percent) and 

sulfur content (0.89 percent) from the 2002 NEI for the Industrial and Commercial/Institutional sectors. These 

percentages are based on the composition of anthracite coal seams in Pennsylvania, where all anthracite coal 

imported by SESARM states originated in 2007 (EIA, 2008c). Tables II-11 and II-12 report the coal ash and/or sulfur 

content values that were used in calculating ICI combustion area source emissions for the 2007 base year inventory. 

 

 

11 The 2002 NEI documentation provides citations to the AP-42 source for each emission factor. 

12 These factors reduce PM emissions by more than 90 percent. 

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Table II-11. Bituminous/Subbituminous Coal Sulfur Content for 2007 ICI Combustion 

State 

Industrial Coal1

Sulfur Content (%) 

Commercial/ 

Institutional Coal2

Sulfur Content (%) 

Alabama 0.94 0.94

Florida 0.87 0.87

Georgia 0.95 0.95

Kentucky 0.89 0.89

Mississippi 2.01 2.01

South Carolina 1.10 1.10

North Carolina 0.90 0.90

Tennessee 1.21 1.21

Virginia 0.96 0.96

West Virginia 0.95 0.95

1Reflects the average from coal received in 2007. 

2Assumes that coal burned in the Commercial/Institutional sector has the same composition as coal 

burned in the Industrial sector. 

Table II-12. Anthracite Coal Ash and Sulfur Content for 2007 ICI Combustion 

State 

Industrial Commercial/Institutional 

Ash Content

(%) Sulfur Content (%) 

Ash Content

(%) Sulfur Content (%) 

Alabama 13.38 0.89 13.38 0.89

Florida 13.38 0.89 13.38 0.89

Georgia 13.38 0.89 13.38 0.89

Kentucky 13.38 0.89 13.38 0.89

Mississippi 13.38 0.89 13.38 0.89

South Carolina 13.38 0.89 13.38 0.89

North Carolina 13.38 0.89 13.38 0.89

Tennessee 13.38 0.89 13.38 0.89

Virginia 13.38 0.89 13.38 0.89

West Virginia 13.38 0.89 13.38 0.89

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f. County Allocation Data 

After computing state-level area source emissions using the data described above, the next step is to allocate these 

emissions to individual counties. Separate allocation approaches were implemented for the Industrial and 

Commercial/Institutional sectors. For Commercial/Institutional sector source categories, the approach relies on 

county employment data compiled from government sources. For Industrial sector source categories, the approach 

utilizes county-level Industrial sector energy consumption estimates developed in this effort. 

Commercial/Institutional 

Because SEDS data originate from EIA fuel sector-specific surveys of energy suppliers,13 TranSystems reviewed 

these survey forms/instructions for further details on what SEDS considers Commercial sector use of each fuel. This 

review found that the surveys/guidance do not always provide further clarity. In addition, the EIA has admitted that 

energy suppliers may use their own account classifications as well as EIA guidance in determining whether a 

particular account belongs in the Residential, Commercial, Industrial, or Transportation sector. The only source of 

NAICS-code based EIA definitions of the Commercial energy sector is a “rough crosswalk” between Commercial 

building types and NAICS codes developed for EIA’s Commercial Building Energy Consumption Survey (CBECS). 

With the exception of NAICS code 814 (Private Households), this crosswalk links all NAICS codes between 42 and 

92 with Commercial building energy consumption. Employment data for the CBECS-identified NAICS codes (42 

though 92 with exception of 814) were used to allocate SEDS energy consumption data to individual counties. 

TranSystems used private sector 2006 employment data from County Business Patterns (CBP) and public sector 

2006 employment data from the Census of Governments (Census, 2009a; and Census, 2009b) because these data 

were already compiled in support of the 2008 NEI (year-to-year changes in county employment proportions are 

expected to be minimal). 

Industrial 

Unlike the Commercial sector, documentation provides a clear listing of the NAICS codes associated with SEDS 

Industrial energy consumption data: “the industrial sector encompasses the following types of activity: 

Manufacturing (NAICS codes 31–33); Agriculture, Forestry, Fishing and Hunting (NAICS code 11); Mining, including 

Oil and Gas Extraction (NAICS code 21); and Construction (NAICS code 23).” As noted earlier, a portion of Industrial 

sector consumption (Agriculture, Mining and Construction) is already accounted for in other emission inventory 

sectors and was removed. Therefore, TranSystems did not expand the list of NAICS codes used to represent the 

area source Industrial fuel combustion category beyond the Manufacturing sector NAICS codes (31-33). 

Employment-based county allocation methods lead to overrepresentation of energy consumption in counties with 

sectors that have high employment but low energy intensities (measured on a Btu per employee basis), and viceversa. Given that Manufacturing sectors have much greater energy intensity variability than Commercial/Institutional 

sectors, TranSystems utilized energy use per employee values by NAICS code to improve upon the employmentbased county allocation approach used in the 2008 NEI for the Industrial fuel combustion category. This procedure 

relied on 2007 national energy consumption data by NAICS code as reported by EIA in Annual Energy Outlook (EIA, 

2009d). Energy intensity values were computed by dividing these Btu-based energy consumption estimates by 

NAICS code-level 2007 national employment data. The resulting intensity values were then multiplied by

county/NAICS code-level employment estimates from CBP to estimate total county energy consumption by NAICS 

code. These values were then summed for the appropriate Industrial fuel combustion NAICS codes. The resulting 

county-level total Industrial energy consumption estimates were used to apportion state-level area source Industrial 

fuel combustion emissions to each county. 

 

13 For natural gas, for example – EIA-176 “Annual Report of Natural and Supplemental Gas Supply and Disposition.” 

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Estimation of Withheld Employment Data 

Due to concerns with releasing confidential business information, the CBP withholds values for a given county/NAICS 

code if it would be possible to identify individual businesses from these values. In such cases, the CBP reports a 

letter code, representing a particular employment size range. TranSystems used the following procedure to estimate 

data for withheld counties/NAICS codes. 

1. County-level employment for counties with reported values are totaled by state for the applicable NAICS code. 

2. Value from step 1 is subtracted from the state employment value for the NAICS code. 

3. Each of the withheld counties is assigned an initial employment estimate reflecting the midpoint of the CBP 

range code (e.g., code A, which reflects 1-19 employees, is assigned an estimate of 10 employees). 

4. The initial employment estimates from step 3 are then summed to the state level. 

5. The value from step 2 is divided by the value from step 4 to yield an adjustment factor to apply to the initial 

employment estimates to yield employment values that will sum to the state employment total for the applicable 

NAICS code. 

6. The final county-level employment values are estimated by multiplying the initial employment estimates from 

step 3 by the step 5 adjustment factors. 

Example: NAICS 31-33 (Manufacturing) in Maine 

fipsstate fipscty naics empflag emp 

23 001 31---- 6,774 

23 003 31---- 3,124 

23 005 31---- 10,333 

23 007 31---- 1,786 

23 009 31---- 1,954 

23 011 31---- 2,535 

23 013 31---- 1,418 

23 015 31---- F 0 

23 017 31---- 2,888 

23 019 31---- 4,522 

23 021 31---- 948 

23 023 31---- I 0 

23 025 31---- 4,322 

23 027 31---- 1,434 

23 029 31---- 1,014 

23 031 31---- 9,749 

1. The total of employees not including counties 015 and 023 is 52,801. 

2. The state-level CBP reports 59,322 employees in NAICS 31—the difference is 6,521. 

3. County 015 is given a midpoint of 1,750 (since range code F is 1,000-2,499) and County 023 is given a midpoint 

of 17,500. 

4. State total for these two counties is 19,250. 

5. 6,521/19,250 = 0.33875. 

The final employment estimate for county 015 is 1,750 * 0.33875 = 593. The county 023 final employment estimate 

is computed as 17,500 * 0.33875 = 5,928. 

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3. Estimation of Area Source Emissions from Residential Wood Combustion 

Residential wood combustion was calculated using the EPA’s Residential Wood Combustion (RWC) Tool. The tool 

uses the following equation to estimate RWC emissions: 

Emissions = (Number of wood-burning appliances) x (Cords of wood burned per appliance) x (Density of 

wood burned) x (Emission factor) 

A review of the spatial distribution of SESARM region PM2.5 emissions from the tool indicated much higher emissions 

in urbanized areas than rural areas. Although there is reason to expect some correlation between the number of 

occupied housing units and residential wood combustion emissions, this correlation would be expected to be fairly 

weak because of at least two factors. The first factor is that housing units in urbanized areas generally have greater 

access to natural gas as a heating fuel, and therefore, would be expected to have a greater penetration of natural 

gas fireplaces than rural areas. The second factor is that the access to inexpensive wood supplies would be 

expected to be much greater in rural areas (and related to this, the proportion of housing units with wood-burning 

appliances that are used as primary heating units – i.e., woodstoves, outdoor hydronic heaters, pellet stoves – would 

also be expected to be greater in rural areas). Review of several wood consumption surveys, including the latest 

survey from Minnesota, also showed a clear trend in households in urbanized areas consuming less wood than their 

counterparts in rural areas. 

Based on this review, SESARM, with primary assistance from Tracy Anderson of the Alabama Department of 

Environmental Management, examined the EPA Tool’s default assumptions for the first two variables in the RWC 

emissions estimation equation. The following describes the specific refinements that SESARM incorporated into a 

revised RWC Tool for these two variables. 

Number of Wood-Burning Appliances 

SESARM incorporated updates to the estimated number of the following types of wood-burning appliances:

• Fireplaces; 

• Fireplace Insert Uncertified; 

• Fireplace Insert EPA Certified Catalytic; 

• Fireplace Insert EPA Certified Non-catalytic; 

• Woodstove Uncertified; 

• Woodstove EPA Certified Catalytic; 

• Woodstove EPA Certified Non-catalytic; and 

• Fireplaces Burning Wax Logs. 

For these equipment types, the EPA’s RWC tool estimates the number of wood-burning appliances in each county by 

multiplying the county’s number of occupied housing units by an appropriate wood-burning appliance profile. 

Where possible, SESARM first updated the occupied housing unit estimates in the Tool. The Tool estimates the 

number of occupied housing units by multiplying each county’s total number of housing units in 2007, as reported by 

the U.S. Census Bureau, by the county-level occupancy rate in 2000 (last year of occupancy rate data available from 

the Census). For select counties (primarily those with large populations), the Census’ American Community Survey 

(ACS) reports estimates of the 2007 year number of occupied housing units. Several states use the ACS data and 

indicated a preference for its use. Therefore, SESARM updated the EPA tool to use the ACS’ housing unit estimates 

for counties where these data were available. 

A second type of update involved revisions to the wood-burning appliance profiles. Appliance profiles represent the 

fraction of occupied housing units that have each of the wood-burning appliances listed above. The appliance 

profiles were developed from the number of wood burning appliances and number of occupied housing units data 

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compiled from the U.S. Census Bureau’s "American Housing Survey" (AHS). The RWC Tool applies appliance 

profiles to one or more geographic locations. The Tool includes a set of Metropolitan Statistical Area (MSA)-specific 

appliance profiles and regional default appliance profiles (Northeast, Midwest, South, and West). Based on new 

information gathered from these surveys, SESARM calculated 12 additional appliance profiles to better characterize 

the wood-burning appliance population. These profiles are as follows: 

1) A default urban appliance profile based on national urban values reported by the 2005 National AHS, 

2) "Sub-MSA" area profiles for each of the following MSAs: 

a. Birmingham, AL; 

b. Miami-Dade County, FL; 

c. Urban Atlanta, GA; 

d. Kenton County, KY; 

e. De Soto County, MS; 

f. Gaston County, NC; 

g. Mecklenburg County, NC; 

h. York County, SC; 

i. Shelby County, TN; 

j. Fairfax County, VA; and 

k. Urban Norfolk-Virginia Beach-Newport News area, VA.

These sub-MSA appliance profiles were developed using the “sub-area” sections of the original Metropolitan Areas 

AHS used in the RWC tool. In keeping with EPA’s MSA appliance profile assignment approach, SESARM assigned 

the sub-MSA profiles only to the counties to which they applied. 

SESARM developed a default urban appliance profile in an attempt to better characterize wood-burning equipment 

populations in urbanized areas for which the AHS does not report MSA-specific data. This profile reflects national 

average wood-burning appliance information from the 2005 National AHS. The next step was to develop a set of 

criteria for determining what counties should be assigned the applicable regional average appliance profile (South), 

and which would be assigned the new national urban appliance profile. Figure 1 shows the decision tree that 

SESEARM developed to assign each of these two appliance profiles. 

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Figure 1. Decision Tree for Assigning Regional Average (Default) or National Urban 

Appliance Profile 

 

Was the County/City 

considered urban in the 

2000 Census?

No.

Are the number of tracts 

>1000 people/mile2 less than 

or equal to 5?

Yes.

Use Default Appliance 

Profile.

No.

Is Calculated Urban Fraction 

greater than or equal to 

0.80?

No.

Use Default Appliance 

Profile.

Yes.

Is 2010 County/City 

Population Density greater 

than 200 people/mile2 ?

Yes.

Where there is not a Survey 

Appliance Profile use the 

Urban Appliance Profile.

No.

Use Default Appliance 

Profile.

Yes.

Where there is not a Survey 

Appliance Profile use the 

Urban Appliance Profile.

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The above does not address the estimated count of the following wood-burning appliance types: 

• Pellet stoves; 

• Indoor furnaces; and 

• Hydronic heaters (also known as outdoor wood boilers). 

The estimates for these equipment types are hard-coded into the RWC Tool. After review of the EPA’s appliance 

count estimation methods for these units, SESARM decided that the estimates for these appliances should also be 

updated. 

In the case of pellet stoves and hydronic heaters, the RWC Tool allocates regional (pellet stoves) or state-level 

(hydronic heater) counts of each appliance type. The RWC Tool utilizes estimates of the number of each type of 

equipment as calculated from cumulative sales data. The Tool then allocates these regional/state estimates to 

counties based on the proportion of regional/state number of woodstoves in each county. Because SESARM’s 

revised RWC Tool includes updated county-level woodstove population estimates, consistency with EPA’s 

methodology requires re-allocating the estimated number of regional/state pellet stoves and hydronic heaters to each 

county using the updated woodstove data incorporated into the revised Tool. 

The RWC Tool estimates the number of wood-burning indoor furnaces by multiplying the estimated number of

woodstoves in each county by a factor. The EPA calculated this factor (0.53) from data on the number of 

woodstoves and indoor furnaces used for main heating in climate zones 1-3. To be consistent with the RWC Tool 

methods for estimating indoor furnaces, SESARM updated the indoor furnace appliance counts by multiplying the 

revised number of woodstoves in each county by the 0.53 factor. 

Cords of Wood Burned per Appliance 

SESARM also incorporated new burn rate profiles that characterize the amount of wood burned in each type of 

appliance. As with the appliance profiles, burn rate profiles can be assigned to one or more geographical areas. The 

EPA’s RWC Tool included burn rate profiles that were developed and refined by EPA using survey data from the U.S. 

Forest Service’s North Central region as the starting point. The EPA adjusted these data based on the ratio of 

energy consumption in the surveyed climate to energy consumption in other areas of the country. For example, if the 

energy consumption in climate zone 5 (the warmest climate zone) was half of the energy consumption in climate 

zone 1 (the surveyed climate zone), burn rates in climate zone 5 were estimated to be 50 percent of the burn rates in 

climate zone 1. The energy consumption data for these adjustments was obtained from the Energy Information 

Administration (EIA)'s 2005 Residential Energy Consumption Survey (RECS). 

SESARM compiled 2005 RECS data to refine the EPA’s burn rates, by computing the average cords of wood burned 

per household for each of three categories: Rural, Urban (sum of cities, towns, and suburbs), and Total. SESARM 

then calculated two ratios: Rural to Total wood consumption per household (1.563); and Urban to Total wood 

consumption per household (0.537). These ratios were then applied to the existing burn rate profiles to create new 

Rural and Urban burn rate profiles for each of the SESARM region climate zones—2, 3, 4, and 5. After the 

appropriate calculations were performed the new burn rate profiles were developed by adding either an “r” for Rural 

or “u” for urban to the original RWC tool default burn rate profile number. They are as follows: 

1. Climate zone 2 : Nu and Nr 

2. Climate zone 3 : 3Au and 3Ar 

3. Climate zone 4 : 4u and 4r 

4. Climate zone 5 : 5u and 5r 

The next step in refining the burn rate information was to identify the criteria for assigning the Rural, Urban, and 

overall average burn rates (the original tool burn rate for a given climate zone) to each county within a climate zone. 

SESEARM developed these criteria, which are represented in Figure 2. 

 

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After implementing the appliance profile and burn rate refinements, SESARM developed emission summary 

comparisons of EPA’s default RWC Tool versus the Tool updated by ADEM. These comparisons were submitted for 

State//Local agency review and comment. The following identify the revisions that were implemented based on 

comments supplied by S/L agencies: 

• West Virginia revised the burn rate profiles in the following counties: 

o Berkeley – from default to urban; 

o Fayette – from rural to default; and 

o Jefferson – from rural to default. 

It should also be noted that Shelby County, Tennessee directed SESARM to utilize Local agency RWC emissions in 

place of the RWC Tool emissions. 

Figure 2. Decision Tree for Assigning Average (Default), Urban, or Rural Burn Profiles 

Was the County/City considered urban in the 2000 Census?

No.

Is Calculated Urban fraction less than 0.50?

No.

Are the number of tracts >1000 people/mile2 equal to zero?

No.

Is Calculated Urban fraction greater than or equal to 0.80?

No.

Is 2010 County Population 

Density >= 200 people/mile2?

No.

Use Default Burn Rate.

Yes.

Are the number of tracts >1000 

people/mile2 more than five?

Yes.

Use Urban Burn Rate.

No.

Use Default Burn Rate.

Yes.

Use Urban Burn Rate.

Yes.

Is Appliance Profile = 39?

Yes.

Use Default Burn Rate.

No.

Use Rural Burn Rate.

Yes.

Is 2010 County Population Density >= 

200 and has 1 or more tracts>= 

1000people/mile2?

Yes.

Use Default Burn Rate.

No.

Use Rural Burn rate.

Yes.

Use Urban Burn Rate.

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4. Estimation of Area Source Emissions from Gasoline Service Stations/Stage I 

TranSystems estimated stage I gasoline service station emissions using the NEI methodology referenced in 

Table II-2. To improve emission estimates, TranSystems prepared a proposed set of key Stage I gasoline service 

station emission calculation parameter values for review by S/L agencies: (a) county-level gasoline throughput 

values; (b) emission control parameter values; and (c) county/month-level Reid vapor pressure (RVP) values. 

TranSystems specifically requested that agencies provide any updates they have to these values, including updates 

to the following control information: (a) filling technologies used (splash, submerged, and balanced submerged); 

(b) the rule effectiveness of S/L requirements for submerged and/or balanced submerged filling; (c) the rule 

penetration (RP) for submerged and/or balanced submerged filling; and (d) the control efficiency of balanced 

submerged filling. The RP value represents the proportion of throughput that is filled using submerged/balanced 

submerged filling, while the remaining proportion is assumed to be splash filling. In keeping with past NEI practice, 

the default rule effectiveness assumption was 100 percent (rule effectiveness is an adjustment to reflect any 

assumed non-compliance with the requirements of a regulation). The default control efficiency for balanced 

submerged filling was 90 percent for all SESARM counties (control efficiency is the percentage of a source 

category's emissions that is controlled by a control device). There is no control efficiency for submerged filling 

because the emission reduction effects of submerged filling are accounted for in the emission estimation equation 

(via a submerged-filling specific saturation factor) rather than a post-emission estimation adjustment. 

TranSystems reviewed all updated parameter values supplied by S/L agencies, provided follow-up questions/data 

requests to ensure the completeness and validity of the data, and incorporated any updated Stage I emission 

calculation parameter values provided by agencies. TranSystems prepared revised base year stage I gasoline 

service station VOC emission estimates using the agency-supplied values and provided S/L agencies with

spreadsheets comparing the original and revised emission estimates. TranSystems updated the draft revised 

emission estimates to reflect S/L agency comments, and incorporated the final revised Stage I estimates into the 

revised final stationary area source inventory. 

C. INVENTORY SUPPLEMENTATION/FINAL DATA MERGING 

As directed by S/L agencies, TranSystems supplemented 2007 S/L agency supplied emissions data (when supplied) 

and TranSystems default emissions data with emissions data from the 2002 nonpoint source NEI, or in the case of 

Georgia, the State’s 2005 Consolidated Emissions Reporting Rule (CERR) submittal. To assist agencies that 

supplied S/L emissions data, TranSystems compiled a list of SCC/pollutant combinations in the S/L area’s portion of 

the 2002 nonpoint source NEI that did not match to combinations in either the S/L agency inventory or TranSystems’ 

default inventory. This list was documented in an Excel worksheet and transmitted along with a request for agencies 

to identify whether each combination’s emissions should be carried forward or grown to 2007 using EGAS growth 

factors. TranSystems contacted agencies with any necessary follow-up questions to clarify guidance on the NEI 

supplementation procedure. 

To assist agencies that did not supply their own emissions data, TranSystems compiled a list of SCC/pollutant 

combinations in the state’s portion of the 2002 nonpoint source NEI that did not match to combinations in 

TranSystems default inventory. These lists were documented in an Excel workbook, which also contained a

worksheet identifying associated inventory supplementation questions (e.g., “the 2002 NEI reports VOC emissions 

under Dry Cleaning/Perchloroethylene SCCs—TranSystems default inventory does not include VOC emissions for 

this SCC because perchloroethylene is no longer considered a VOC by EPA. Please confirm that VOC emissions 

from these SCCs should not be carried forward/grown”). After reviewing state agency responses to these data 

merging questions, TranSystems contacted agencies with follow-up questions as necessary to clarify state guidance. 

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Table II-13 displays the SCC/pollutant combinations for which 2002 nonpoint source NEI emissions were carried 

forward or grown to 2007 using growth factors from EGAS.14 Further documenting the data merging procedures are 

NIF EM table records and the SCC/county-level emission summaries that display a data source code for each record. 

Table II-14 presents the data source codes used to document the source of each area source emission record. The 

compiled inventory was converted into EPA’s NIF 3.0 nonpoint source file format.15 

 

14 Note that for some SCCs, EGAS did not provide growth factors. In these cases, Pechan used underlying EGAS 5.0 

information (i.e., the EGAS Version 5.0 SCC-to-growth indicator crosswalk and economic output data from version 5.5 of the 

Regional Economic Models, Inc. [REMI] model) to develop growth factors.

15 Pechan removed throughput data when 2002 nonpoint source NEI data were carried forward, 

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36 

Table II-13. Summary of Data Carried Forward/Grown From 2002 NEI 

Source Classification Code Source Classification Code Description Alabama Florida Georgia1

KentuckyRest of 

State Mississippi 

Sou

Caro

2275085000 Aircraft/Unpaved Airstrips/Total EGAS EGAS 2275900000 Aircraft/Refueling: All Fuels/All Processes ** (Use 25-01-080-xxx) EGAS 2301030000 Chemical Manufacturing/Process Emissions from Pharmaceutical Manuf/Total Carry EGAS EGAS 2301040000 Chemical Manufacturing/Fugitive Emissions from Synthetic Organic Chem Manuf/Total Carry EGAS Carry 2302050000 Food & Kindred Products/Bakery Products/Total EGAS EGAS EGAS Carry EGA2302070005 Food & Kindred Products/Fermentation/Beverages/Wineries EGAS 2302070010 Food & Kindred Products/Fermentation/Beverages/Distilleries EGAS 2305070000 Mineral Processes/Concrete, Gypsum, Plaster Products/Total 2306000000 Petroleum Refining/All Processes/Total EGAS 2306010000 Petroleum Refining/Asphalt Paving/Roofing Materials/Total 2307060000 Wood Products/Misc Wood Products/Total 2308000000 Rubber/Plastics/All Processes/Total Carry 2309000000 Fabricated Metals/All Processes/Total 2309100010 Fabricated Metals/Coating, Engraving, and Allied Services/Electroplating 2309100230 Fabricated Metals/Coating, Engraving, and Allied Services/Alkaline Cleaning 2310000000 Oil & Gas Expl & Prod/All Processes/Total: All Processes EGAS Carry EGAS EGAS Carry 2325000000 Mining &Quarrying/All Processes/Total Carry EGAS EGAS EGAS EGA2399000000 Industrial Processes: NEC/Industrial Processes: NEC/Total EGAS Carry EGAS EGAS 2401001010 Surface Coating/Architectural Coatings/Primers, Sealers, and Undercoaters 2401001050 Surface Coating/Architectural Coatings/All Other Architectural Categories 2401005600 Surface Coating/Auto Refinishing/Primers 2401005700 Surface Coating/Auto Refinishing/Top Coats 2440000000 Misc Industrial/All Processes/Total: All Solvent Types Carry EGAS 2461800000 Misc Non-industrial: Commercial/Pesticide Applic.: All Processes/Total: All Solvent Types EGAS EGAS EGAS EGAS Carry EGA2461850000 Misc Non-indus: Consumer/Pesticide Application: Agricultural/All Processes EGAS EGAS Carry 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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Source Classification Code Source Classification Code Description Alabama Florida Georgia1

KentuckyRest of 

State Mississippi 

Sou

Caro

2465800000 Misc Non-indus: Consumer/Pesticide Application/Total: All Solvent Types EGAS 2501000090 Petrol & Petrol Product Storage/All Storage Types: Breathing Loss/Distillate Oil 2501050090 Petrol & Petrol Product Storage/Bulk Terminals: All Evaporative Losses/Distillate Oil 2501050150 Petrol & Petrol Product Storage/Bulk Terminals: All Evaporative Losses/Jet Naphtha 2501050180 Petrol & Petrol Product Storage/Bulk Terminals: All Evaporative Losses/Kerosene 2501070000 Diesel Service Stations/Total: All Products/All Processes EGAS 2501070051 Diesel Service Stations/Stage 1: Submerged Filling Carry 2501070052 Diesel Service Stations/Stage 1: Splash Filling 2501070101 Diesel Service Stations/Stage 2: Displacement Loss/Uncontrolled 2501070103 Diesel Service Stations/Stage 2: Spillage 2501070201 Diesel Service Stations/Underground Tank: Breathing and Emptying Carry 2510000000 Organic Chemical Storage/All Storage Types: Breathing Loss/Total: All Products 2530000020 Bulk Materials Storage/All Storage Types/Cement 2530000100 Bulk Materials Storage/All Storage Types/Limestone 2530000120 Bulk Materials Storage/All Storage Types/Sand 2530050000 Bulk Materials Storage/Bulk Stations/Terminals/Total: All Products 2601000000 On-site Incineration/All Categories/Total Carry 2601010000 On-site Incineration/Industrial/Total EGAS EGAS 2601020000 On-site Incineration/Commercial/Institutional/Total EGAS EGAS EGAS 2620000000 Landfills/All Categories/Total EGAS 2620030000 Landfills/Municipal/Total Carry EGAS 2630020000 Wastewater Treatment/Public Owned/Total Processed 2630020001 Wastewater Treatment/Public Owned/Flaring of Gases 2640000000 TSDFs/All TSDF Types/Total: All Processes EGAS EGAS EGAS EGAS 2660000000 Leaking Underground Storage Tanks/Leaking Underground Storage Tanks/Total: All Storage Types EGAS EGAS 2801000000 Agric - Crops/Total Carry EGAS Carry EGA

WV SIP Revision: Regional Haze 5-Year Periodic Report 
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Source Classification Code Source Classification Code Description Alabama Florida Georgia1

KentuckyRest of 

State Mississippi 

Sou

Caro

2801000003 Agric - Crops/Tilling Carry EGAS EGAS Carry EGA2805001000 Agric - Livestock/Beef cattle - finishing operations on feedlots (drylots)/Dust Kicked-up by Hooves EGAS EGAS EGA2810030000 Structure Fires/Unspecified Carry EGAS EGAS Carry EGA2810050000 Motor Vehicle Fires/Unspecified EGAS EGAS 2810060200 Cremation/Animals 2830000000 Catastrophic/Accidental Releases/All Catastrophic/Accidental Releases/Total Carry 2830001000 Catastrophic/Accidental Releases/Industrial Accidents/Total Carry 2841000040 Misc Repair Shops/Misc Repair Shops/Soldering Operations 1 TranSystems Default inventory for GA supplemented with EGAS-grown emissions from Georgia’s 2005 CERR submission.

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Table II-14. Area Source Inventory Data Source Codes 

Code Description

P-07-X-NPT TranSystems default area source estimate 

P-07-X-PT TranSystems default total source estimate adjusted for point source activity (note that adjustment only 

occurred if emissions were reported in point source inventory). 

N-02-G 2002 nonpoint source NEI estimate grown using EGAS

N-02-F 2002 nonpoint source NEI estimate carried forward (no growth)

S-05-G 2005 Georgia area source CERR submission estimate grown using EGAS

S-07-X State agency-supplied estimate

L-07-X Local agency-supplied estimate

L-07-X-VR Estimated from local agency VOC estimate and TranSystems default inventory derived ratio of 

pollutant emission factor to VOC emission factor. 

D. QA/QC PROCEDURES 

In addition to the quality assurance procedures that TranSystems performed on the revised final 2007 stationary area 

source inventory (e.g., running EPA’s NIF QA/Content Checker program to check for referential integrity issues, 

invalid entries, and out of typical range values), TranSystems quality assured all updates provided by S/L agencies to 

ensure that they were correctly incorporated into the final inventory, and reviewed the ratios of post-point source 

subtraction emissions to pre-point source subtraction emissions to confirm that these subtractions were properly 

implemented. 

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III. 2007 NONROAD MOBILE SOURCE INVENTORY 

The nonroad sector is comprised of nonroad engines included in EPA’s NONROAD model, as well as other engines 

not modeled in NONROAD, including aircraft, commercial marine vessels and locomotives. A 2007 nonroad sector 

inventory was developed using the following general procedures: 

• NONROAD model categories were based on the National Mobile Inventory Model (NMIM2008). SESARM 

agencies were asked to review the latest 2007 NMIM County Database and provide revisions as needed to 

the NMIM inputs. 

• The aircraft category was based on EPA’s 2008 NEI. The 2008 estimates were backcast to 2007, and any 

state comments were incorporated. 

• The commercial marine vessel category was based on EPA’s 2008 NEI, adjusted to 2007, and 

supplemented with any state emissions data. 

• The locomotive category was based on draft Class I and Class II/III line haul emissions, as well as draft 

railyard emissions developed by ERTAC. Passenger and commuter rail emissions were based on EPA’s 

2002 NEI. State emission estimates were also included. 

A more detailed description of how 2007 emissions estimates for all nonroad categories were prepared is provided 

below. 

A. NONROAD MODEL CATEGORIES 

NONROAD model categories include equipment such as recreational marine and land-based vehicles, farm, 

construction and industrial machinery, and lawn and garden equipment. These equipment are powered by 

compression-ignition engines, which are typically diesel-fueled, as well as spark-ignition or gasoline-fueled engines. 

Compressed natural gas (CNG) and LPG engines are also included in the NONROAD model. Criteria pollutant 

emissions may not be reported for all SCCs for all counties in the SESARM region, and will depend on the 

geographic allocation methods used by the model, or state-specific allocation data.

NMIM2008 incorporates EPA’s latest NONROAD model (NONROAD2008) released in April 2009, and reflects all of 

EPA’s final nonroad standards to date. TranSystems first distributed the 2007 year NMIM county-level database 

(NCD) to SESARM agencies for review and comment. TranSystems prepared a report to accompany nonroadrelated tables from the 2007 NCD providing instructions for agencies to provide any updates to these files that may 

represent S/L/T improvements to the NMIM/NONROAD defaults (Pechan, 2009c). A summary of the tables 

distributed and comments received from states is provided in Table III-1. 

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Table III-1. Summary of 2007 NCD Tables and State Comments

NMIM Table Description Comments State(s)

County County-specific variables Revised OzoneSeasonStartMonth and 

OzoneSeasonEndMonth 

AL, SC, VA

Update Barometric Pressure Jefferson County KY, VA

CountyYearMonthHour Hourly temps and relative humidity 

by month and county 

Revised temperatures and relative humidity using NCDC 

data and EPA-prescribed methodology 

VA

CountyNRFile External NONROAD data files Provided updates to SEASON.DAT file NC

Revised Underground Mining Cty Allocation File WV

CountyYear Additional external data files (mostly 

onroad related) 

None

CountyYearMonth Maps counties to monthly fuel data Revised county/monthly gasoline profile assignments GA, KY, Jefferson County 

KY, NC, SC, 

Davidson County TN, VA 

Gasoline Gasoline fuel properties Revised/added gasoline fuel profiles GA, KY, Jefferson County 

KY, NC, SC, Davidson 

Cty TN, VA 

Diesel Diesel sulfur content Revised Diesel sulfur content Davidson County, TN

Natural Gas Natural gas content None

Further descriptions of the state data provided and how they were evaluated and used is provided below.

CountyYearMonthHour Table 

Virginia provided revised temperatures and relative humidity using National Climatic Data Center (NCDC) data and 

the EPA-prescribed methodology for stretching hourly averages to capture daily minima and maxima values. 

CountyNR Table 

North Carolina provided an updated SEASON.DAT file (37000.sea) that changed the seasonal profile assignment for 

North Carolina from the default Mid-Atlantic region to the Southeast region. 

West Virginia provided an updated county allocation file for distributing activity and emissions related to underground 

mining equipment in their state. This revised county distribution was based on 2007 Underground Coal Production 

values as reported by the West Virginia’s Office of Miners' Health Safety and Training 2007 Coal Production by 

County. 

CountyYearMonth, Gasoline, and Diesel Tables 

Several states provided revised fuel profile assignments by county, as reflected in changes to the CountyYearMonth 

table. In many cases, this also involved the creation of new gasoline profiles in the Gasoline table. The revisions 

submitted primarily related to changes by month for Reid Vapor Pressure (RVP) values as well as gasoline sulfur 

content. Updates to the oxygenated fuel data were provided for some states as well. 

Some states also revised the diesel fuel sulfur content values for 2007. For regional consistency, unless the values 

were based on actual testing that reflected the diesel sulfur content in use for an area, the NMIM default values of 

1218 parts per million (ppm) for land-based equipment 1389 ppm for recreational marine were retained. 

Once the inputs to NMIM/NONROAD were quality assured, TranSystems ran NMIM to generate 2007 annual 

emission estimates for all SESARM states for all nonroad SCCs. Emissions from aircraft ground support equipment 

are now entirely addressed by the aircraft sector inventory (see discussion under Section III.B of this report). 

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TranSystems removed emission estimates from the NMIM output for the airport GSE SCCs (i.e., SCCs 2265008005, 

2267008005, and 2270008005). 

B. AIRCRAFT 

Airport-related emission estimates were developed for the following SCCs listed in Table III-2. 

Table III-2. Aircraft Source Classification Codes 

Description SCC 

Military Aircraft 2275001000 

Commercial Aircraft 2275020000 

General Aviation - Piston 2275050011 

General Aviation - Turbine 2275050012 

Air Taxi - Piston 2275060011 

Air Taxi - Turbine 2275060012 

Auxiliary Power Unit (APU) 2275070000 

4-Stroke Gasoline GSE 2265008005 

LPG GSE 2267008005 

CNG GSE 2268008005 

Diesel GSE 2270008005 

2007 aircraft emissions were primarily based on EPA’s 2008 NEI. The procedures and data for developing aircraft 

emissions are described in further detail in EPA’s 2008 NEI documentation (ERG, 2009a). 

For commercial aircraft, the emission estimation methodology relied on airport and aircraft-specific landing and takeoff (LTO) data, coupled with mode and aircraft-specific emission rates from the FAA’s Emission and Dispersion 

Modeling System (EDMS). Emissions for ground support equipment (GSE) and auxiliary power units (APUs)

associated with commercial air carriers were estimated by EDMS, using operating time defaults based on the type of 

service performed. LTO data for general aviation and air taxi were obtained from FAA’s Terminal Area Forecasts 

(TAF) and 5010 Forms. This activity was assigned to jet and propeller-driven fractions, and fleet-average emission 

factors were then applied. Finally, military aircraft activity at civilian and commercial airports was obtained by EPA 

from FAA’s TAF, and these emissions (with a few noted exceptions) were largely included in the 2007 SEMAP. 

Unless provided by a state or local agency (e.g., Georgia, North Carolina, and Virginia), military aircraft activity and 

emissions occurring at military facility bases are not accounted for in the SEMAP inventory. 

The 2008 emissions and LTO data were back-cast to 2007 using approach operations by airport and aircraft type 

compiled from the FAA’s Air Traffic Activity Data System (ATADS) (FAA, 2010). The airport-level LTOs were 

assigned to counties and summed for the county. For counties with aircraft emissions without a county match in 

ATADS, state average growth factors were calculated and applied. The county-level growth factors are not 

presented in this report, but could be provided to SESARM if requested. The 2007 to 2008 growth factors were 

developed for each of the six airport source categories. Commercial aircraft, APU, and GSE categories relied on 

growth factors calculated from commercial air carrier LTOs. General aviation and air taxi were grown using LTO data 

reported for these specific aviation categories. Military aircraft were held constant from 2008 to 2007. 

State-supplied data are summarized in Table III-3. Comments from Alabama, Georgia, and Davidson County, 

Tennessee related to removing non-operational airports, correcting county assignments for individual airports, or 

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updating emissions for specific commercial airports. Georgia, North Carolina, and Virginia submitted military aircraft 

emissions for military bases in their state. In addition, North Carolina provided emissions for military aircraft activity 

at commercial airports, and also provided diesel GSE emissions associated with all military aircraft. Note that for 

several North Carolina facilities, EPA had already reported diesel GSE emissions associated with commercial aircraft 

activity, so state-provided diesel GSE emissions were added to these existing EPA estimates at the SCC level. 

Table III-3. Summary of State Updates to Aircraft Category Emissions 

State/County SCC SCC Description Pollutants Comments

Alabama 2275050011 General Aviation Piston All Removed emissions for 1 non-operational airport; 1 airport in 

GA incorrectly assigned to AL county 

2275050012 General Aviation Turbine

Georgia 2275001000 Military Aircraft All Updated emissions for Dobbins Air Reserve Base

2275007000 Auxiliary Power Unit (APU) All Updated emissions for Dobbins Air Reserve Base

2275050011 General Aviation Piston All Made revisions to county assignments for 2 airports

2275050012 General Aviation Turbine

All SCCs See Table III-2 All Updated emissions for Atlanta Hartsfield Airport

North Carolina 2275001000 Military Aircraft All Added military aircraft emissions at military bases and civilian 

airports 

2270008005 Diesel Airport GSE

Davidson County, TN 2275050011 General Aviation Piston All Removed emissions for 4 non-operational airports; reassigned 

1 airport from Davidson to Rutherford County 

2275050012 General Aviation Turbine

2275020000 Commercial Aircraft All Updated emissions for Nashville International Airport

2265008005 Gasoline Airport GSE All Updated emissions for Nashville International Airport

2270008005 Diesel Airport GSE All Updated emissions for Nashville International Airport

Virginia 2275001000 Military Aircraft All but PM10, PM-2.5, 

SO2 

Added military aircraft emissions for 15 military bases

North Carolina and Georgia provided estimates for all needed pollutants, and Virginia provided estimates for all 

pollutants, with some exceptions for PM-10 and PM-2.5. Where PM-10 was provided by Virginia for two facilities, we 

estimated PM-2.5 using a particle size multiplier of 0.669, from Table “Military Aircraft Emission Factors” in Appendix 

A to EPA 2008 NEI documentation (ERG, 2009a). PM and SO2 emissions for the remaining military facilities in

Virginia were not estimated. 

C. COMMERCIAL MARINE VESSELS 

Commercial marine vessel emissions are reported under the following SCCs: 

• 2280002100 – Diesel, In Port 

• 2280002200 – Diesel, Underway 

• 2280003100 – Residual, In Port 

• 2280003200 – Residual, Underway 

For the purpose of the NEI it was assumed that Category 1 and 2 vessels typically use distillate fuels, while 

Category 3 vessels primarily use residual blends. Category 3 engines are defined as having displacement above 

30 liters per cylinder. 

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2007 CMV emissions were based largely on EPA’s 2008 NEI. For Category 1 and 2 engines, national diesel

emissions, based on national 2008 fuel sales, were split into near-shore port and underway components. Port 

emissions were assigned to 150 largest ports using port traffic data per Waterborne Commerce of the U.S. For the 

county allocation procedure, EPA developed a GIS shape file library based on Bureau of Transportation data to more 

precisely assign port emissions to counties, and to better allocate underway emissions to line segments/counties. 

This represents an improvement to the spatial allocation procedure used for previous versions of the NEI. 

2008 Category 3 CMV estimates were projected from a 2002 hourly modeling inventory developed by EPA’s Office of 

Transportation and Air Quality (OTAQ), and aggregated to an annual basis for the NEI. EPA developed Category 3 

inventories for a total of 117 deep sea and inland ports, accounting for 4 different types of near-port emissions, 

including hotelling, maneuvering, reduced-speed zone, and cruise mode. EPA spatially allocated emissions using 

GIS shapefiles to specify the geographic locations for each type of near port emissions. Additional details concerning 

the methodologies are described in EPA’s 2008 NEI documentation (ERG, 2009b). 

The 2008 CMV estimates were then adjusted to represent 2007. For Category 1 & 2 diesel commercial marine 

vessels, 2007 emissions were estimated by applying growth factors to the 2008 emissions. National 2007 and 2008 

emissions, by pollutant, were used to estimate the growth factors (EPA, 2008a). Emissions were adjusted at a 

national level because the surrogate data used to estimate county-level emissions for the 2008 NEI actually 

represent year 2007. Table III-4 shows the growth factors, by pollutant. The PM10-PRI and PM25-PRI growth factor 

value was also used for NH3. 

Table III-4. Category 1 & CMV Growth Factors, by Pollutant 

Pollutant Growth Factor

CO 1.009

NH3 1.045

NOx 1.016

PM10-PRI 1.045

PM25-PRI 1.045

SO2 1.110

VOC 1.008

To estimate 2007 emissions for Category 3 residual commercial marine vessels, an annual average regional growth 

rate was applied as a corresponding decrease to the 2008 NEI emissions (EPA, 2008b). A correspondence was 

developed between the SESARM states and available regional growth rates for the East Coast and Gulf Coast. 

Table III-5 contains this correspondence along with the growth factor. Counties in the State of Florida were assigned 

to the two regions as appropriate. 

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Table III-5. Category 3 CMV Growth Factors, by State and SCC

FIPSST State SCC Region GF

01 AL 2280003100 Gulf Coast 0.955

01 AL 2280003200 Gulf Coast 0.955

12 FL 2280003100 Gulf Coast 0.955

12 FL 2280003200 Gulf Coast 0.955

12 FL 2280003100 East Coast 0.971

12 FL 2280003200 East Coast 0.971

13 GA 2280003100 East Coast 0.971

13 GA 2280003200 East Coast 0.971

21 KY 2280003100 East Coast 0.971

21 KY 2280003200 East Coast 0.971

28 MS 2280003100 Gulf Coast 0.955

28 MS 2280003200 Gulf Coast 0.955

37 NC 2280003100 East Coast 0.971

37 NC 2280003200 East Coast 0.971

45 SC 2280003100 East Coast 0.971

45 SC 2280003200 East Coast 0.971

47 TN 2280003100 East Coast 0.971

47 TN 2280003200 East Coast 0.971

51 VA 2280003100 East Coast 0.971

51 VA 2280003200 East Coast 0.971

54 WV 2280003100 East Coast 0.971

54 WV 2280003200 East Coast 0.971

State provided data are listed in Table III-6. South Carolina provided a county-level inventory for the port of 

Charleston for 2005. The 2005 estimates were grown to 2007 using Army Corps of Engineers data on total

commodity tonnage handled at the Port of Charleston (ACE, 2010). Davidson County provided a county-level CMV 

inventory reported under the general SCC 2280000000. Finally, Virginia also provided a military marine emissions 

inventory, with the exclusion of Coast Guard Vessels, since activity for these ships should be captured by EPA’s 

Category 1 & 2 inventory. The port and underway components of Virginia’s marine inventory were assigned to the 

Residual, In Port and Residual, Underway SCCs, respectively. In counties where EPA had already reported residual 

port or underway emissions, state-provided military marine emissions were added to these existing EPA estimates at 

the SCC level. Any necessary pollutant augmentation is described in Table III-6.

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Table III-6. Summary of State Updates to Commercial Marine Category Emissions 

State/County SCC SCC Description Pollutants Comments Additional RevisionsCharleston 

County, SC 

2280002100 Category 1&2 Residual 

Port 

All but NH3 Removed NEI emissions and added SC supplied emissions 

for Charleston County, SC. 

NH3 estimated using PM

2280002200 Category 1&2 Residual 

Underway 

All but NH3 NH3 estimated using the 

for the particular County

2280003100 Category 3 Diesel Port All but NH3 NH3 estimated using PM2280003200 Category 3 Diesel 

Underway 

All but NH3 NH3 estimated using the 

for the particular County

Davidson 

County, TN 

2280000000 All Commercial Marine All but PM-10, PM-25 

and NH3

Removed all CMV NEI emissions for Davidson County, TN 

and added emissions supplied by the county. 

PM-10 estimated using 

consumption (provided PM-25 estimated using NH3 estimated using PM

Shelby 

County, TN 

2280002100 Category 1&2 Residual 

Port 

All Replaced CMV NEI emissions for Shelby

County, TN with emissions supplied by the county. 

2280002200 Category 1&2 Residual 

Underway 

All but NH3 Relied on EPA NEI NH3 

Virginia 2280003100 Category 3 Diesel Port All but VOC, PM-25, 

and NH3

Added military marine emissions VOC estimated using H

PM-25 estimated using NH3 estimated using rat

the particular County/SC

2280003200 Category 3 Diesel 

Underway 

All but VOC, PM-25, 

and NH3

VOC estimated using H

PM-25 estimated using NH3 estimated using rat

the particular County/SC

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D. LOCOMOTIVES 

Locomotive emissions are reported under the following SCCs: 

• 2285002006 – Diesel Class I Line Haul 

• 2285002007 – Diesel Class II/III Line Haul 

• 2285002008 – Diesel Passenger (Amtrak) 

• 2285002009 – Diesel Commuter 

• 2285002010 – Diesel Switchyard Locomotives 

Class I line haul operations typically account for the majority of fuel consumed and emissions when preparing 

locomotive inventories. As such, resources should be focused on developing emission estimates for these 

operations relative to other rail-related operations. However, for some local areas, certain operations related to 

switchyard activity may also be important. 

For Class I line-haul locomotives, emissions are normally calculated by multiplying the amount of fuel consumed in 

the inventory area by pollutant-specific emission factors. This calculation is performed for each railroad. The results 

for each railroad are then summed to obtain the total Class I railroad emissions in the inventory area.

For Class I line haul, TranSystems obtained 2007 emission estimates from the Eastern Regional Technical Advisory 

Committee (ERTAC, 2010a). ERTAC used the Federal Railroad Administration’s GIS data to construct a dataset of 

link-level million gross tons per mile (MGT). Next the Railroad Fuel Consumption Index (RFCI) value was calculated 

for each railroad, which represents the number of GTM produced per gallon of diesel fuel. When applied to each 

link’s GTM per year, link-based fuel consumption can be calculated. This methodology allows for a more accurate 

reflection of how GTM are actually concentrated across rail line route miles. Finally, the fuel consumed is multiplied 

by the various emission factors derived for each Class I rail line to determine link-level emissions for each pollutant. 

An important aspect is determining the fraction of locomotives that fall under each regulatory “Tier,” since each Tier 

has an increasingly stringent emission rate for pollutants of concern. 

A limitation of the link-level MGT data maintained by the FRA is that the data are proprietary and can only be publicly 

released with the express permission of each Class I railroad. In addition, when the FRA coded the link-level MGT 

data they did not provide a means for separating out individual MGT contributions for links that are operated by 

multiple railroad companies. As such, some assumptions were made for these contributions by ERTAC. 

Class II/III line haul emissions were also developed and distributed by ERTAC (ERTAC, 2010b). Limited

documentation has been developed to describe the procedures used by ERTAC to develop this inventory. Generally, 

fuel consumption for all Class II/III railroads was obtained from the American Shortline and Regional Railroad 

Association and assigned to counties using route miles by rail line within each county. An average fuel use factor 

expressed in gallons per mile was then multiplied by the route miles to estimate fuel consumption by railroad and by 

county. Class II/III locomotives were all assumed to be uncontrolled with respect to emission rates used for 

estimating pollutant emissions. Class II/III rail emissions represent calendar year 2008, and as such were back-cast 

to 2007 using a surrogate growth indicator. A SESARM regional growth factor of 1.438 was developed using 2007 

and 2008 total distillate fuel sales/deliveries to railroad consumers which were obtained from the DOE Energy 

Information Administration State Energy Data (DOE, 2009a). 

Passenger and commuter rail line emissions from EPA’s 2002 NEI were grown to 2007. For both categories, the 

growth factor was developed using 2002 and 2007 passenger/commuter fuel use data obtained from the DOE

Transportation Energy Data Book (DOE, 2009b). For passenger rail operations, the growth factor value was 0.732. 

For commuter rail operations, a growth factor of 1.11 was used. 

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Finally, a switchyard inventory was completed by ERTAC on June 4, 2010 (ERTAC, 2010c). This inventory was 

compiled at a railyard level by ERTAC, but was summed to a county level for use in the SEMAP 2007 inventory. In 

general, switcher emissions were estimated using total switcher fuel consumption available from each Class I R-1 

report allocated to railyards based on average density code data reported by the Federal Railroad Administration. 

Documentation describing the specific methodology and data sources used will be forthcoming from ERTAC. 

Some state data were provided for the locomotive category. These data are summarized in Table III-7. North 

Carolina provided a statewide passenger rail inventory for 2007. Davidson County provided a county level inventory 

comprised of Class I line haul and switchyard activity, reported under the general SCC 2285000000. Shelby County 

provided an updated Class I line haul, passenger, and yard locomotive inventory for most pollutants. Any needed 

pollutant augmentation is described in Table III-7. 

E. QA/QC PROCEDURES 

TranSystems performed the following quality assurance procedures on the final 2007 nonroad sector inventory. 

For the NONROAD/NMIM categories, TranSystems quality assured all NCD updates provided by states to ensure 

consistency with the NCD formats, and for reasonableness. Where questions came up, we coordinated with the 

appropriate S/L agency. Cross-checks were performed to confirm that state-supplied revisions were correctly 

incorporated into the NCD. TranSystems compared results with 2007 emission estimates prepared by EPA using a 

prior version of the NCD. These comparisons were performed to ensure that results changed as expected given the 

updates made by specific states to the NMIM inputs.

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Table III-7. Summary of State Updates to Locomotive Category Emissions 

State SCC SCC Description Pollutants Comments Add

North Carolina 2285002008 Line Haul Locomotives: Passenger 

Trains (Amtrak) 

All but NH3 Replaced NEI passenger emissions with 

NC supplied emissions 

NH3 

2008 for t

2285002007 Line Haul Locomotives: Class II/III 

Locomotives 

All Removed activity/emissions for several rail 

lines 

Davidson County, TN 2285000000 All Railroad All Fuels All but PM-25 

and NH3

Replaced ERTAC rail emissions with 

Davidson County supplied emissions 

PM-

multNH3 NEI part

Shelby County, TN 2285002006 Line Haul Locomotives: Class I 

Operations 

All but PM-25 and 

NH3

Replaced ERTAC rail emissions with 

Shelby County supplied emissions 

Reli

miss

2285002008 Line Haul Locomotives: Passenger 

Trains (Amtrak) 

All but NH3 Reli

emis

2285002010 Yard Locomotives All 

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TranSystems compiled records for the SESARM region from EPA’s NEI for aircraft, CMV, and passenger/commuter 

rail, and obtained Class I and Class II/III line haul, and railyard emission estimates from ERTAC. TranSystems 

performed and quality assured any needed adjustments to year 2007 (i.e., correct application of growth or backcast 

factors). Cross-checks were also performed to verify that state-supplied emission estimates were correctly 

incorporated into the draft inventory. TranSystems also calculated missing pollutants for SCC-level state emission 

estimates, where emission factors or emission ratios were available. 

Emission estimates were converted into EPA’s NIF3.0 as a final deliverable. For the NMIM categories, commercial 

marine, and locomotive, separate database files were prepared for each subsector following EPA’s NIF3.0 nonpoint 

format. Aircraft emission estimates were prepared in EPA’s NIF3.0 point source format. EPA’s NIF QA Checker 

program was then run on these final files, and any referential integrity issues and invalid codes were identified and 

corrected. Finally, data source codes as described in Table III-8 were added to the NIF3.0 files to represent the 

source of the SCC, county-level emissions data for the final inventory.

Table III-8. Data Source Codes Used for Revised Final 2007 Nonroad Mobile Emission Estimates 

Code Description

P-07-X TranSystems default

N-02-G 2002 NEI grown

S-07-X State supplied

S-07-X-PS State supplied added to TranSystems default

S-05-G State supplied 2005 grown 

L-07-X Local agency supplied

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IV. EMISSIONS SUMMARIES 

This section presents the emission summaries for the revised final 2007 stationary area and nonroad mobile 

emissions inventory for the SEMAP project. In addition to the summaries provided in this section, TranSystems has 

also provided SESARM with detailed county-level emission summaries in Excel worksheets. 

A. STATIONARY AREA SOURCE EMISSIONS 

Table IV-1 provides a summary of the final 2007 SESARM area source emissions inventory by the four major area 

source subsectors. Table IV-2 displays final area source emission estimates by state, as well as the percent 

contribution of each state to total regional emissions. Similar summaries providing 2007 annual state-level emission 

estimates for each major area source sector, as well as percent contributions by state, are shown in Tables IV-3 

through IV-6. 

Table IV-1. Final 2007 SESARM Area Source Emissions by Major Sector 

Category 

Pollutant Emissions, TPY 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Combustion 81,876 105,283 28,444 95,946 69,362 273,557 7,901 

Solvents 712,961 24 4 0.1 

Fugitive Dust 2,311,660 242,976 

All Other 2,905 11,807 433,868 299,768 109,872 157,631 576,975 

All Nonpoint 84,782 117,090 1,175,273 2,707,398 422,214 431,188 584,876 

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Table IV-2. Final 2007 Area Source Emission Estimates by State 

State 

Pollutant Emissions, TPY 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 431 3,940 79,030 349,981 41,587 15,152 62,426 

Florida 11,203 13,014 296,131 340,693 55,515 43,381 33,940 

Georgia 4,858 25,552 143,469 652,757 95,801 83,246 86,544 

Kentucky 15,590 12,693 75,100 226,829 40,341 55,450 52,332 

Mississippi 344 6,091 74,755 326,350 42,758 22,377 58,774 

North Carolina 8,365 12,715 152,825 51,678 16,829 47,379 169,440 

South Carolina 6,048 9,353 76,838 266,749 39,538 32,208 30,248 

Tennessee 14,415 12,418 111,100 215,667 33,948 44,668 35,277 

Virginia 17,022 17,740 133,935 176,265 39,034 63,838 43,038 

West Virginia 6,504 3,574 32,089 100,429 16,862 23,490 12,858 

Total SESARM 84,782 117,090 1,175,273 2,707,398 422,214 431,188 584,876 

 

State 

Percentage of Regional Total 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 0.5 3.4 6.7 12.9 9.8 3.5 10.7 

Florida 13.2 11.1 25.2 12.6 13.1 10.1 5.8 

Georgia 5.7 21.8 12.2 24.1 22.7 19.3 14.8 

Kentucky 18.4 10.8 6.4 8.4 9.6 12.9 8.9 

Mississippi 0.4 5.2 6.4 12.1 10.1 5.2 10.0 

North Carolina 9.9 10.9 13.0 1.9 4.0 11.0 29.0 

South Carolina 7.1 8.0 6.5 9.9 9.4 7.5 5.2 

Tennessee 17.0 10.6 9.5 8.0 8.0 10.4 6.0 

Virginia 20.1 15.2 11.4 6.5 9.2 14.8 7.4 

West Virginia 7.7 3.1 2.7 3.7 4.0 5.4 2.2 

Total SESARM 100 100 100 100 100 100 100 

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Table IV-3. Final 2007 Combustion Emission Estimates by State 

State 

Pollutant Emissions, TPY 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 376 3,490 1,903 1,400 1,391 11,257 449 

Florida 11,032 12,163 2,421 27,419 19,713 29,097 585 

Georgia 4,528 23,648 2,751 14,118 14,092 59,474 1,851 

Kentucky 15,250 11,287 3,892 13,006 8,573 31,102 670 

Mississippi 206 5,274 1,238 1,074 1,043 9,933 307 

North Carolina 8,090 11,534 4,313 4,795 4,394 29,963 910 

South Carolina 5,900 8,480 1,743 10,510 7,926 18,699 427 

Tennessee 14,058 10,853 2,929 12,756 2,521 25,816 833 

Virginia 16,061 15,569 5,270 8,142 7,358 43,205 1,443 

West Virginia 6,376 2,985 1,984 2,728 2,354 15,012 424 

Total SESARM 81,876 105,283 28,444 95,946 69,362 273,557 7,901 

 

State 

Percentage of Regional Total 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 0.5 3.3 6.7 1.5 2.0 4.1 5.7 

Florida 13.5 11.6 8.5 28.6 28.4 10.6 7.4 

Georgia 5.5 22.5 9.7 14.7 20.3 21.7 23.4 

Kentucky 18.6 10.7 13.7 13.6 12.4 11.4 8.5 

Mississippi 0.3 5.0 4.4 1.1 1.5 3.6 3.9 

North Carolina 9.9 11.0 15.2 5.0 6.3 11.0 11.5 

South Carolina 7.2 8.1 6.1 11.0 11.4 6.8 5.4 

Tennessee 17.2 10.3 10.3 13.3 3.6 9.4 10.5 

Virginia 19.6 14.8 18.5 8.5 10.6 15.8 18.3 

West Virginia 7.8 2.8 7.0 2.8 3.4 5.5 5.4 

Total SESARM 100 100 100 100 100 100 100 

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Table IV-4. Final 2007 Solvent Emission Estimates by State

State 

Pollutant Emissions, TPY 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 54,760 

Florida 164,244 

Georgia 86,349 

Kentucky 45,697 1 1 

Mississippi 42,797 

North Carolina 113,623 0.1 

South Carolina 38,952 

Tennessee 63,279 22 4 

Virginia 89,798 

West Virginia 13,463 

Total SESARM 712,961 24 4 0.1 

 

State 

Percentage of Regional Total 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 7.7 0.0 0.0 0.0 

Florida 23.0 0.0 0.0 0.0 

Georgia 12.1 0.0 0.0 0.0 

Kentucky 6.4 5.0 16.5 0.0 

Mississippi 6.0 0.0 0.0 0.0 

North Carolina 15.9 0.0 0.0 100.0 

South Carolina 5.5 0.0 0.0 0.0 

Tennessee 8.9 95.0 83.5 0.0 

Virginia 12.6 0.0 0.0 0.0 

West Virginia 1.9 0.0 0.0 0.0 

Total SESARM 100 100 100 100 

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Table IV-5. Final 2007 Fugitive Dust Emission Estimates by State 

State 

Pollutant Emissions, TPY 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 318,858 33,717 

Florida 270,262 22,325 

Georgia 580,492 62,104 

Kentucky 184,551 19,979 

Mississippi 301,642 32,897 

North Carolina 37,467 3,722 

South Carolina 235,508 23,304 

Tennessee 176,850 19,521 

Virginia 134,014 18,730 

West Virginia 72,018 6,676 

Total SESARM 2,311,660 242,976 

 

State 

Percentage of Regional Total 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 13.8 13.9 

Florida 11.7 9.2 

Georgia 25.1 25.6 

Kentucky 8.0 8.2 

Mississippi 13.0 13.5 

North Carolina 1.6 1.5 

South Carolina 10.2 9.6 

Tennessee 7.7 8.0 

Virginia 5.8 7.7 

West Virginia 3.1 2.7 

Total SESARM 100 100 

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Table IV-6. Final 2007 All Other Area Source Emission Estimates by State 

State 

Pollutant Emissions, TPY 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 56 450 22,368 29,724 6,480 3,895 61,977 

Florida 171 851 129,465 43,012 13,477 14,285 33,355 

Georgia 331 1,903 54,369 58,148 19,605 23,771 84,693 

Kentucky 340 1,406 25,512 29,271 11,789 24,347 51,662 

Mississippi 138 817 30,720 23,634 8,819 12,445 58,467 

North Carolina 276 1,181 34,888 9,417 8,713 17,416 168,530 

South Carolina 147 873 36,143 20,732 8,308 13,508 29,820 

Tennessee 357 1,565 44,892 26,039 11,903 18,852 34,444 

Virginia 961 2,172 38,867 34,109 12,946 20,633 41,594 

West Virginia 128 589 16,643 25,683 7,833 8,478 12,433 

Total SESARM 2,905 11,807 433,868 299,768 109,872 157,631 576,975 

 

State 

Percentage of Regional Total 

SO2 NOx VOC PM10-PRI PM2.5-PRI CO NH3

Alabama 1.9 3.8 5.2 9.9 5.9 2.5 10.7 

Florida 5.9 7.2 29.8 14.3 12.3 9.1 5.8 

Georgia 11.4 16.1 12.5 19.4 17.8 15.1 14.7 

Kentucky 11.7 11.9 5.9 9.8 10.7 15.4 9.0 

Mississippi 4.8 6.9 7.1 7.9 8.0 7.9 10.1 

North Carolina 9.5 10.0 8.0 3.1 7.9 11.0 29.2 

South Carolina 5.1 7.4 8.3 6.9 7.6 8.6 5.2 

Tennessee 12.3 13.3 10.3 8.7 10.8 12.0 6.0 

Virginia 33.1 18.4 9.0 11.4 11.8 13.1 7.2 

West Virginia 4.4 5.0 3.8 8.6 7.1 5.4 2.2 

Total SESARM 100 100 100 100 100 100 100 

B. NONROAD MOBILE SOURCE EMISSIONS 

Table IV-7 provides a summary of final 2007 nonroad mobile annual emissions by the four major nonroad subsectors 

for the SESARM region. PM-10 and PM-2.5 emissions represent primary PM, and are reported as PM10-PRI, and 

PM25-PRI. The commercial marine category is the most significant contributor regionally to SO2 emissions. 

Nonroad model categories account for the large majority of emissions for NOx, VOC, PM10-PRI, PM25-PRI, and CO. 

Table IV-8 presents a summary of the final annual NONROAD model emission estimates by state, as well as the 

percent contribution of each state to total regional emissions. Similar summaries providing 2007 annual state-level 

emission estimates for aircraft, commercial marine, and locomotives, as well as the percent contributions, are shown 

in Tables IV-9, IV-10, and IV-11, respectively. 

Since development of the draft inventory, locomotive switchyard emissions developed by ERTAC have been added. 

These emission estimates were developed at a railyard level, and summed to the county level for the 2007 SEMAP 

inventory. As mentioned in Section III.D, we are providing an electronic file that provides emissions at a railyard 

level, so that SESARM agencies can review the data that form the basis of the county-level estimates, and make any 

needed revisions. In addition, for the aircraft category, EPA made some additions to the 2008 military aircraft NEI 

that formed the basis of the initial draft SEMAP inventory. As discussed in Section III.B, we are distributing an 

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electronic file showing additional emission records calculated by EPA for military aircraft by airport for the SESARM 

region. Agencies should provide feedback as to whether these records should be added to their inventory. 

Table IV-7. Final 2007 SESARM Nonroad Source Emissions by Major Sector 

 Category 

Pollutant Emissions, tons per year 

SO2 NOx VOC PM10-PRI PM25-PRI CO NH3

NONROAD Model 23,308 404,580 629,693 41,489 39,517 4,642,050 447 

Aircraft 3,105 32,153 18,444 4,066 3,037 196,823 NA 

Commercial Marine 33,715 162,801 4,516 7,869 7,462 28,726 86 

Locomotive 2,178 155,025 8,285 5,085 4,693 21,633 67 

All Nonroad 62,307 754,560 660,938 58,508 54,709 4,889,232 601 

Table IV-8. Final 2007 NONROAD Model Emission Estimates by State 

 State Pollutant Emissions, tons per year 

SO2 NOx VOC PM10-PRI PM25-PRI CO NH3

Alabama 1,483 26,695 49,956 2,806 2,665 316,138 30 

Florida 6,714 109,218 193,974 11,543 10,986 1,431,464 134 

Georgia 3,079 51,524 69,914 5,315 5,067 629,419 56 

Kentucky 1,630 28,665 36,641 2,877 2,749 240,397 28

Mississippi 1,147 20,050 33,760 2,126 2,025 187,258 21 

North Carolina 3,111 55,743 76,568 5,434 5,181 597,360 58 

South Carolina 1,522 26,742 42,293 2,661 2,534 328,606 29 

Tennessee 1,884 36,756 54,089 3,637 3,467 388,496 38 

Virginia 2,329 41,658 55,164 4,132 3,937 416,303 45 

West Virginia 410 7,529 17,333 957 905 106,610 9 

Total SESARM 23,308 404,091 630,621 41,489 39,517 4,674,012 447 

 

 State Percentage of Regional Total 

SO2 NOx VOC PM10-PRI PM25-PRI CO NH3

Alabama 6.4 6.6 7.9 6.8 6.7 6.8 6.7 

Florida 28.8 27.0 30.8 27.8 27.8 30.8 29.9 

Georgia 13.2 12.7 11.1 12.8 12.8 13.6 12.6 

Kentucky 7.0 7.1 5.8 6.9 7.0 5.2 6.2 

Mississippi 4.9 5.0 5.4 5.1 5.1 4.0 4.7 

North Carolina 13.3 13.8 12.2 13.1 13.1 12.9 13.0 

South Carolina 6.5 6.6 6.7 6.4 6.4 7.1 6.6 

Tennessee 8.1 9.1 8.6 8.8 8.8 8.4 8.4 

Virginia 10.0 10.3 8.8 10.0 10.0 9.0 10.0 

West Virginia 1.8 1.9 2.8 2.3 2.3 2.3 2.0 

Total SESARM 100 100 100 100 100 100 100 

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Table IV-9. Final 2007 Aircraft Emission Estimates by State 

 State Pollutant Emissions, tons per year 

SO2 NOx VOC PM10-PRI PM25-PRI CO 

Alabama 51 440 891 294 205 14,778 

Florida 992 10,746 5,060 1,028 772 57,332 

Georgia 608 4,909 2,771 433 346 28,082 

Kentucky 219 2,257 918 204 154 11,555 

Mississippi 26 219 665 168 117 8,520 

North Carolina 370 3,499 2,487 521 423 22,482 

South Carolina 68 586 930 210 149 11,117 

Tennessee 354 4,054 1,623 292 227 16,318 

Virginia 410 5,385 2,842 844 594 23,032 

West Virginia 7 59 257 72 50 3,607 

Total SESARM 3,105 32,153 18,444 4,066 3,037 196,823 

 

 State Percentage of Regional Total 

SO2 NOx VOC PM10-PRI PM25-PRI CO 

Alabama 1.6 1.4 4.8 7.2 6.8 7.5 

Florida 32.0 33.4 27.4 25.3 25.4 29.1 

Georgia 19.6 15.3 15.0 10.7 11.4 14.3 

Kentucky 7.1 7.0 5.0 5.0 5.1 5.9 

Mississippi 0.8 0.7 3.6 4.1 3.9 4.3 

North Carolina 11.9 10.9 13.5 12.8 13.9 11.4 

South Carolina 2.2 1.8 5.0 5.2 4.9 5.6 

Tennessee 11.4 12.6 8.8 7.2 7.5 8.3 

Virginia 13.2 16.7 15.4 20.8 19.6 11.7 

West Virginia 0.2 0.2 1.4 1.8 1.6 1.8 

Total SESARM 100 100 100 100 100 100 

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Table IV-10. Final 2007 Commercial Marine Vessel Emission Estimates by State 

State Pollutant Emissions, tons per year 

SO2 NOx VOC PM10-PRI PM25-PRI CO NH3

Alabama 1,739 18,554 411 726 699 3,723 8 

Florida 18,146 48,271 1,261 2,971 2,778 7,014 29 

Georgia 2,044 10,582 257 476 456 1,845 5 

Kentucky 1,015 15,726 338 576 558 3,009 11 

Mississippi 1,784 18,119 401 710 683 3,368 10 

North Carolina 1,846 4,233 109 222 209 670 2 

South Carolina 1,289 1,946 109 138 123 220 1 

Tennessee 731 7,565 765 502 469 2,082 4 

Virginia 4,094 21,918 524 966 922 3,755 10 

West Virginia 1,026 15,888 341 582 564 3,040 8 

Total SESARM 33,715 162,801 4,516 7,869 7,462 28,726 86 

 

State Percentage of Regional Total 

SO2 NOx VOC PM10-PRI PM25-PRI CO NH3

Alabama 5.2 11.4 9.1 9.2 9.4 13.0 9.4 

Florida 53.8 29.7 27.9 37.8 37.2 24.4 33.3 

Georgia 6.1 6.5 5.7 6.1 6.1 6.4 5.3 

Kentucky 3.0 9.7 7.5 7.3 7.5 10.5 12.6 

Mississippi 5.3 11.1 8.9 9.0 9.2 11.7 11.3 

North Carolina 5.5 2.6 2.4 2.8 2.8 2.3 2.3 

South Carolina 3.8 1.2 2.4 1.8 1.6 0.8 1.0 

Tennessee 2.2 4.6 16.9 6.4 6.3 7.2 4.6 

Virginia 12.1 13.5 11.6 12.3 12.4 13.1 11.5 

West Virginia 3.0 9.8 7.6 7.4 7.6 10.6 8.8 

Total SESARM 100 100 100 100 100 100 100 

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Table IV-11. Final 2007 Locomotive Emission Estimates by State

State Pollutant Emissions, tons per year 

SO2 NOx VOC PM10-PRI PM25-PRI CO NH3

Alabama 196 17,899 972 598 552 2,542 8 

Florida 175 11,625 592 356 332 1,505 5 

Georgia 252 24,066 1,303 801 739 3,402 11 

Kentucky 173 16,806 888 550 508 2,355 7 

Mississippi 131 9,933 489 304 280 1,295 4 

North Carolina 130 11,592 622 378 350 1,610 5 

South Carolina 99 8,968 479 296 273 1,264 4 

Tennessee 367 19,461 1,083 650 591 2,799 8 

Virginia 444 21,639 1,180 728 678 3,066 9 

West Virginia 212 13,037 677 423 389 1,796 6 

Total SESARM 2,178 155,025 8,285 5,085 4,693 21,633 67 

 

 

State Percentage of Regional Total 

SO2 NOx VOC PM10-PRI PM25-PRI CO NH3

Alabama 9.0 11.5 11.7 11.8 11.8 11.8 11.8 

Florida 8.0 7.5 7.1 7.0 7.1 7.0 6.9 

Georgia 11.6 15.5 15.7 15.7 15.7 15.7 15.8 

Kentucky 8.0 10.8 10.7 10.8 10.8 10.9 10.9 

Mississippi 6.0 6.4 5.9 6.0 6.0 6.0 6.0 

North Carolina 6.0 7.5 7.5 7.4 7.5 7.4 7.5 

South Carolina 4.6 5.8 5.8 5.8 5.8 5.8 5.8 

Tennessee 16.8 12.6 13.1 12.8 12.6 12.9 12.5 

Virginia 20.4 14.0 14.2 14.3 14.4 14.2 14.0 

West Virginia 9.8 8.4 8.2 8.3 8.3 8.3 8.7 

Total SESARM 100 100 100 100 100 100 100 

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V. REFERENCES 

ACE, 2010. U.S. Army Corps of Engineers, Navigation Data Center, U.S. Waterways Data, Principal Port

commodity tonnage for 2005 and 2007, available at http://www.iwr.usace.army.mil/ndc/db/pport/dbf, accessed 

on January 2010. 

Census, 2009a. U.S. Census Bureau, 2006 County Business Patterns, U.S. Department of Commerce, accessed 

from http://www.census.gov/epcd/cbp/index.html, March 2009. 

Census, 2009b: U.S. Census Bureau, 2006 Census of Governments, U.S. Department of Commerce, accessed from 

http://www.census.gov/govs/apes/historical_data_2006.html, April 2009. 

DOE, 2009a. U.S. Department of Energy, Energy Information Administration, “Petroleum Navigator- Total Distillate 

Sales/Deliveries to Railroad Consumers (Thousand Gallons),” 

http://tonto.eia.doe.gov/dnav/pet/pet_cons_821dst_dcu_nus_a.htm, December 2009. 

DOE, 2009b. U.S. Department of Energy, Energy Efficiency and Renewable Energy, “Transportation Energy Data 

Book: Tables A.13 and A.15, http://cta.ornl.gov/data/appendix_a.shtml, 2009. 

EIA, 2008a. Energy Information Administration, “Domestic Distribution of U.S. Coal by Destination State, Consumer, 

Origin and Method of Transportation, 2007,” U.S. Department of Energy, available from 

http://www.eia.doe.gov/cneaf/coal/page/coaldistrib/2007/d_07state.pdf, issued December 2008. 

EIA, 2008b:. Energy Information Administration, “Quarterly Coal Report, October–December 2007,” DOE/EIA-0121 

(2007/04Q), U.S. Department of Energy, available from 

http://tonto.eia.doe.gov/FTPROOT/coal/qcr/0121074q.pdf, issued March 2008. 

EIA, 2008c. Energy Information Administration, “Domestic Distribution of U.S. Coal by Origin State, Consumer, 

Destination and Method of Transportation, 2007,” U.S. Department of Energy, available from 

http://www.eia.doe.gov/cneaf/coal/page/coaldistrib/2007/o_07state.pdf, issued December 2008. 

EIA, 2009a. Energy Information Administration, “State Energy Data System (SEDS): Consumption, Price, and 

Expenditure Estimates,” U.S. Department of Energy, accessed from 

http://www.eia.doe.gov/emeu/states/_seds.html, accessed December 2009. 

EIA, 2009b. Energy Information Administration, “Fuel Oil and Kerosene Sales,” U.S. Department of Energy, 

accessed from 

http://www.eia.doe.gov/pub/oil_gas/petroleum/data_publications/fuel_oil_and_kerosene_sales/historical/2002/

foks_2002.html, accessed December 2009. 

EIA, 2009c. Energy Information Administration, “2006 Energy Consumption by Manufacturers−Data Tables,” 2006 

Manufacturing Energy Consumption Survey, U.S. Department of Energy, accessed from 

http://www.eia.doe.gov/emeu/mecs/mecs2006/2006tables.html, issued June 2009. 

EIA, 2009d. Energy Information Administration, “Annual Energy Outlook 2010 Early Release Overview,” Department 

of Energy, accessed from http://www.eia.doe.gov/oiaf/aeo/index.html, released December 2009. 

EPA, 2003a. U.S. Environmental Protection Agency, “Draft Regulatory Impact Analysis: Control of Emissions from 

Nonroad Diesel Engines,” EPA420-R-03-008, Office of Transportation and Air Quality, April 2003. 

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62 Final Report

EPA, 2003b. U.S. Environmental Protection Agency, AP 42, Compilation of Air Pollutant Emission Factors, Fifth 

Edition, “Volume I, Chapter 1: External Combustion Sources, Section 1.6-Wood Residue in Combustion 

Boilers,” accessed from http://www.epa.gov/ttn/chief/ap42/ch01/final/c01s06.pdf, September 2003. 

EPA, 2008a. U.S. Environmental Protection Agency, “Regulatory Impact Analysis: Control of Emissions of Air 

Pollution from Locomotive Engines and Marine Compression Ignition Engines Less than 30 Liters Per 

Cylinder,” EPA420-R-08-001a, Assessment and Standards Division, Office of Transportation and Air Quality, 

May 2008 

EPA, 2008b. U.S. Environmental Protection Agency, “Regulatory Impact Analysis: Control of Emissions of Air 

Pollution from Category 3 Marine Diesel Engines, Chapter 3 Emission Inventory,” EPA-420-R-09-019, 

Assessment and Standards Division Office of Transportation and Air, December 2008. 

EPA, 2009. U.S. Environmental Protection Agency, “Economic Analysis of Final Effluent Limitation Guidelines and 

Standards for the Construction and Development Industry,” Office of Water, October 21, 2009. 

EPA, 2010. U.S. Environmental Protection Agency, EGAS Version 5.0, available for download from 

http://www.epa.gov/ttnecas1/egas5.htm, accessed March 2010. 

ERG, 2009a. Eastern Research Group, “Documentation for Aircraft Component of the National Emissions Inventory 

Methodology,” prepared under subcontract to E.H. Pechan and Associates, Inc. for U.S. Environmental 

Protection Agency, Emissions, Monitoring and Analysis Division, December 15, 2009. 

ERG, 2009b. Eastern Research Group, “Documentation for Commercial Marine Vessel Component of the National 

Emissions Inventory Methodology,” prepared under subcontract to E.H. Pechan and Associates, Inc. for U.S. 

Environmental Protection Agency, Emissions, Monitoring and Analysis Division, December 15, 2009. 

ERTAC, 2010a. Eastern Regional Technical Advisory Committee, 2007 Class I line haul emissions, transmitted in 

file “EmissionsByCounty_Round6.xls” in email entitled “ERTAC update/Class I emissions,” from M. Bergin, 

ERTAC to K. Thesing, E.H. Pechan & Associates, Inc., March 23, 2010. 

ERTAC, 2010b. Eastern Regional Technical Advisory Committee, 2008 Class II/III line haul Emissions, transmitted 

in file “ClassII_III_v4.xls” in email entitled “Class II/III Spreadsheet with Reporting Marks,” from M. Janssen, 

LADCO to ERTAC distribution list, March 1, 2010. 

ERTAC, 2010c. Eastern Regional Technical Advisory Committee, Railyard Emissions, transmitted in file “ERTAC 

Railyard switcher emissions inventory 6_4_2010.xls” in email from M. Bergin, ERTAC to ERTAC distribution 

list, June 4, 2010. 

FAA, 2010. Federal Aviation Administration, “2007 and 2008 LTO operations by SESARM State,” obtained from Air 

Traffic Activity System, http://aspm.faa.gov/opsnet/sys/Main.asp?force=atads, February 2010. 

Huntley, 2009. Huntley, Roy, U.S. Environmental Protection Agency, “SCCs & emission factors to be used in 2008 

NEI to Bollman May 1 2009.mdb [electronic file],” May 1, 2009. 

Lorenz, 2009. Lorenz, Thomas, Energy Information Administration, personal communication with Jonathan Dorn, 

E.H. Pechan & Associates, Inc., September 29, 2009.

Pechan, 2004. E.H. Pechan & Associates, Inc. “Estimating Ammonia Emissions from Anthropogenic Nonagricultural 

Sources - Draft Final Report,” prepared for the Emission Inventory Improvement Program, April 2004. 

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63 Final Report

Pechan, 2009a. E.H. Pechan and Associates, Inc., “Non-Road and Area Source Base Year and Future Year 

Emissions Inventories Technical Memorandum #1: Base Year Inventory – Summary of 2008 NEI Efforts,” 

prepared for Southeastern States Air Resource Managers, Inc., September 14, 2009. 

Pechan, 2009b. E.H. Pechan and Associates, Inc., “Evaluation of ICI Combustion Coal Sulfur Content, Technical 

Memorandum,” prepared for Central Air Planning Association, March 28, 2009. 

Pechan, 2009c. E.H. Pechan and Associates, Inc., “Instructions To SESARM States For Updating EPA’s National 

Mobile Inventory Model 2007 County-Level Database, Technical Memorandum,” prepared for SESARM, 

September 18, 2009. 

Pechan, 2010. E.H. Pechan and Associates, Inc., “Area & Nonroad Base & Forecast Year Inventories, Final Report,” 

prepared for Southeastern States Air Resource Managers, Inc., June 2010. 

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APPENDIX A. POINT SOURCE SUBTRACTION PROCEDURE DETAILS 

This Appendix describes source category-specific details on the point source subtraction procedures, and displays 

the area SCC to point SCC crosswalk (see Tables A-1 through A-8). 

A. ICI FUEL COMBUSTION 

To assist in the point source subtractions for industrial, commercial, and institutional (ICI) fuel combustion, 

TranSystems developed two crosswalks: one between each industrial fuel combustion area SCC and associated 

point SCCs (Table A-1), and an analogous crosswalk developed for commercial/institutional fuel combustion (Table 

A-2). 

Because natural gas consumed as pipeline fuel is not included by the Energy Information Administration (EIA) in 

EIA’s state energy consumption data for the Industrial sector, it was necessary to exclude pipeline natural gas 

combustion emissions from the point source subtraction procedure. Since there are no SCCs specific to pipeline 

natural gas combustion, point source pipeline natural gas combustion emission estimates were compiled by summing 

emissions for industrial sector natural gas internal combustion engine records (SCC 202002xx) with a pipelinerelated Standard Industrial Classification (SIC) or North American Industrial Classification System (NAICS) code (SIC 

codes 1311, 1321, 1381, 4612, 4613, 4619, 4922, 4923, 4924, 4925, or 4931; NAICS codes 211111, 21112, 22121, 

221210, 486110, 48621, 486210, 486910, 48699, or 486990). 

B. CONSTRUCTION DUST 

Table A-3 displays the point SCCs associated with dust from Construction activities. These SCCs do not provide 

information to separate activity into the two area source category processes: 

• 2311010000 - Construction: SIC 15-17; Residential; Total; and 

• 2311020000 - Construction: SIC 15-18; Industrial/Commercial/Institutional; Total. 

TranSystems apportioned point source construction dust emissions between the two categories using state-level 

acreage data reported in the EPA October 2008 report “Economic Analysis of Final Effluent Limitation Guidelines and 

Standards for the Construction and Development Industry” (EPA, 2009). These proportions for each SESARM state 

are displayed below. 

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Percentage of Construction Acreage by State and Type of Construction 

State Residential % Other % 

Alabama 36 64

Florida 41 59

Georgia 39 61

Kentucky 31 69

Mississippi 24 76

North Carolina 48 52

South Carolina 42 58

Tennessee 35 65

Virginia 45 55

West Virginia 40 60

Source: Table 4-8 from EPA, 2009. 

C. SOLVENT UTILIZATION 

Table A-5 presents the point source crosswalk for each solvent utilization nonpoint SCC. This crosswalk was derived 

from the crosswalk used in performing VOC emissions-based point source subtractions for the 2002 NEI. As noted 

in the Table A-5 crosswalk, two area source solvent utilization SCCs (2401005000-Auto Refinishing and 

2401070000-Motor Vehicles) are associated with the same point SCCs. For the Auto Refinishing area source 

category, point source subtractions for the listed SCCs were limited to records identified with Auto Refinishing 

industry sector SIC/NAICS codes (e.g., NAICS code 8111*). Emissions for all other applicable point SCC S/L 

inventory records were subtracted from total emissions for the Motor Vehicles source category. 

D. GASOLINE DISTRIBUTION 

Table A-6 displays the point SCCs associated with gasoline distribution. Some of these SCCs do not provide 

information to separate activity into each area source stage I gasoline distribution filling technology. Therefore, 

TranSystems allocated the emissions from these point SCCs to each filling technology based on the proportion of 

emissions from TranSystems default inventory. 

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A-3 

Table A-1. Industrial Fuel Combustion Crosswalk for Point Source Subtractions. 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2102001000 - Stationary Source Fuel Combustion; Industrial; Anthracite Coal; Total: All Boiler Types 

10200101 External Combustion Boilers Industrial Anthracite Coal Pulverized Coal10200104 External Combustion Boilers Industrial Anthracite Coal Traveling Grate (Overfeed) Stoker10200107 External Combustion Boilers Industrial Anthracite Coal Hand-fired10200117 External Combustion Boilers Industrial Anthracite Coal Fluidized Bed Boiler Burning Anthracite-Culm F39000189 Industrial Processes In-process Fuel Use Anthracite Coal General39000199 Industrial Processes In-process Fuel Use Anthracite Coal General

2102002000 - Stationary Source Fuel Combustion; Industrial; Bituminous/Subbituminous Coal; Total: All Boiler Types 

10200201 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Pulverized Coal: Wet Bottom10200202 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Pulverized Coal: Dry Bottom10200203 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Cyclone Furnace10200204 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Spreader Stoker10200205 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Overfeed Stoker10200206 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Underfeed Stoker10200210 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Overfeed Stoker **10200212 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Pulverized Coal: Dry Bottom (Tangential)10200213 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Wet Slurry10200217 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Atmospheric Fluidized Bed Combustion: Bubbl

Bed (Bituminous Coal) 

10200218 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Atmospheric Fluidized Bed Combustion: Circula

Bed (Bitum. Coal) 

10200219 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Cogeneration (Bituminous Coal)10200221 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Pulverized Coal: Wet Bottom (Subbituminous C10200222 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Pulverized Coal: Dry Bottom (Subbituminous Co10200223 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Cyclone Furnace (Subbituminous Coal)10200224 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Spreader Stoker (Subbituminous Coal)10200225 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Traveling Grate (Overfeed) Stoker (Subbitumino

Coal) 

10200226 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Pulverized Coal: Dry Bottom Tangential 

(Subbituminous Coal) 

10200229 External Combustion Boilers Industrial Bituminous/Subbituminous Coal Cogeneration (Subbituminous Coal)10500102 External Combustion Boilers Space Heaters Industrial Coal **39000201 Industrial Processes In-process Fuel Use Bituminous Coal Cement Kiln/Dryer (Bituminous Coal)39000203 Industrial Processes In-process Fuel Use Bituminous Coal Lime Kiln (Bituminous)39000288 Industrial Processes In-process Fuel Use Bituminous Coal General (Subbituminous)

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A-4 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

39000289 Industrial Processes In-process Fuel Use Bituminous Coal General (Bituminous)39000299 Industrial Processes In-process Fuel Use Bituminous Coal General (Bituminous)50390002 Waste Disposal Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Coal

2102004000 - Stationary Source Fuel Combustion; Industrial; Distillate Oil; Total: Boilers and IC Engines 

10200501 External Combustion Boilers Industrial Distillate Oil Grades 1 and 2 Oil10200502 External Combustion Boilers Industrial Distillate Oil 10-100 Million Btu/hr **10200503 External Combustion Boilers Industrial Distillate Oil < 10 Million Btu/hr **10200504 External Combustion Boilers Industrial Distillate Oil Grade 4 Oil10200505 External Combustion Boilers Industrial Distillate Oil Cogeneration10201403 External Combustion Boilers Industrial CO Boiler Distillate Oil10500105 External Combustion Boilers Space Heaters Industrial Distillate Oil20200101 Internal Combustion Engines Industrial Distillate Oil (Diesel) Turbine20200102 Internal Combustion Engines Industrial Distillate Oil (Diesel) Reciprocating20200103 Internal Combustion Engines Industrial Distillate Oil (Diesel) Turbine: Cogeneration20200104 Internal Combustion Engines Industrial Distillate Oil (Diesel) Reciprocating: Cogeneration20200105 Internal Combustion Engines Industrial Distillate Oil (Diesel) Reciprocating: Crankcase Blowby20200106 Internal Combustion Engines Industrial Distillate Oil (Diesel) Reciprocating: Evaporative Losses (Fuel Stora

and Delivery System) 

20200107 Internal Combustion Engines Industrial Distillate Oil (Diesel) Reciprocating: Exhaust20200108 Internal Combustion Engines Industrial Distillate Oil (Diesel) Turbine: Evaporative Losses (Fuel Storage an

Delivery System) 

20200109 Internal Combustion Engines Industrial Distillate Oil (Diesel) Turbine: Exhaust20200401 Internal Combustion Engines Industrial Large Bore Engine Diesel20200405 Internal Combustion Engines Industrial Large Bore Engine Crankcase Blowby20200406 Internal Combustion Engines Industrial Large Bore Engine Evaporative Losses (Fuel Storage and Delive

System) 

20200407 Internal Combustion Engines Industrial Large Bore Engine Exhaust27000320 Internal Combustion Engines Off-highway Diesel Engines Industrial Equipment Industrial Fork Lift: Diesel30190001 Industrial Processes Chemical Manufacturing Fuel Fired Equipment Distillate Oil (No. 2): Process Heaters30190011 Industrial Processes Chemical Manufacturing Fuel Fired Equipment Distillate Oil (No. 2): Incinerators30190021 Industrial Processes Chemical Manufacturing Fuel Fired Equipment Distillate Oil (No. 2): Flares30290001 Industrial Processes Food and Agriculture Fuel Fired Equipment Distillate Oil (No. 2): Process Heaters30390001 Industrial Processes Primary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Process Heaters30390011 Industrial Processes Primary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Incinerators30390021 Industrial Processes Primary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Flares30400406 Industrial Processes Secondary Metal Production Lead Pot Furnace Heater: Distillate Oil

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-5 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

30490001 Industrial Processes Secondary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Process Heaters30490011 Industrial Processes Secondary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Incinerators30490021 Industrial Processes Secondary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Flares30490031 Industrial Processes Secondary Metal Production Fuel Fired Equipment Distillate Oil (No. 2): Furnaces30500208 Industrial Processes Mineral Products Asphalt Concrete Asphalt Heater: Distillate Oil30505022 Industrial Processes Mineral Products Asphalt Processing (Blowing) Asphalt Heater: Distillate Oil30590001 Industrial Processes Mineral Products Fuel Fired Equipment Distillate Oil (No. 2): Process Heaters30590011 Industrial Processes Mineral Products Fuel Fired Equipment Distillate Oil (No. 2): Incinerators30590021 Industrial Processes Mineral Products Fuel Fired Equipment Distillate Oil (No. 2): Flares30600901 Industrial Processes Petroleum Industry Flares Distillate Oil30609901 Industrial Processes Petroleum Industry Incinerators Distillate Oil (No. 2)30790001 Industrial Processes Pulp and Paper and Wood 

Products 

Fuel Fired Equipment Distillate Oil (No. 2): Process Heaters

30790011 Industrial Processes Pulp and Paper and Wood 

Products 

Fuel Fired Equipment Distillate Oil (No. 2): Incinerators

30790021 Industrial Processes Pulp and Paper and Wood 

Products 

Fuel Fired Equipment Distillate Oil (No. 2): Flares

30890001 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Distillate Oil (No. 2): Process Heaters

30890011 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Distillate Oil (No. 2): Incinerators

30890021 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Distillate Oil (No. 2): Flares

30990001 Industrial Processes Fabricated Metal Products Fuel Fired Equipment Distillate Oil (No. 2): Process Heaters30990011 Industrial Processes Fabricated Metal Products Fuel Fired Equipment Distillate Oil (No. 2): Incinerators31000401 Industrial Processes Oil and Gas Production Process Heaters Distillate Oil (No. 2)31000411 Industrial Processes Oil and Gas Production Process Heaters Distillate Oil (No. 2): Steam Generators31390001 Industrial Processes Electrical Equipment Process Heaters Distillate Oil (No. 2)39000501 Industrial Processes In-process Fuel Use Distillate Oil Asphalt Dryer **39000502 Industrial Processes In-process Fuel Use Distillate Oil Cement Kiln/Dryer39000503 Industrial Processes In-process Fuel Use Distillate Oil Lime Kiln39000589 Industrial Processes In-process Fuel Use Distillate Oil General39000598 Industrial Processes In-process Fuel Use Distillate Oil Grade 4 Oil: General39000599 Industrial Processes In-process Fuel Use Distillate Oil General39900501 Industrial Processes Miscellaneous Manufacturing 

Industries 

Process Heater/Furnace Distillate Oil

39990001 Industrial Processes Miscellaneous Manufacturing 

Industries 

Miscellaneous Manufacturing 

Industries 

Distillate Oil (No. 2): Process Heaters

39990011 Industrial Processes Miscellaneous Manufacturing 

Industries 

Miscellaneous Manufacturing 

Industries 

Distillate Oil (No. 2): Incinerators

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-6 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

39990021 Industrial Processes Miscellaneous Manufacturing 

Industries 

Miscellaneous Manufacturing 

Industries 

Distillate Oil (No. 2 Oil): Flares

40201002 Petroleum and Solvent Evaporation Surface Coating Operations Coating Oven Heater Distillate Oil40290011 Petroleum and Solvent Evaporation Surface Coating Operations Fuel Fired Equipment Distillate Oil: Incinerator/Afterburner49090011 Petroleum and Solvent Evaporation Organic Solvent Evaporation Fuel Fired Equipment Distillate Oil (No. 2): Incinerators49090021 Petroleum and Solvent Evaporation Organic Solvent Evaporation Fuel Fired Equipment Distillate Oil (No. 2): Flares50390005 Waste Disposal Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Distillate Oil

2102005000 - Stationary Source Fuel Combustion; Industrial; Residual Oil; Total: All Boiler Types 

10200401 External Combustion Boilers Industrial Residual Oil Grade 6 Oil10200402 External Combustion Boilers Industrial Residual Oil 10-100 Million Btu/hr **10200403 External Combustion Boilers Industrial Residual Oil < 10 Million Btu/hr **10200404 External Combustion Boilers Industrial Residual Oil Grade 5 Oil10200405 External Combustion Boilers Industrial Residual Oil Cogeneration10201404 External Combustion Boilers Industrial CO Boiler Residual Oil20200501 Internal Combustion Engines Industrial Residual/Crude Oil Reciprocating20200505 Internal Combustion Engines Industrial Residual/Crude Oil Reciprocating: Crankcase Blowby20200506 Internal Combustion Engines Industrial Residual/Crude Oil Reciprocating: Evaporative Losses (Fuel Stora

and Delivery System) 

20200507 Internal Combustion Engines Industrial Residual/Crude Oil Reciprocating: Exhaust30190002 Industrial Processes Chemical Manufacturing Fuel Fired Equipment Residual Oil: Process Heaters30190012 Industrial Processes Chemical Manufacturing Fuel Fired Equipment Residual Oil: Incinerators30190022 Industrial Processes Chemical Manufacturing Fuel Fired Equipment Residual Oil: Flares30290002 Industrial Processes Food and Agriculture Fuel Fired Equipment Residual Oil: Process Heaters30390002 Industrial Processes Primary Metal Production Fuel Fired Equipment Residual Oil: Process Heaters30390012 Industrial Processes Primary Metal Production Fuel Fired Equipment Residual Oil: Incinerators30390022 Industrial Processes Primary Metal Production Fuel Fired Equipment Residual Oil: Flares30490002 Industrial Processes Secondary Metal Production Fuel Fired Equipment Residual Oil: Process Heaters30490012 Industrial Processes Secondary Metal Production Fuel Fired Equipment Residual Oil: Incinerators30490022 Industrial Processes Secondary Metal Production Fuel Fired Equipment Residual Oil: Flares30490032 Industrial Processes Secondary Metal Production Fuel Fired Equipment Residual Oil: Furnaces30500207 Industrial Processes Mineral Products Asphalt Concrete Asphalt Heater: Residual Oil30505021 Industrial Processes Mineral Products Asphalt Processing (Blowing) Asphalt Heater: Residual Oil30590002 Industrial Processes Mineral Products Fuel Fired Equipment Residual Oil: Process Heaters30590012 Industrial Processes Mineral Products Fuel Fired Equipment Residual Oil: Incinerators30600111 Industrial Processes Petroleum Industry Process Heaters Oil-fired (No. 6 Oil) > 100 Million Btu Capacity30600902 Industrial Processes Petroleum Industry Flares Residual Oil

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-7 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

30609902 Industrial Processes Petroleum Industry Incinerators Residual Oil30790002 Industrial Processes Pulp and Paper and Wood 

Products 

Fuel Fired Equipment Residual Oil: Process Heaters

30790012 Industrial Processes Pulp and Paper and Wood 

Products 

Fuel Fired Equipment Residual Oil: Incinerators

30790022 Industrial Processes Pulp and Paper and Wood 

Products 

Fuel Fired Equipment Residual Oil: Flares

30890002 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Residual Oil: Process Heaters

30890012 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Residual Oil: Incinerators

30890022 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Residual Oil: Flares

30990002 Industrial Processes Fabricated Metal Products Fuel Fired Equipment Residual Oil: Process Heaters30990012 Industrial Processes Fabricated Metal Products Fuel Fired Equipment Residual Oil: Incinerators31000402 Industrial Processes Oil and Gas Production Process Heaters Residual Oil31000412 Industrial Processes Oil and Gas Production Process Heaters Residual Oil: Steam Generators31390002 Industrial Processes Electrical Equipment Process Heaters Residual Oil39000402 Industrial Processes In-process Fuel Use Residual Oil Cement Kiln/Dryer39000403 Industrial Processes In-process Fuel Use Residual Oil Lime Kiln39000489 Industrial Processes In-process Fuel Use Residual Oil General39000499 Industrial Processes In-process Fuel Use Residual Oil General39990002 Industrial Processes Miscellaneous Manufacturing 

Industries 

Miscellaneous Manufacturing 

Industries 

Residual Oil: Process Heaters

39990012 Industrial Processes Miscellaneous Manufacturing 

Industries 

Miscellaneous Manufacturing 

Industries 

Residual Oil: Incinerators

39990022 Industrial Processes Miscellaneous Manufacturing 

Industries 

Miscellaneous Manufacturing 

Industries 

Residual Oil: Flares

40201003 Petroleum and Solvent Evaporation Surface Coating Operations Coating Oven Heater Residual Oil40290012 Petroleum and Solvent Evaporation Surface Coating Operations Fuel Fired Equipment Residual Oil: Incinerator/Afterburner49090012 Petroleum and Solvent Evaporation Organic Solvent Evaporation Fuel Fired Equipment Residual Oil: Incinerators49090022 Petroleum and Solvent Evaporation Organic Solvent Evaporation Fuel Fired Equipment Residual Oil: Flares

2102006000 - Stationary Source Fuel Combustion; Industrial; Natural Gas; Total: Boilers and IC Engines

10200601 External Combustion Boilers Industrial Natural Gas > 100 Million Btu/hr10200602 External Combustion Boilers Industrial Natural Gas 10-100 Million Btu/hr10200603 External Combustion Boilers Industrial Natural Gas < 10 Million Btu/hr10200604 External Combustion Boilers Industrial Natural Gas Cogeneration10201401 External Combustion Boilers Industrial CO Boiler Natural Gas10500106 External Combustion Boilers Space Heaters Industrial Natural Gas

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-8 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

20200201 Internal Combustion Engines Industrial Natural Gas Turbine 20200202 Internal Combustion Engines Industrial Natural Gas Reciprocating 20200203 Internal Combustion Engines Industrial Natural Gas Turbine: Cogeneration 20200204 Internal Combustion Engines Industrial Natural Gas Reciprocating: Cogeneration 20200205 Internal Combustion Engines Industrial Natural Gas Reciprocating: Crankcase Blowby 20200206 Internal Combustion Engines Industrial Natural Gas Reciprocating: Evaporative Losses (Fuel Delive

System) 

20200207 Internal Combustion Engines Industrial Natural Gas Reciprocating: Exhaust 20200208 Internal Combustion Engines Industrial Natural Gas Turbine: Evaporative Losses (Fuel Delivery 

System) 

20200209 Internal Combustion Engines Industrial Natural Gas Turbine: Exhaust 20200251 Internal Combustion Engines Industrial Natural Gas 2-cycle Rich Burn 20200252 Internal Combustion Engines Industrial Natural Gas 2-cycle Lean Burn 20200253 Internal Combustion Engines Industrial Natural Gas 4-cycle Rich Burn 20200254 Internal Combustion Engines Industrial Natural Gas 4-cycle Lean Burn 20200255 Internal Combustion Engines Industrial Natural Gas 2-cycle Clean Burn 20200256 Internal Combustion Engines Industrial Natural Gas 4-cycle Clean Burn 30190003 Industrial Processes Chemical Manufacturing Fuel Fired Equipment Natural Gas: Process Heaters30190013 Industrial Processes Chemical Manufacturing Fuel Fired Equipment Natural Gas: Incinerators30190023 Industrial Processes Chemical Manufacturing Fuel Fired Equipment Natural Gas: Flares30290003 Industrial Processes Food and Agriculture Fuel Fired Equipment Natural Gas: Process Heaters30291001 Industrial Processes Food and Agriculture Fuel Fired Equipment Broiling Food: Natural Gas30390003 Industrial Processes Primary Metal Production Fuel Fired Equipment Natural Gas: Process Heaters30390013 Industrial Processes Primary Metal Production Fuel Fired Equipment Natural Gas: Incinerators30390023 Industrial Processes Primary Metal Production Fuel Fired Equipment Natural Gas: Flares30400407 Industrial Processes Secondary Metal Production Lead Pot Furnace Heater: Natural Gas30490003 Industrial Processes Secondary Metal Production Fuel Fired Equipment Natural Gas: Process Heaters30490013 Industrial Processes Secondary Metal Production Fuel Fired Equipment Natural Gas: Incinerators30490023 Industrial Processes Secondary Metal Production Fuel Fired Equipment Natural Gas: Flares30490033 Industrial Processes Secondary Metal Production Fuel Fired Equipment Natural Gas: Furnaces

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-9 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

30500206 Industrial Processes Mineral Products Asphalt Concrete Asphalt Heater: Natural Gas30505020 Industrial Processes Mineral Products Asphalt Processing (Blowing) Asphalt Heater: Natural Gas30590003 Industrial Processes Mineral Products Fuel Fired Equipment Natural Gas: Process Heaters30590013 Industrial Processes Mineral Products Fuel Fired Equipment Natural Gas: Incinerators30590023 Industrial Processes Mineral Products Fuel Fired Equipment Natural Gas: Flares30600105 Industrial Processes Petroleum Industry Process Heaters Natural Gas30600903 Industrial Processes Petroleum Industry Flares Natural Gas30602401 Industrial Processes Petroleum Industry Reciprocating Engine Compressors Natural Gas Fired30609903 Industrial Processes Petroleum Industry Incinerators Natural Gas30790003 Industrial Processes Pulp and Paper and Wood 

Products 

Fuel Fired Equipment Natural Gas: Process Heaters

30790013 Industrial Processes Pulp and Paper and Wood 

Products 

Fuel Fired Equipment Natural Gas: Incinerators

30790023 Industrial Processes Pulp and Paper and Wood 

Products 

Fuel Fired Equipment Natural Gas: Flares

30890003 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Natural Gas: Process Heaters

30890013 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Natural Gas: Incinerators

30890023 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Natural Gas: Flares

30990003 Industrial Processes Fabricated Metal Products Fuel Fired Equipment Natural Gas: Process Heaters30990013 Industrial Processes Fabricated Metal Products Fuel Fired Equipment Natural Gas: Incinerators30990023 Industrial Processes Fabricated Metal Products Fuel Fired Equipment Natural Gas: Flares31000404 Industrial Processes Oil and Gas Production Process Heaters Natural Gas31000414 Industrial Processes Oil and Gas Production Process Heaters Natural Gas: Steam Generators31390003 Industrial Processes Electrical Equipment Process Heaters Natural Gas39000602 Industrial Processes In-process Fuel Use Natural Gas Cement Kiln/Dryer39000603 Industrial Processes In-process Fuel Use Natural Gas Lime Kiln39000605 Industrial Processes In-process Fuel Use Natural Gas Metal Melting **39000689 Industrial Processes In-process Fuel Use Natural Gas General39000699 Industrial Processes In-process Fuel Use Natural Gas General39900601 Industrial Processes Miscellaneous Manufacturing 

Industries 

Process Heater/Furnace Natural Gas

39990003 Industrial Processes Miscellaneous Manufacturing 

Industries 

Miscellaneous Manufacturing 

Industries 

Natural Gas: Process Heaters

39990013 Industrial Processes Miscellaneous Manufacturing 

Industries 

Miscellaneous Manufacturing 

Industries 

Natural Gas: Incinerators

39990023 Industrial Processes Miscellaneous Manufacturing 

Industries 

Miscellaneous Manufacturing 

Industries 

Natural Gas: Flares

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-10 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40201001 Petroleum and Solvent Evaporation Surface Coating Operations Coating Oven Heater Natural Gas40290013 Petroleum and Solvent Evaporation Surface Coating Operations Fuel Fired Equipment Natural Gas: Incinerator/Afterburner40290023 Petroleum and Solvent Evaporation Surface Coating Operations Fuel Fired Equipment Natural Gas: Flares49090013 Petroleum and Solvent Evaporation Organic Solvent Evaporation Fuel Fired Equipment Natural Gas: Incinerators49090023 Petroleum and Solvent Evaporation Organic Solvent Evaporation Fuel Fired Equipment Natural Gas: Flares50390006 Waste Disposal Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Natural Gas

2102007000 - Stationary Source Fuel Combustion; Industrial; Liquified Petroleum Gas (LPG); Total: All Boiler Types 

10201001 External Combustion Boilers Industrial Liquified Petroleum Gas (LPG) Butane10201002 External Combustion Boilers Industrial Liquified Petroleum Gas (LPG) Propane10201003 External Combustion Boilers Industrial Liquified Petroleum Gas (LPG) Butane/Propane Mixture: Specify Percent Butan

Comments 

10500110 External Combustion Boilers Space Heaters Industrial Liquified Petroleum Gas (LPG)20201001 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Propane: Reciprocating20201002 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Butane: Reciprocating20201005 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Reciprocating: Crankcase Blowby20201006 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Reciprocating: Evaporative Losses (Fuel Stora

and Delivery System) 

20201007 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Reciprocating: Exhaust20201008 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Turbine: Evaporative Losses (Fuel Storage an

Delivery System) 

20201009 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Turbine: Exhaust20201011 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Turbine20201012 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Reciprocating Engine20201013 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Turbine: Cogeneration20201014 Internal Combustion Engines Industrial Liquified Petroleum Gas (LPG) Reciprocating Engine: Cogeneration27300320 Internal Combustion Engines Off-highway LPG-fueled Engines Industrial Equipment Industrial Fork Lift: Liquified Petroleum Gas (LP30290005 Industrial Processes Food and Agriculture Fuel Fired Equipment Liquified Petroleum Gas (LPG): Process Heate30490035 Industrial Processes Secondary Metal Production Fuel Fired Equipment Propane: Furnaces30500209 Industrial Processes Mineral Products Asphalt Concrete Asphalt Heater: LPG30505023 Industrial Processes Mineral Products Asphalt Processing (Blowing) Asphalt Heater: LP Gas30590005 Industrial Processes Mineral Products Fuel Fired Equipment Liquified Petroleum Gas (LPG): Process Heate30600107 Industrial Processes Petroleum Industry Process Heaters LPG-fired30600905 Industrial Processes Petroleum Industry Flares Liquified Petroleum Gas30609905 Industrial Processes Petroleum Industry Incinerators Liquified Petroleum Gas30890004 Industrial Processes Rubber and Miscellaneous 

Plastics Products 

Fuel Fired Equipment Liquified Petroleum Gas (LPG): Process Heate

31000406 Industrial Processes Oil and Gas Production Process Heaters Propane/Butane

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-11 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

39001089 Industrial Processes In-process Fuel Use Liquified Petroleum Gas General39001099 Industrial Processes In-process Fuel Use Liquified Petroleum Gas General39901001 Industrial Processes Miscellaneous Manufacturing 

Industries 

Process Heater/Furnace LPG

40201004 Petroleum and Solvent Evaporation Surface Coating Operations Coating Oven Heater Liquified Petroleum Gas (LPG)50390010 Waste Disposal Solid Waste Disposal - Industrial Auxiliary Fuel/No Emissions Liquified Petroleum Gas (LPG)

2102008000 - Stationary Source Fuel Combustion; Industrial; Wood; Total: All Boiler Types 

10200901 External Combustion Boilers Industrial Wood/Bark Waste Bark-fired Boiler10200902 External Combustion Boilers Industrial Wood/Bark Waste Wood/Bark-fired Boiler10200903 External Combustion Boilers Industrial Wood/Bark Waste Wood-fired Boiler - Wet Wood (>=20% moistu10200904 External Combustion Boilers Industrial Wood/Bark Waste Bark-fired Boiler (< 50,000 Lb Steam) **10200905 External Combustion Boilers Industrial Wood/Bark Waste Wood/Bark-fired Boiler (< 50,000 Lb Steam) *10200906 External Combustion Boilers Industrial Wood/Bark Waste Wood-fired Boiler (< 50,000 Lb Steam) **10200907 External Combustion Boilers Industrial Wood/Bark Waste Wood Cogeneration10200908 External Combustion Boilers Industrial Wood/Bark Waste Wood-fired Boiler - Dry Wood (<20% moisture10200910 External Combustion Boilers Industrial Wood/Bark Waste Fuel cell/Dutch oven boilers **10200911 External Combustion Boilers Industrial Wood/Bark Waste Stoker boilers **10200912 External Combustion Boilers Industrial Wood/Bark Waste Fluidized bed combustion boiler39000989 Industrial Processes In-process Fuel Use Wood General39000999 Industrial Processes In-process Fuel Use Wood General: Wood

2102011000 - Stationary Source Fuel Combustion; Industrial; Kerosene; Total: All Boiler Types 

20200901 Internal Combustion Engines Industrial Kerosene/Naphtha (Jet Fuel) Turbine20200902 Internal Combustion Engines Industrial Kerosene/Naphtha (Jet Fuel) Reciprocating20200905 Internal Combustion Engines Industrial Kerosene/Naphtha (Jet Fuel) Reciprocating: Crankcase Blowby20200906 Internal Combustion Engines Industrial Kerosene/Naphtha (Jet Fuel) Reciprocating: Evaporative Losses (Fuel Stora

and Delivery System) 

20200907 Internal Combustion Engines Industrial Kerosene/Naphtha (Jet Fuel) Reciprocating: Exhaust20200908 Internal Combustion Engines Industrial Kerosene/Naphtha (Jet Fuel) Turbine: Evaporative Losses (Fuel Storage an

Delivery System) 

20200909 Internal Combustion Engines Industrial Kerosene/Naphtha (Jet Fuel) Turbine: Exhaust

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-12 

Table A-2. Commercial/Institutional Fuel Combustion Crosswalk for Point Source Subtractions 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2103001000 - Stationary Source Fuel Combustion; Commercial/Institutional; Anthracite Coal; Total: All Boiler Types 

10300101 External Combustion Boilers Commercial/Institutional Anthracite Coal Pulverized Coal10300102 External Combustion Boilers Commercial/Institutional Anthracite Coal Traveling Grate (Overfeed) Stoker10300103 External Combustion Boilers Commercial/Institutional Anthracite Coal Hand-fired

2103002000 - Stationary Source Fuel Combustion; Commercial/Institutional; Bituminous/Subbituminous Coal; Total: All Boiler Types 

10300203 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Cyclone Furnace (Bituminous Coal10300205 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Pulverized Coal: Wet Bottom (Bituminous 10300206 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Pulverized Coal: Dry Bottom (Bituminous 10300207 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Overfeed Stoker (Bituminous Coal)10300208 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Underfeed Stoker (Bituminous Coa10300209 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Spreader Stoker (Bituminous Coal)10300211 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Overfeed Stoker **10300214 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Hand-fired (Bituminous Coal)10300216 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Pulverized Coal: Dry Bottom (Tangential) (Bitum10300217 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Atmospheric Fluidized Bed Combustion: Bubbling B

Coal) 

10300218 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Atmospheric Fluidized Bed Combustion: Circulati

Coal) 

10300221 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Pulverized Coal: Wet Bottom (Subbitumino10300222 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Pulverized Coal: Dry Bottom (Subbitumino10300223 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Cyclone Furnace (Subbituminous Co10300224 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Spreader Stoker (Subbituminous Coa10300225 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Traveling Grate (Overfeed) Stoker (Subbitumi10300226 External Combustion Boilers Commercial/Institutional Bituminous/Subbituminous Coal Pulverized Coal: Dry Bottom Tangential (Subbitu10500202 External Combustion Boilers Space Heaters Commercial/Institutional Coal **50190002 Waste Disposal Solid Waste Disposal - Government Auxiliary Fuel/No Emissions Coal50290002 Waste Disposal Solid Waste Disposal - Commercial/Institutional Auxiliary Fuel/No Emissions Coal

2103004000 - Stationary Source Fuel Combustion; Commercial/Institutional; Distillate Oil; Total: Boilers and IC Engines 

10300501 External Combustion Boilers Commercial/Institutional Distillate Oil Grades 1 and 2 Oil10300502 External Combustion Boilers Commercial/Institutional Distillate Oil 10-100 Million Btu/hr **10300503 External Combustion Boilers Commercial/Institutional Distillate Oil < 10 Million Btu/hr **10300504 External Combustion Boilers Commercial/Institutional Distillate Oil Grade 4 Oil

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-13 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

10500205 External Combustion Boilers Space Heaters Commercial/Institutional Distillate Oil20300101 Internal Combustion Engines Commercial/Institutional Distillate Oil (Diesel) Reciprocating20300102 Internal Combustion Engines Commercial/Institutional Distillate Oil (Diesel) Turbine20300105 Internal Combustion Engines Commercial/Institutional Distillate Oil (Diesel) Reciprocating: Crankcase Blowby20300106 Internal Combustion Engines Commercial/Institutional Distillate Oil (Diesel) Reciprocating: Evaporative Losses (Fuel Storage 

System) 

20300107 Internal Combustion Engines Commercial/Institutional Distillate Oil (Diesel) Reciprocating: Exhaust20300108 Internal Combustion Engines Commercial/Institutional Distillate Oil (Diesel) Turbine: Evaporative Losses (Fuel Storage and D20300109 Internal Combustion Engines Commercial/Institutional Distillate Oil (Diesel) Turbine: Exhaust50100602 Waste Disposal Solid Waste Disposal - Government Fire Fighting Structure: Distillate Oil50190005 Waste Disposal Solid Waste Disposal - Government Auxiliary Fuel/No Emissions Distillate Oil50290005 Waste Disposal Solid Waste Disposal - Commercial/Institutional Auxiliary Fuel/No Emissions Distillate Oil

2103005000 - Stationary Source Fuel Combustion; Commercial/Institutional; Residual Oil; Total: All Boiler Types 

10300401 External Combustion Boilers Commercial/Institutional Residual Oil Grade 6 Oil10300402 External Combustion Boilers Commercial/Institutional Residual Oil 10-100 Million Btu/hr **10300403 External Combustion Boilers Commercial/Institutional Residual Oil < 10 Million Btu/hr **10300404 External Combustion Boilers Commercial/Institutional Residual Oil Grade 5 Oil

2103006000 - Stationary Source Fuel Combustion; Commercial/Institutional; Natural Gas; Total: Boilers and IC Engines

10300601 External Combustion Boilers Commercial/Institutional Natural Gas > 100 Million Btu/hr10300602 External Combustion Boilers Commercial/Institutional Natural Gas 10-100 Million Btu/hr10300603 External Combustion Boilers Commercial/Institutional Natural Gas < 10 Million Btu/hr10500206 External Combustion Boilers Space Heaters Commercial/Institutional Natural Gas20300201 Internal Combustion Engines Commercial/Institutional Natural Gas Reciprocating20300202 Internal Combustion Engines Commercial/Institutional Natural Gas Turbine20300203 Internal Combustion Engines Commercial/Institutional Natural Gas Turbine: Cogeneration20300204 Internal Combustion Engines Commercial/Institutional Natural Gas Cogeneration20300205 Internal Combustion Engines Commercial/Institutional Natural Gas Reciprocating: Crankcase Blowby20300206 Internal Combustion Engines Commercial/Institutional Natural Gas Reciprocating: Evaporative Losses (Fuel Deliv20300207 Internal Combustion Engines Commercial/Institutional Natural Gas Reciprocating: Exhaust20300208 Internal Combustion Engines Commercial/Institutional Natural Gas Turbine: Evaporative Losses (Fuel Delivery 20300209 Internal Combustion Engines Commercial/Institutional Natural Gas Turbine: Exhaust50190006 Waste Disposal Solid Waste Disposal - Government Auxiliary Fuel/No Emissions Natural Gas

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-14 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

50290006 Waste Disposal Solid Waste Disposal - Commercial/Institutional Auxiliary Fuel/No Emissions Natural Gas

2103007000 - Stationary Source Fuel Combustion; Commercial/Institutional; Liquified Petroleum Gas (LPG); Total: All Combustor Types 

10301001 External Combustion Boilers Commercial/Institutional Liquified Petroleum Gas (LPG) Butane10301002 External Combustion Boilers Commercial/Institutional Liquified Petroleum Gas (LPG) Propane10301003 External Combustion Boilers Commercial/Institutional Liquified Petroleum Gas (LPG) Butane/Propane Mixture: Specify Percent Butane 10500210 External Combustion Boilers Space Heaters Commercial/Institutional Liquified Petroleum Gas (LPG)20301001 Internal Combustion Engines Commercial/Institutional Liquified Petroleum Gas (LPG) Propane: Reciprocating20301002 Internal Combustion Engines Commercial/Institutional Liquified Petroleum Gas (LPG) Butane: Reciprocating20301005 Internal Combustion Engines Commercial/Institutional Liquified Petroleum Gas (LPG) Reciprocating: Crankcase Blowby20301006 Internal Combustion Engines Commercial/Institutional Liquified Petroleum Gas (LPG) Reciprocating: Evaporative Losses (Fuel Storage 

System) 

20301007 Internal Combustion Engines Commercial/Institutional Liquified Petroleum Gas (LPG) Reciprocating: Exhaust50190010 Waste Disposal Solid Waste Disposal - Government Auxiliary Fuel/No Emissions Liquified Petroleum Gas (LPG)50290010 Waste Disposal Solid Waste Disposal - Commercial/Institutional Auxiliary Fuel/No Emissions Liquified Petroleum Gas (LPG)

2103008000 - Stationary Source Fuel Combustion; Commercial/Institutional; Wood; Total: All Boiler Types 

10300901 External Combustion Boilers Commercial/Institutional Wood/Bark Waste Bark-fired Boiler10300902 External Combustion Boilers Commercial/Institutional Wood/Bark Waste Wood/Bark-fired Boiler10300903 External Combustion Boilers Commercial/Institutional Wood/Bark Waste Wood-fired Boiler - Wet Wood (>=20% mo10300908 External Combustion Boilers Commercial/Institutional Wood/Bark Waste Wood-fired Boiler - Dry Wood (<20% mo10300910 External Combustion Boilers Commercial/Institutional Wood/Bark Waste Fuel cell/Dutch oven boilers **10300911 External Combustion Boilers Commercial/Institutional Wood/Bark Waste Stoker boilers **10300912 External Combustion Boilers Commercial/Institutional Wood/Bark Waste Fluidized bed combustion boilers10500209 External Combustion Boilers Space Heaters Commercial/Institutional Wood

2103011000 - Stationary Source Fuel Combustion; Commercial/Institutional; Kerosene; Total: All Combustor Types 

20300901 Internal Combustion Engines Commercial/Institutional Kerosene/Naphtha (Jet Fuel) Turbine: JP-420300908 Internal Combustion Engines Commercial/Institutional Kerosene/Naphtha (Jet Fuel) Turbine: Evaporative Losses (Fuel Storage and D20300909 Internal Combustion Engines Commercial/Institutional Kerosene/Naphtha (Jet Fuel) Turbine: Exhaust50100603 Waste Disposal Solid Waste Disposal - Government Fire Fighting Structure: Kerosene

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-15 

Table A-3. Construction Crosswalk for Point Source Subtractions 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2311010000 - Industrial Processes; Construction: SIC 15 – 17; Residential; Total

and 

2311020000 - Industrial Processes; Construction: SIC 15 – 18; Industrial/Commercial/Institutional; Total 

31100101 Industrial Processes Building Construction Construction: Building Contractors Site Preparation: Topsoil Removal S

2

31100102 Industrial Processes Building Construction Construction: Building Contractors Site Preparation: Earth Moving (Cut and Fill) S

2

31100103 Industrial Processes Building Construction Construction: Building Contractors Site Preparation: Aggregate Hauling (On Dirt) S

2

31100199 Industrial Processes Building Construction Construction: Building Contractors Other Not Classified S

2

31100201 Industrial Processes Building Construction Demolitions/Special Trade 

Contracts 

Mechanical or Explosive Dismemberment S

2

31100202 Industrial Processes Building Construction Demolitions/Special Trade 

Contracts 

Mechanical or Explosive Dismemberment S

2

31100205 Industrial Processes Building Construction Demolitions/Special Trade 

Contracts 

On-site Truck Traffic S

2

31100206 Industrial Processes Building Construction Demolitions/Special Trade 

Contracts 

On-site Truck Traffic S

2

31100299 Industrial Processes Building Construction Demolitions/Special Trade 

Contracts 

Other Not Classified: Construction/Demolition S

2

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-16 

Table A-4. Publicly Owned Treatment Works Crosswalk for Point Source Subtractions 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2630020000 - Waste Disposal, Treatment, and Recovery; Wastewater Treatment; Public Owned; Total Processed 

50100701 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Entire Plant50100702 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Primary Settling Tank50100703 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Secondary Settling Tank50100704 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Aeration Tank50100707 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Headworks Screening50100708 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Comminutor50100710 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Collector Sewers50100715 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Aerated Grit Chamber50100719 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Lift Station50100720 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Primary Settling Tank50100731 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Diffused Air Act Sludge50100732 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Mechanical Mix Air Act Sludge50100733 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Pure Oxygen Act Sludge50100734 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Trickling Filter50100740 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Secondary Clarifier50100750 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Tertiary Filters50100760 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Chlorine Contact Tank50100761 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Dechlorination50100765 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Weir50100769 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Storage Basin or Open Tank50100771 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Gravity Sludge Thickener50100772 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: DAF Sludge Thickener50100781 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Anaerobic Digester50100791 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Belt Filter Press50100792 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Sludge Centrifuge50100793 Waste Disposal Solid Waste Disposal - Government Sewage Treatment POTW: Sludge Drying Bed50100795 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Sludge Storage Lagoons/Drying Beds50100799 Waste Disposal Solid Waste Disposal - Government Sewage Treatment Other Not Classified

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-17 

Table A-5. Solvent Utilization Crosswalk for Point Source Subtractions 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2401005000 - Solvent Utilization; Surface Coating; Auto Refinishing: SIC 7532; Total: All Solvent Types 

40201601 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Application/Electo-deposition/Dip/Spray 

40201602 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Cleaning/Pretreatment 

40201603 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Coating Mixing 

40201604 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Coating Storage 

40201605 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Equipment Cleanup 

40201606 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat Operation 

40201607 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Sealers 

40201608 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Deadeners 

40201609 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Anti-corrosion Priming 

40201619 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Surfacing Operation 

40201620 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Repair Topcoat Application Area 

40201621 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Coating: Solvent-borne - Automobiles 

40201622 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Coating: Electro-deposition - Automobiles 

40201623 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Guide Coating: Solvent-borne - Automobiles 

40201624 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Guide Coating: Water-borne - Automobiles 

40201625 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat: Solvent-borne - Automobiles 

40201626 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat: Water-borne - Automobiles 

40201627 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Coating: Solvent-borne - Light Trucks 

40201628 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Coating: Electro-deposition - Light Trucks 

40201629 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Guide Coating: Solvent-borne - Light Trucks 

40201630 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Guide Coating: Water-borne - Light Trucks 

40201631 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat: Solvent-borne - Light Trucks 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-18 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40201632 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat: Water-borne - Light Trucks 

40201699 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Other Not Classified 

2401015000 - Solvent Utilization; Surface Coating; Factory Finished Wood: SIC 2426 thru 242; Total: All Solvent Types 

40202101 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Base Coat

40202103 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Coating Mixing

40202104 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Coating Storage

40202105 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Equipment Cleanup

40202106 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Topcoat

40202107 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Filler

40202108 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Sealer

40202109 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Inks

40202110 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Grove Coat Application

40202111 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Stain Application

40202117 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Filler Sander

40202118 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Sealer Sander

40202131 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Water-borne Coating

40202132 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Solvent-borne Coating

40202133 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Ultraviolet Coating

40202140 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Surface Preparation (Includes Tempering, Sanding

Brushing, Grove Cut) 

40202199 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Flatwood Products Other Not Classified

2401020000 - Solvent Utilization; Surface Coating; Wood Furniture: SIC 25; Total: All Solvent Types 

40201901 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Wood Furniture Surface Coating Coating Operation

40201903 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Wood Furniture Surface Coating Coating Mixing

40201904 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Wood Furniture Surface Coating Coating Storage

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-19 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40201999 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Wood Furniture Surface Coating Other Not Classified

2401025000 - Solvent Utilization; Surface Coating; Metal Furniture: SIC 25; Total: All Solvent Types 

40202001 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Coating Operation

40202002 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Cleaning/Pretreatment

40202003 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Coating Mixing

40202004 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Coating Storage

40202005 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Equipment Cleanup

40202010 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Prime Coat Application

40202011 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Prime Coat Application: Spray, High Solids

40202012 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Prime Coat Application: Spray, Water-borne

40202013 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Prime Coat Application: Dip

40202014 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Prime Coat Application: Flow Coat

40202015 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Prime Coat Application: Flashoff

40202020 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Topcoat Application

40202021 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Topcoat Application: Spray, High Solids

40202022 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Topcoat Application: Spray, Water-borne

40202023 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Topcoat Application: Dip

40202024 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Topcoat Application: Flow Coat

40202025 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Topcoat Application: Flashoff

40202031 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Single Spray Line: General

40202032 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Spray Dip Line: General ** (Use 4-02-020-37)

40202033 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Spray High Solids Coating ** (Use 4-02-020-35)

40202034 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Spray Water-borne Coating ** (Use 4-02-020-36)

40202035 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Single Coat Application: Spray, High Solids

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-20 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40202036 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Single Coat Application: Spray, Water-borne

40202037 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Single Coat Application: Dip

40202038 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Single Coat Application: Flow Coat

40202039 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Single Coat Application: Flashoff

40202099 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Furniture Operations Other Not Classified

2401030000 - Solvent Utilization; Surface Coating; Paper: SIC 26; Total: All Solvent Types 

40201301 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Paper Coating Coating Operation

40201303 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Paper Coating Coating Mixing

40201304 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Paper Coating Coating Storage

40201305 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Paper Coating Equipment Cleanup

40201310 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Paper Coating Coating Application: Knife Coater

40201320 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Paper Coating Coating Application: Reverse Roll Coater

40201330 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Paper Coating Coating Application: Rotogravure Printer

40201399 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Paper Coating Other Not Classified

2401040000 - Solvent Utilization; Surface Coating; Metal Cans: SIC 341; Total: All Solvent Types 

40201702 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Cleaning/Pretreatment

40201703 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Coating Mixing

40201704 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Coating Storage

40201705 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Equipment Cleanup

40201706 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Solvent Storage

40201721 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Two Piece Exterior Base Coating

40201722 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Interior Spray Coating

40201723 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Sheet Base Coating (Interior)

40201724 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Sheet Base Coating (Exterior)

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-21 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40201725 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Side Seam Spray Coating

40201726 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating End Sealing Compound (Also See 4-02-017-36 & -3

40201727 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Lithography

40201728 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Over Varnish

40201729 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Exterior End Coating

40201731 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Three-piece Can Sheet Base Coating

40201732 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Three-piece Can Sheet Lithographic Coating Line

40201733 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Three-piece Can-side Seam Spray Coating

40201734 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Three-piece Can Interior Body Spray Coat

40201735 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Two-piece Can Coating Line

40201736 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Two-piece Can End Sealing Compound

40201737 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Three Piece Can End Sealing Compound

40201738 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Two Piece Can Lithographic Coating Line

40201739 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Three Piece Can Coating Line (All Coating Solven

Emission Points) 

40201799 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Can Coating Other Not Classified

2401045000 - Solvent Utilization; Surface Coating; Metal Coils: SIC 3498; Total: All Solvent Types 

40201801 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Coil Coating Prime Coating Application

40201802 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Coil Coating Cleaning/Pretreatment

40201803 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Coil Coating Solvent Mixing

40201804 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Coil Coating Solvent Storage (Use 4-07-004-01 thru 4-07-999-98 

possible) 

40201805 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Coil Coating Equipment Cleanup

40201806 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Coil Coating Finish Coating

40201807 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Coil Coating Coating Storage

40201899 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Metal Coil Coating Other Not Classified

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-22 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2401055000 - Solvent Utilization; Surface Coating; Machinery and Equipment: SIC 35; Total: All Solvent Types 

40202501 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Coating Operation

40202502 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Cleaning/Pretreatment

40202503 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Coating Mixing

40202504 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Coating Storage

40202505 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Equipment Cleanup

40202510 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Prime Coat Application

40202511 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Prime Coat Application: Spray, High Solids

40202512 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Prime Coat Application: Spray, Water-borne

40202515 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Prime Coat Application: Flashoff

40202520 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Topcoat Application

40202521 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Topcoat Application: Spray, High Solids

40202522 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Topcoat Application: Spray, Water-borne

40202523 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Topcoat Application: Dip

40202524 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Topcoat Application: Flow Coat

40202525 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Topcoat Application: Flashoff

40202531 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Conveyor Single Flow

40202532 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Conveyor Single Dip

40202533 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Conveyor Single Spray

40202534 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Conveyor Two Coat, Flow and Spray

40202535 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Conveyor Two Coat, Dip and Spray

40202536 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Conveyor Two Coat, Spray

40202537 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Manual Two Coat, Spray and Air Dry

40202542 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Single Coat Application: Spray, High Solids

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-23 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40202543 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Single Coat Application: Spray, Water-borne

40202544 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Single Coat Application: Dip

40202545 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Single Coat Application: Flow Coat

40202546 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Single Coat Application: Flashoff

40202599 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Miscellaneous Metal Parts Other Not Classified

2401060000 - Solvent Utilization; Surface Coating; Large Appliances: SIC 363; Total: All Solvent Types

40201401 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Prime Coating Operation

40201402 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Cleaning/Pretreatment

40201403 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Coating Mixing

40201404 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Coating Storage

40201405 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Equipment Cleanup

40201406 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Topcoat Spray

40201410 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Prime Coat Flashoff

40201411 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Topcoat Flashoff

40201431 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Coating Line: General

40201432 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Prime Air Spray

40201433 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Prime Electrostatic Spray

40201434 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Prime Flow Coat

40201435 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Prime Dip Coat

40201436 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Prime Electro-deposition

40201437 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Top Air Spray

40201438 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Top Electrostatic Spray

40201499 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Appliances Other Not Classified

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-24 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2401065000 - Solvent Utilization; Surface Coating; Electronic and Other Electrical: SIC 36 – 363; Total: All Solvent Types 

40203001 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Semiconductors Specify Solvent

2401070000 - Solvent Utilization; Surface Coating; Motor Vehicles: SIC 371; Total: All Solvent Types 

40201601 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Application/Electo-deposition/Dip/Spray 

40201602 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Cleaning/Pretreatment 

40201603 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Coating Mixing 

40201604 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Coating Storage 

40201605 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Equipment Cleanup 

40201606 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat Operation 

40201607 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Sealers 

40201608 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Deadeners 

40201609 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Anti-corrosion Priming 

40201619 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Surfacing Operation 

40201620 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Repair Topcoat Application Area 

40201621 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Coating: Solvent-borne - Automobiles 

40201622 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Coating: Electro-deposition - Automobiles 

40201623 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Guide Coating: Solvent-borne - Automobiles 

40201624 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Guide Coating: Water-borne - Automobiles 

40201625 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat: Solvent-borne - Automobiles 

40201626 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat: Water-borne - Automobiles 

40201627 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Coating: Solvent-borne - Light Trucks 

40201628 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Prime Coating: Electro-deposition - Light Trucks 

40201629 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Guide Coating: Solvent-borne - Light Trucks 

40201630 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Guide Coating: Water-borne - Light Trucks 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-25 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40201631 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat: Solvent-borne - Light Trucks 

40201632 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Topcoat: Water-borne - Light Trucks 

40201699 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Automobiles and Light Trucks Other Not Classified 

2401075000 - Solvent Utilization; Surface Coating; Aircraft: SIC 372; Total: All Solvent Types 

40202401 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Aircraft Prime Coating Operation

40202402 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Aircraft Cleaning/Pretreatment

40202403 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Aircraft Coating Mixing

40202404 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Aircraft Coating Storage

40202405 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Aircraft Equipment Cleanup

40202406 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Aircraft Topcoat Operation

40202499 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Aircraft Other Not Classified

2401080000 - Solvent Utilization; Surface Coating; Marine: SIC 373; Total: All Solvent Types 

40202301 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Ships Prime Coating Operation

40202302 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Ships Cleaning/Pretreatment

40202303 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Ships Coating Mixing

40202304 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Ships Coating Storage

40202305 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Ships Equipment Cleanup

40202306 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Ships Topcoat Operation

40202399 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Large Ships Other Not Classified

2401090000 - Solvent Utilization; Surface Coating; Miscellaneous Manufacturing; Total: All Solvent Types 

40202201 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Coating Operation

40202202 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Cleaning/Pretreatment

40202203 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Coating Mixing

40202204 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Coating Storage

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-26 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40202205 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Equipment Cleanup

40202206 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: Baseline Coating Mix

40202207 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: Low Solids Solvent-borne Coating

40202208 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: Medium Solids Solvent-borne Coating

40202209 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: High Solids Coating (25% Efficiency)

40202210 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: High Solids Solvent-borne Coating (40% 

Efficiency) 

40202211 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: Water-borne Coating

40202212 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: Low Solids Solvent-borne EMI/RFI Shieldi

Coating 

40202213 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: Higher Solids Solvent-borne EMI/RFI Shield

Coating 

40202214 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: Water-borne EMI/RFI Shielding Coating

40202215 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Business: Zinc Arc Spray

40202220 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Prime Coat Application

40202229 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Prime Coat Flashoff

40202230 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Color Coat Application

40202239 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Color Coat Flashoff

40202240 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Topcoat/Texture Coat Application

40202249 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Topcoat/Texture Coat Flashoff

40202250 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts EMI/RFI Shielding Coat Application

40202259 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts EMI/RFI Shielding Coat Flashoff

40202270 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Sanding/Grit Blasting Prior to EMI/RFI Shielding Co

Application 

40202280 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Maskant Application

40202299 Petroleum and Solvent 

Evaporation 

Surface Coating Operations Plastic Parts Other Not Classified

2415000000 - Solvent Utilization; Degreasing; All Processes/All Industries; Total: All Solvent Types 

40100201 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Stoddard (Petroleum Solvent): Open-top Vapor 

Degreasing 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-27 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40100202 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing 1,1,1-Trichloroethane (Methyl Chloroform): Open-to

Vapor Degreasing 

40100203 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Perchloroethylene: Open-top Vapor Degreasing

40100204 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Methylene Chloride: Open-top Vapor Degreasing

40100205 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Trichloroethylene: Open-top Vapor Degreasing

40100206 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Toluene: Open-top Vapor Degreasing

40100207 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Trichlorotrifluoroethane (Freon): Open-top Vapor 

Degreasing 

40100208 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Chlorosolve: Open-top Vapor Degreasing

40100209 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Butyl Acetate: Open-top Vapor Degreasing

40100215 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Entire Unit: Open-top Vapor Degreasing

40100216 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Degreaser: Entire Unit

40100217 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Entire Unit

40100221 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Stoddard (Petroleum Solvent): Conveyorized Vapo

Degreasing 

40100222 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing 1,1,1-Trichloroethane (Methyl Chloroform):Conveyoriz

Vapor Degreaser 

40100223 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Perchloroethylene: Conveyorized Vapor Degreasin

40100224 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Methylene Chloride: Conveyorized Vapor Degreasin

40100225 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Trichloroethylene: Conveyorized Vapor Degreasing

40100235 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Entire Unit: with Vaporized Solvent: Conveyorized Va

Degreasing 

40100236 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Entire Unit: with Non-boiling Solvent: Conveyorized Va

Degreasing 

40100251 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Stoddard (Petroleum Solvent): General Degreasing U

40100252 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing 1,1,1-Trichloroethane (Methyl Chloroform): Genera

Degreasing Units 

40100253 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Perchloroethylene: General Degreasing Units

40100254 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Methylene Chloride: General Degreasing Units

40100255 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Trichloroethylene: General Degreasing Units

40100256 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Toluene: General Degreasing Units

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-28 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40100257 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Trichlorotrifluoroethane (Freon): General Degreasin

Units 

40100258 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Trichlorofluoromethane: General Degreasing Units

40100259 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing 1,1,1-Trichloroethane (Methyl Chloroform): Genera

Degreasing Units 

40100295 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Other Not Classified: General Degreasing Units

40100296 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Other Not Classified: General Degreasing Units

40100297 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Other Not Classified: Open-top Vapor Degreasing

40100298 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Other Not Classified: Conveyorized Vapor Degreasin

40100299 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Degreasing Other Not Classified: Open-top Vapor Degreasing

40100301 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Methanol

40100302 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Methylene Chloride

40100303 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Stoddard (Petroleum Solvent)

40100304 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Perchloroethylene

40100305 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping 1,1,1-Trichloroethane (Methyl Chloroform)

40100306 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Trichloroethylene

40100307 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Isopropyl Alcohol

40100308 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Methyl Ethyl Ketone

40100309 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Freon

40100310 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Acetone

40100311 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Glycol Ethers

40100335 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Entire Unit

40100336 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Degreaser: Entire Unit

40100398 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Other Not Classified

40100399 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Cold Solvent Cleaning/Stripping Other Not Classified

40100401 Petroleum and Solvent 

Evaporation 

Organic Solvent Evaporation Knit Fabric Scouring with 

Chlorinated Solvent 

Perchloroethylene

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-29 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2425000000 - Solvent Utilization; Graphic Arts; All Processes; Total: All Solvent Types

40500101 Petroleum and Solvent 

Evaporation 

Printing/Publishing Drying Dryer

40500199 Petroleum and Solvent 

Evaporation 

Printing/Publishing Drying Dryer

40500201 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Letter Press: 2751

40500202 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent (Kerosene)

40500203 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvents (Mineral Solvents)

40500211 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Letter Press: 2751

40500212 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Printing: Letter Press

40500215 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Letterpress: Cleaning Solution

40500301 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Printing: Flexographic

40500302 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent (Carbitol)

40500303 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent (Cellosolve)

40500304 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent (Ethyl Alcohol)

40500305 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent (Isopropyl Alcohol)

40500306 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent (n-Propyl Alcohol)

40500307 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent (Naphtha)

40500311 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Printing: Flexographic

40500312 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Printing: Flexographic

40500314 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Printing: Flexographic: Propyl Alcohol Cleanup

40500315 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Flexographic: Steam: Water-based

40500316 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Flexographic: Steam: Water-based

40500317 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Flexographic: Steam: Water-based

40500318 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Flexographic: Steam: Water-based in Ink

40500319 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Flexographic: Steam: Water-based Ink Storage

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-30 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40500401 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Lithographic: 2752

40500411 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Lithographic: 2752

40500412 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Lithographic: 2752

40500413 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Lithographic: Isopropyl Alcohol Cleanup

40500414 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Flexographic: Propyl Alcohol Cleanup

40500415 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Offset Lithography: Dampening Solution with Alcoho

Substitute 

40500416 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Offset Lithography: Dampening Solution with High Sol

Content 

40500417 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Offset Lithography: Cleaning Solution: Water-based

40500418 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Offset Lithography: Dampening Solution with Isoprop

Alcohol 

40500421 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Offset Lithography: Heatset Ink Mixing

40500422 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Offset Lithography: Heatset Solvent Storage

40500431 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Offset Lithography: Nonheated Lithographic Inks

40500432 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Offset Lithography: Nonheated Lithographic Inks

40500433 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Offset Lithography: Nonheated Lithographic Inks

40500501 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Gravure: 2754

40500502 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent: Dimethylformamide

40500503 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent: Ethyl Acetate

40500506 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent: Methyl Ethyl Ketone

40500507 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent: Methyl Isobutyl Ketone

40500510 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent: Toluene

40500511 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Gravure: 2754

40500512 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Gravure: 2754

40500513 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Gravure: 2754

40500514 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Gravure: Cleanup Solvent

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-31 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40500597 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Other Not Classified

40500598 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent: Other Not Specified

40500599 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Thinning Solvent: Other Not Specified

40500601 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Ink Mixing

40500701 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Solvent Storage

40500801 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Screen Printing

40500802 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Fugitive Emissions: Cleaning Rags

40500811 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Screen Printing

40500812 Petroleum and Solvent 

Evaporation 

Printing/Publishing General Screen Printing

40588801 Petroleum and Solvent 

Evaporation 

Printing/Publishing Fugitive Emissions Specify in Comments Field

40588802 Petroleum and Solvent 

Evaporation 

Printing/Publishing Fugitive Emissions Specify in Comments Field

40588803 Petroleum and Solvent 

Evaporation 

Printing/Publishing Fugitive Emissions Specify in Comments Field

40588804 Petroleum and Solvent 

Evaporation 

Printing/Publishing Fugitive Emissions Specify in Comments Field

40588805 Petroleum and Solvent 

Evaporation 

Printing/Publishing Fugitive Emissions Specify in Comments Field

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-32 

Table A-6. Gasoline Distribution Crosswalk for Point Source Subtractions 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2501050120 - Storage and Transport; Petroleum and Petroleum Product Storage; Bulk Terminals: All Evaporative Losses; Gasoline 

40400101 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Breathing Loss (67000 Bbl Capacity) - Fixed Roof Tank 40400102 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Breathing Loss (67000 Bbl Capacity) - Fixed Roof Tank 40400103 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Breathing Loss (67000 Bbl. Capacity) - Fixed Roof Tank 40400104 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Breathing Loss (250000 Bbl Capacity)-Fixed Roof Tank 40400105 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Breathing Loss (250000 Bbl Capacity)-Fixed Roof Tank 40400106 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Breathing Loss (250000 Bbl Capacity) - Fixed Roof Tank 40400107 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Working Loss (Diam. Independent) - Fixed Roof Tank 40400108 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Working Loss (Diam. Independent) - Fixed Roof Tank 40400109 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Working Loss (Diam. Independent) - Fixed Roof Tank 40400110 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Standing Loss (67000 Bbl Capacity)-Float. Roof Tank 40400111 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Standing Loss (67000 Bbl Capacity)-Float. Roof Tank 40400112 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Standing Loss (67000 Bbl Capacity)- Floating Roof Tank 40400113 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Standing Loss (250000 Bbl Cap.) - Floating Roof Tank 40400114 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Standing Loss (250000 Bbl Cap.) - Floating Roof Tank 40400115 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Standing Loss (250000 Bbl Cap.) - Floating Roof Tank 40400116 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13/10/7: Withdrawal Loss (67000 Bbl Cap.) - Float Rf Tnk 40400117 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13/10/7: Withdrawal Loss (250000 Bbl Cap.) - Float Rf Tnk 40400118 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space 40400119 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space 40400120 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space 40400131 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Standing Loss - Ext. Floating Roof w/ Primary Seal 40400132 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Standing Loss - Ext. Floating Roof w/ Primary Seal 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-33 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40400133 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Standing Loss - External Floating Roof w/ Primary Seal 40400141 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Standing Loss - Ext. Floating Roof w/ Secondary Seal 40400142 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Standing Loss - Ext. Floating Roof w/ Secondary Seal 40400143 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Standing Loss - Ext. Floating Roof w/ Secondary Seal 40400148 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13/10/7: Withdrawal Loss - Ext. Float Roof (Pri/Sec Seal) 40400150 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Miscellaneous Losses/Leaks: Loading Racks40400151 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Valves, Flanges, and Pumps40400152 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Vapor Collection Losses40400153 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Vapor Control Unit Losses40400161 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Standing Loss - Int. Floating Roof w/ Primary Seal 40400162 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Standing Loss - Int. Floating Roof w/ Primary Seal 40400163 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Standing Loss - Internal Floating Roof w/ Primary Seal 40400171 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13: Standing Loss - Int. Floating Roof w/ Secondary Seal 40400172 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 10: Standing Loss - Int. Floating Roof w/ Secondary Seal 40400173 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 7: Standing Loss - Int. Floating Roof w/ Secondary Seal 40400178 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Gasoline RVP 13/10/7: Withdrawal Loss - Int. Float Roof (Pri/Sec Seal) 

2501055120 - Storage and Transport; Petroleum and Petroleum Product Storage; Bulk Plants: All Evaporative Losses; Gasoline 

40400201 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 13: Breathing Loss (67000 Bbl Capacity) - Fixed Roof Tank 40400202 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10: Breathing Loss (67000 Bbl Capacity) - Fixed Roof Tank 40400203 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 7: Breathing Loss (67000 Bbl. Capacity) - Fixed Roof Tank 40400204 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 13: Working Loss (67000 Bbl. Capacity) - Fixed Roof Tank 40400205 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10: Working Loss (67000 Bbl. Capacity) - Fixed Roof Tank 40400206 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 7: Working Loss (67000 Bbl. Capacity) - Fixed Roof Tank 40400207 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 13: Standing Loss (67000 Bbl Cap.) - Floating Roof Tank 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-34 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40400208 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10: Standing Loss (67000 Bbl Cap.) - Floating Roof Tank 40400209 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 7: Standing Loss (67000 Bbl Cap.) - Floating Roof Tank 40400210 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 13/10/7: Withdrawal Loss (67000 Bbl Cap.) - Float Rf Tnk 40400211 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 13: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space 40400212 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space 40400213 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 7: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space 40400231 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 13: Standing Loss - Ext. Floating Roof w/ Primary Seal 40400232 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10: Standing Loss - Ext. Floating Roof w/ Primary Seal 40400233 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 7: Standing Loss - External Floating Roof w/ Primary Seal 40400241 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 13: Standing Loss - Ext. Floating Roof w/ Secondary Seal 40400242 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10: Standing Loss - Ext. Floating Roof w/ Secondary Seal 40400243 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 7: Standing Loss - Ext. Floating Roof w/ Secondary Seal 40400248 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10/13/7: Withdrawal Loss - Ext. Float Roof (Pri/Sec Seal) 40400250 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Loading Racks40400251 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Valves, Flanges, and Pumps40400252 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Miscellaneous Losses/Leaks: Vapor Collection Losses 40400253 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Miscellaneous Losses/Leaks: Vapor Control Unit Losses 40400261 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 13: Standing Loss - Int. Floating Roof w/ Primary Seal 40400262 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10: Standing Loss - Int. Floating Roof w/ Primary Seal 40400263 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 7: Standing Loss - Internal Floating Roof w/ Primary Seal 40400271 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 13: Standing Loss - Int. Floating Roof w/ Secondary Seal 40400272 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10: Standing Loss - Int. Floating Roof w/ Secondary Seal 40400273 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 7: Standing Loss - Int. Floating Roof w/ Secondary Seal 40400278 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Gasoline RVP 10/13/7: Withdrawal Loss - Int. Float Roof (Pri/Sec Seal) 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-35 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

40400401 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Petrol Prods - Undergrd Tanks Gasoline RVP 13: Breathing Loss40400402 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Petrol Prods - Undergrd Tanks Gasoline RVP 13: Working Loss40400403 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Petrol Prods - Undergrd Tanks Gasoline RVP 10: Breathing Loss40400404 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Petrol Prods - Undergrd Tanks Gasoline RVP 10: Working Loss40400405 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Petrol Prods - Undergrd Tanks Gasoline RVP 7: Breathing Loss40400406 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Petrol Prods - Undergrd Tanks Gasoline RVP 7: Working Loss40600101 Petroleum and Solvent Evaporation Transport. & Marketing of Petrol 

Product 

Tank Cars/Trucks Gasoline: Splash Loading **

40600126 Petroleum and Solvent Evaporation Transport. & Marketing of Petrol 

Product 

Tank Cars/Trucks Gasoline: Submerged Loading **

40600131 Petroleum and Solvent Evaporation Transport. & Marketing of Petrol 

Product 

Tank Cars/Trucks Gasoline: Submerged Loading (Normal Service)

40600136 Petroleum and Solvent Evaporation Transport. & Marketing of Petrol 

Product 

Tank Cars/Trucks Gasoline: Splash Loading (Normal Service)

40600141 Petroleum and Solvent Evaporation Transport. & Marketing of Petrol 

Product 

Tank Cars/Trucks Gasoline: Submerged Loading (Balanced 

Service) 

40600144 Petroleum and Solvent Evaporation Transport. & Marketing of Petrol 

Product 

Tank Cars/Trucks Gasoline: Splash Loading (Balanced Service)

40600147 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Tank Cars/Trucks Gasoline: Submerged Loading (Clean Tanks)

2501060051 - Storage and Transport; Petroleum and Petroleum Product Storage; Gasoline Service Stations; Stage 1: Submerged Filling 

40600302 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Submerged Filling w/o Controls

40600305 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Unloading ** 

40600399 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Not Classified ** 

40600702 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Consumer (Corporate) 

Fleet Refueling - Stage I 

Submerged Filling w/o Controls

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-36 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2501060052 - Storage and Transport; Petroleum and Petroleum Product Storage; Gasoline Service Stations; Stage 1: Splash Filling 

40600301 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Splash Filling

40600305 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Unloading ** 

40600399 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Not Classified ** 

40600701 Petroleum and Solvent Evaporation Transportation and Marketing of

Petroleum Products 

Consumer (Corporate) 

Fleet Refueling - Stage I 

Splash Filling

2501060053 - Storage and Transport; Petroleum and Petroleum Product Storage; Gasoline Service Stations; Stage 1: Balanced Submerged Filli

40600305 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Unloading ** 

40600306 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Balanced Submerged Filling

40600399 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Not Classified ** 

40600706 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Consumer (Corporate) 

Fleet Refueling - Stage I 

Balanced Submerged Filling

2501060100 - Storage and Transport; Petroleum and Petroleum Product Storage; Gasoline Service Stations; Stage 2: Total 

40600401 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Filling Vehicle Gas Tanks - Stage II Vapor Loss w/o Controls

40600402 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Filling Vehicle Gas Tanks - Stage II Liquid Spill Loss w/o Controls

40600403 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Filling Vehicle Gas Tanks - Stage II Vapor Loss w/o Controls

40600499 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Filling Vehicle Gas Tanks - Stage II Not Classified **

40600601 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Consumer (Corporate) 

Fleet Refueling - Stage II 

Vapor Loss w/o Controls

40600602 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Consumer (Corporate) 

Fleet Refueling - Stage II 

Liquid Spill Loss w/o Controls

40600603 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Consumer (Corporate) 

Fleet Refueling - Stage II 

Vapor Loss w/controls

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-37 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2501060201 – Storage and Transport; Petroleum and Petroleum Product Transport; Gasoline Service Stations; Underground Tank: Breathing and Em

40600307 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Gasoline Retail Operations 

- Stage I 

Underground Tank Breathing and Emptying

40600707 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Consumer (Corporate) 

Fleet Refueling - Stage I 

Underground Tank Breathing and Emptying

2505030120 - Storage and Transport; Petroleum and Petroleum Product Transport; Truck; Gasoline 

40400154 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Terminals Tank Truck Vapor Leaks40400254 Petroleum and Solvent Evaporation Petroleum Liquids Storage (non- Refinery) Bulk Plants Tank Truck Vapor Losses40600162 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Tank Cars and Trucks Gasoline: Loaded with Fuel (Transit Losses)

40600163 Petroleum and Solvent Evaporation Transportation and Marketing of 

Petroleum Products 

Tank Cars and Trucks Gasoline: Return with Vapor (Transit Losses)

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-38 

Table A-7. Mining and Quarrying Crosswalk for Point Source Subtraction 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2325000000 – Industrial Processes; Mining and Quarrying: SIC 14; All Processes; Total 

30302401 Industrial Processes Primary Metal Production Metal Mining (General Processes) Primary Crushing: Low Mo30302402 Industrial Processes Primary Metal Production Metal Mining (General Processes) Secondary Crushing: Low M30302403 Industrial Processes Primary Metal Production Metal Mining (General Processes) Tertiary Crushing: Low Mo30302404 Industrial Processes Primary Metal Production Metal Mining (General Processes) Material Handling: Low Mo30302405 Industrial Processes Primary Metal Production Metal Mining (General Processes) Primary Crushing: High Mo30302406 Industrial Processes Primary Metal Production Metal Mining (General Processes) Secondary Crushing: High M30302407 Industrial Processes Primary Metal Production Metal Mining (General Processes) Tertiary Crushing: High Mo30302408 Industrial Processes Primary Metal Production Metal Mining (General Processes) Material Handling: High Mo30302409 Industrial Processes Primary Metal Production Metal Mining (General Processes) Dry Grinding with Air Co30302410 Industrial Processes Primary Metal Production Metal Mining (General Processes) Dry Grinding without Air C30302411 Industrial Processes Primary Metal Production Metal Mining (General Processes) Ore Drying30303101 Industrial Processes Primary Metal Production Leadbearing Ore Crushing and Grinding Lead Ore w/ 5.1% Lead 30303102 Industrial Processes Primary Metal Production Leadbearing Ore Crushing and Grinding Zinc Ore w/ 0.2% Lead 30303103 Industrial Processes Primary Metal Production Leadbearing Ore Crushing and Grinding Copper Ore w/ 0.2% Lead 30303104 Industrial Processes Primary Metal Production Leadbearing Ore Crushing and Grinding Lead-Zinc Ore w/ 2% Lea30303105 Industrial Processes Primary Metal Production Leadbearing Ore Crushing and Grinding Copper-Lead Ore w/ 2% Le30303106 Industrial Processes Primary Metal Production Leadbearing Ore Crushing and Grinding Copper-Zinc Ore w/ 0.2% Le30303107 Industrial Processes Primary Metal Production Leadbearing Ore Crushing and Grinding Copper-Lead-Zinc w/ 2% Le30501001 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Fluidized Bed30501002 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Flash or Suspensi30501003 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Multilouvered30501004 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Rotary30501005 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Cascade30501006 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Continuous Carrie30501007 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Screen30501008 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Unloading30501009 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Raw Coal Storag30501010 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Crushing30501011 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Coal Transfer30501012 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Screening30501013 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Air Tables30501014 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Cleaned Coal Stora30501015 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Loading30501016 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Loading: Clean Co30501017 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Secondary Crushi30501021 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Overburden Remo30501022 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Drilling/Blasting30501023 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Loading30501024 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Hauling30501030 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Topsoil Remova30501031 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Scrapers: Travel Mo30501032 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Topsoil Unloadin30501033 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Overburden30501034 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Coal Seam: Drillin

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-39 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

30501035 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Blasting: Coal Overbu30501036 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Dragline: Overburden R30501037 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Truck Loading: Overb30501038 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Truck Loading: Co30501039 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Hauling: Haul Truc30501040 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Truck Unloading: End Du30501041 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Truck Unloading: Bottom D30501042 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Truck Unloading: Bottom Dump 30501043 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Open Storage Pile: C30501044 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Train Loading: Co30501045 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Bulldozing: Overbur30501046 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Bulldozing: Coa30501047 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Grading30501048 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Overburden Replace30501049 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Wind Erosion: Exposed 30501050 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Vehicle Traffic: Light/Mediu30501051 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Surface Mining Operations: Ope

Spoils 

30501060 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Surface Mining Operations: Pr30501061 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Surface Mining Operations: Sec30501062 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Surface Mining Operations30501090 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Haul Roads: Gene30501099 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305310) Other Not Classifie30501640 Industrial Processes Mineral Products Lime Manufacture Vehicle Traffic30501650 Industrial Processes Mineral Products Lime Manufacture Quarrying Raw Limes30502009 Industrial Processes Mineral Products Stone Quarrying - Processing (See also 305320) Blasting: Genera30502010 Industrial Processes Mineral Products Stone Quarrying - Processing (See also 305320) Drilling30502018 Industrial Processes Mineral Products Stone Quarrying - Processing (See also 305320) Drilling with Liquid Inje30502020 Industrial Processes Mineral Products Stone Quarrying - Processing (See also 305320) Drilling30502513 Industrial Processes Mineral Products Construction Sand and Gravel Excavating30502514 Industrial Processes Mineral Products Construction Sand and Gravel Drilling and Blastin30503101 Industrial Processes Mineral Products Asbestos Mining Surface Blasting30503102 Industrial Processes Mineral Products Asbestos Mining Surface Drilling30503103 Industrial Processes Mineral Products Asbestos Mining Cobbing30503108 Industrial Processes Mineral Products Asbestos Mining Overburden Stripp30503109 Industrial Processes Mineral Products Asbestos Mining Ventilation of Process Op30503199 Industrial Processes Mineral Products Asbestos Mining Other Not Classifie30504001 Industrial Processes Mineral Products Mining and Quarrying of Nonmetallic Minerals Open Pit Blasting30504002 Industrial Processes Mineral Products Mining and Quarrying of Nonmetallic Minerals Open Pit Drilling30504003 Industrial Processes Mineral Products Mining and Quarrying of Nonmetallic Minerals Open Pit Cobbing30504010 Industrial Processes Mineral Products Mining and Quarrying of Nonmetallic Minerals Underground Ventila30504024 Industrial Processes Mineral Products Mining and Quarrying of Nonmetallic Minerals Overburden Stripp30504101 Industrial Processes Mineral Products Clay processing: Kaolin Mining30504201 Industrial Processes Mineral Products Clay processing: Ball clay Mining30504301 Industrial Processes Mineral Products Clay processing: Fire clay Mining30504401 Industrial Processes Mineral Products Clay processing: Bentonite Mining30504501 Industrial Processes Mineral Products Clay processing: Fullers earth Mining30504601 Industrial Processes Mineral Products Clay processing: Common clay and shale, NEC Mining30531001 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Fluidized Bed

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-40 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

30531002 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Flash or Suspensi30531003 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Multilouvered30531004 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Rotary30531005 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Cascade30531006 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Continuous Carrie30531007 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Screen30531008 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Unloading30531009 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Raw Coal Storag30531010 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Crushing30531011 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Coal Transfer30531012 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Screening30531013 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Air Tables30531014 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Cleaned Coal Stora30531015 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Loading30531016 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Loading: Clean Co30531017 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Secondary Crushi30531090 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Haul Roads: Gene30531099 Industrial Processes Mineral Products Coal Mining, Cleaning, and Material Handling (See 305010) Other Not Classifie30532009 Industrial Processes Mineral Products Stone Quarrying - Processing (See also 305020 for diff. units) Blasting: Genera30532010 Industrial Processes Mineral Products Stone Quarrying - Processing (See also 305020 for diff. units) Drilling30532011 Industrial Processes Mineral Products Stone Quarrying - Processing (See also 305020 for diff. units) Hauling30532020 Industrial Processes Mineral Products Stone Quarrying - Processing (See also 305020 for diff. units) Drilling30532090 Industrial Processes Mineral Products Stone Quarrying - Processing (See also 305020 for diff. units) Haul Roads - Gene

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-41 

Table A-8. Agriculture Production Crosswalk for Livestock 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

2805001100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Beef cattle - finishing operations on feedlots (drylots); Confinem

30202001 Industrial Processes Food and Agriculture Beef Cattle Feedlots Feedlots: General Apportion 30202002 Industrial Processes Food and Agriculture Beef Cattle Feedlots Feedlots: General Apportion 

2805001200 - Miscellaneous Area Sources; Agriculture Production – Livestock; Beef cattle - finishing operations on feedlots (drylots); Manure handling 

30202001 Industrial Processes Food and Agriculture Beef Cattle Feedlots Feedlots: General Apportion 30202002 Industrial Processes Food and Agriculture Beef Cattle Feedlots Feedlots: General Apportion 

2805001300 - Miscellaneous Area Sources; Agriculture Production – Livestock; Beef cattle - finishing operations on feedlots (drylots); Land application 

30202001 Industrial Processes Food and Agriculture Beef Cattle Feedlots Feedlots: General Apportion 30202002 Industrial Processes Food and Agriculture Beef Cattle Feedlots Feedlots: General Apportion 

2805003100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Beef cattle - finishing operations on pasture/range; Confineme

30202001 Industrial Processes Food and Agriculture Beef Cattle Feedlots Feedlots: General Apportion 30202002 Industrial Processes Food and Agriculture Beef Cattle Feedlots Feedlots: General Apportion 

2805007100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with dry manure management systems; Co

30202101 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Dry Apportion 30202102 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Dry Apportion 

2805007300 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with dry manure management systems; Land appli

30202101 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Dry Apportion 30202102 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Dry Apportion 

2805008100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with wet manure management systems; Co

30202105 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Wet Apportion 30202106 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Wet Apportion 

2805008200 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with wet manure management systems; Manure han

30202105 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Wet Apportion 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
A-42 

Point SCC SCC1 DESC SCC3 DESC SCC6 DESC SCC8 DESC 

30202106 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Wet Apportion 

2805008300 - Miscellaneous Area Sources; Agriculture Production – Livestock; Poultry production - layers with wet manure management systems; Land appli

30202105 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Wet Apportion 30202106 Industrial Processes Food and Agriculture Eggs and Poultry Production Manure Handling: Wet Apportion 

2805039100 - Miscellaneous Area Sources; Agriculture Production – Livestock; Swine production - operations with lagoons (unspecified animal age); Co

30202000 Industrial Processes Food and Agriculture Beef Cattle Feedlots Swine Feedlots Apportion 

2805039200 - Miscellaneous Area Sources; Agriculture Production – Livestock; Swine production - operations with lagoons (unspecified animal age); Manure ha

30202000 Industrial Processes Food and Agriculture Beef Cattle Feedlots Swine Feedlots Apportion 

2805039300 - Miscellaneous Area Sources; Agriculture Production – Livestock; Swine production – deep-pit house operations (unspecified animal age); Land ap

30202000 Industrial Processes Food and Agriculture Beef Cattle Feedlots Swine Feedlots Apportion 

2805047100 – Miscellaneous Area Sources; Agriculture Production – Livestock; Swine Production – deep-pit operations (unspecified animal age); Con

30202000 Industrial Processes Food and Agriculture Beef Cattle Feedlots Swine Feedlots Apportion 

2805047300 – Miscellaneous Area Sources; Agriculture Production – Livestock; Swine Production – deep-pit operations (unspecified animal age); Land applic

30202000 Industrial Processes Food and Agriculture Beef Cattle Feedlots Swine Feedlots Apportion 

2805053100 – Miscellaneous Area Sources; Agriculture Production – Livestock; Swine Production – outdoor operations (unspecified animal age); Con

30202000 Industrial Processes Food and Agriculture Beef Cattle Feedlots Swine Feedlots Apportion 

Note: no emissions were identified in the above SCCs within version 1.10a of the SEMAP point source inventory. 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
2007 MOVES2010a On

Emissions Factors for the 

Southeastern Modeling Analysis 

and Planning (SEMAP) States

Executive Director, Southeastern 

526 Forest Parkway, Suite F

Forest Park, GA 30297

(404) 361

hornback@metro4

AMEC Environment & Infrastructure, Inc.

(352) 333

Alpine Geophysics, LLC

Mark Diblin 

Senior Principal 

AMEC Project No.: 

Contract No.: S

2007 MOVES2010a On-road Mobile Source 

Emissions Factors for the 

Southeastern Modeling Analysis 

Planning (SEMAP) States

Prepared For: 

John Hornback 

Executive Director, Southeastern States Air Resource Managers, Inc.

526 Forest Parkway, Suite F

Forest Park, GA 30297-6140. 

(404) 361-4000, FAX (404) 361-2411 

hornback@metro4-sesarm.org

Prepared by: 

AMEC Environment & Infrastructure, Inc.

404 SW 140th Terrace 

Newberry, FL 32669 

(352) 333-6617, FAX (352) 333-6622 

wrbarnard@ AMEC.com

and 

Alpine Geophysics, LLC

2076 Westwood Lane 

Eugene, OR 97401 

William R. Barnard

Senior Principal

AMEC Project No.: 6066-09-0326.02 

Contract No.: S-2009-06-02 

March 21, 2013 

road Mobile Source 

Southeastern Modeling Analysis 

Planning (SEMAP) States

States Air Resource Managers, Inc.

William R. Barnard

Senior Principal

WV SIP Revision: Regional Haze 5-Year Periodic Report Page A - 1097
2007 MOVES2010a On-road Mobile Source Emissions Factors for the 

Southeastern Modeling Analysis and Planning (SEMAP) States March 21, 2013 

i AMEC 

Table of Contents

1.0 INTRODUCTION ............................................................................................................................ 4

1.1 THE MOTOR VEHICLE EMISSIONS SIMULATOR (MOVES) .................................................. 4

1.2 MOVES/SMOKE INTERFACE TOOL ............................................................................ 4

2.0 COMPONENTS OF THE STUDY ................................................................................................. 6

2.1 RH AND RVP SENSITIVITY EXPERIMENTS......................................................................... 6

2.2 ESTIMATE MOVES AND SMOKE METEOROLOGY ............................................................. 6

2.3 ESTIMATE EMISSIONS FACTORS USING MOVES2010A..................................................... 6

2.4 ESTIMATE EMISSIONS USING SMOKE ............................................................................. 6

2.5 PREPARE EMISSIONS ESTIMATES SUMMARIES FROM SMOKE REPORTS............................ 7

3.0 RELATIVE HUMIDITY (RH) AND REID VAPOR PRESSURE (RVP) 

SENSITIVITY EXPERIMENTS ............................................................................................................ 8

4.0 ESTIMATE MOVES AND SMOKE METEOROLOGY ............................................................. 11

4.1 DATA INPUTS ............................................................................................................ 11

4.2 DATA OUTPUTS ........................................................................................................ 12

4.3 RUN SCRIPTS ............................................................................................................ 13

5.0 ESTIMATE EMISSIONS FACTORS USING MOVES2010A ................................................... 15

5.1 DATA INPUTS ............................................................................................................ 15

5.2 QUALITY ASSURANCE OF THE MOVES INPUTS ..................................................... 16

5.3 MOVES DATA IMPORT AND RUN SPECIFICATION SCRIPTS ................................. 16

5.4 QUALITY ASSURANCE OF THE MOVES XML AND C-SHELL SCRIPTS .................. 18

5.5 RUNNING MOVES2010A ........................................................................................... 18

5.6 DATA OUTPUTS ........................................................................................................ 18

5.7 GENERATION OF THE SMOKE-READY EMISSIONS FACTORS .............................. 19

5.8 QUALITY ASSURANCE OF THE MOVES OUTPUT EMISSIONS FACTORS ............. 20

6.0 DEVELOPMENT OF THE EMISSIONS ESTIMATES REPORTS .......................................... 23

6.1 OVERVIEW OF WORKSHEETS ................................................................................. 23

6.2 OVERVIEW OF EMBEDDED VBA MACROS .............................................................. 23

6.3 USER POLL LIST WORKSHEET ................................................................................ 24

6.4 USER-DEFINED REPORTS ....................................................................................... 25

6.5 EXECUTION SPEED OF MACROS ............................................................................ 25

6.6 EMISSIONS ESTIMATES SUMMARIES ..................................................................... 25

7.0 DATA DISK .................................................................................................................................. 37

8.0 CONCLUSION ............................................................................................................................. 41

9.0 REFERENCES ............................................................................................................................. 43

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Table of Tables 

Table 4-1. Names of representative counties by state and the number of counties assigned to 

the representative counties. 

Table 6-1. Annual on-road mobile source emissions summary by state and network from 

gasoline fueled vehicles (tons/year). 

Table 6-2. Annual on-road mobile source emissions summary by state and network from 

diesel fueled vehicles (tons/year). 

Table 6-3. Annual on-road mobile source emissions summary by state and network from 

gasoline and diesel fueled vehicles (tons/year). 

Table 6-4. Annual on-road mobile source emissions summary by state and vehicle category 

(tons/year). 

Table 6-5. Ozone season day on-road mobile source emissions summary by state and vehicle 

category (tons/day). 

Table 7-1. Description of data disk archive for the SEMAP 2007 MOVES2010a study. 

 

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Table of Figures 

Figure 4-1. Overview of the C-shell script to run MET4MOVES. ?? in the file names refer to 

the two letter state abbreviation.

Figure 5-1. Overview of the data inputs and C-shell scripts used to construct the 

MOVES2010a modeling system data import XML and run specification XML 

scripts. ?? in the file names refer to the two letter state abbreviation. SSCCC in 

the file names refer to the five digit state-county FIPS identifier for the 

representative county.

Figure 5-2. Overview of the SMOKE-MOVESIntegration perl script and input file that was 

necessary to extract the emissions factors from the MOVES2010a MySQL output 

data bases. SS in the file names refer to the two digit state FIPS identifier. 

SSCCC in the file names refer to the five digit state-county FIPS identifier for the 

representative county. MM in the file names refer to the two digit fuel month 

identifier.

Figure 5-3. Running exhaust VOC rate per distance emissions factors (g/mile) for the 2007 

winter season for light duty diesel vehicles on urban interstates for Mecklenburg 

County, North Carolina by temperature and speed bin.

Figure 5-4. Crankcase start exhaust VOC rate per vehicle emissions factors (g/vehicle/hour) 

for the 2007 winter season for light duty gasoline vehicles on all road types for 

Jefferson County, Alabama by hour and temperature.

Figure 6-1. Percentage contribution by state and fuel to annual on-road mobile source 

emissions estimates.

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1.0 INTRODUCTION 

The Southeastern Modeling Analysis and Planning (SEMAP) group requested the development of 

on-road mobile source emissions factors for SEMAP states using the latest version of MOVES2010 

(OTAQ, 2010a, 2010b) and EPA’s MOVES/SMOKE interface tool (EPA, 2010). Though the original 

proposal called for the development of on-road mobile source emissions factors for a 2007 base 

year and up to three future years, this document details how on-road mobile source emissions 

factors were estimated for a 2007 base year. 

1.1 The Motor Vehicle Emissions Simulator (MOVES) 

MOVES2010 is the U.S. EPA’s next generation mobile source emissions model. An important 

feature of MOVES2010 is that a user can choose between two options to model on-road mobile 

source emissions: (1) the Inventory calculation, which estimates emission rates in terms of total 

quantity of emissions for a given time period, and (2) the Emission Rate calculation, which estimates 

emission rates in terms of grams/mile (i.e., on-network driving) and grams/vehicle/hour (i.e., offnetwork idling, starts, refueling, parked, and vapor venting). For purposes of the proposed study, the 

second option (i.e., Emission Rate calculation) was used. 

The first rendition of the model was MOVES2010a. The study team used MOVES2010a for the 

entire project, though MOVES2010b did become available about three-quarters of the way through 

the study. Based on assurances from EPA’s Office of Transportation and Air Quality (OTAQ) that 

the emissions factors between the two versions of MOVES were identical, SEMAP decided that it 

was best to proceed with the use of the first release of the model instead MOVES2010b since input 

file development for MOVES2010a had already progressed significantly and to avoid any potential 

delays resulting from transitioning to the newest MOVES version. All future references to 

MOVES2010 in this document thus refer to MOVES2010a. During the course of the project, the 

study team collaborated with project team members from the northeast United States, who were also 

running MOVES2010a for their purposes, and with OTAQ staff responsible for the development of 

MOVES. As the current study effort really turned out to be one of the first real-world applications of 

the MOVES modeling system, the work involved a substantial shakedown of the MOVES modeling 

system. Thus, as a result of the collaborative effort, we were able to jointly identify, verify, and offer 

suggestions on how to correct errors encountered while running the MOVES modeling system. 

The approach to run MOVES2010 for SMOKE was based on “representative” counties in order to 

avoid duplicate, time consuming runs of MOVE2010. Counties that shared the same fuel 

parameters, fleet age distribution, and inspection/maintenance (I/M) programs, among other factors, 

were grouped together and a MOVES2010 run was made for a single, representative county. 

During SMOKE modeling of the on-road mobile source sector, the MOVES2010 emissions rates for 

this representative county were applied to all counties in the county group. Each representative 

county was modeled at a range of speeds and temperatures to produce emission rate lookup tables 

(grams/mile or grams/vehicle/hour). The approach allowed any county with unique distributions of 

vehicle miles traveled (VMT), vehicle population, roadway speed, and grid cell temperatures to be 

modeled in SMOKE without having to rerun MOVES2010.

1.2 MOVES/SMOKE INTERFACE TOOL 

OTAQ, through contractor support, has developed the MOVES/SMOKE Interface Tool to facilitate 

the process of using MOVES to create on-road mobile source emissions estimates for use in air 

quality modeling. The MOVES/SMOKE Interface Tool is comprised of scripts that automate the 

proper use of the Emission Rate calculations. The SMOKE-MOVES tool provides three major 

functions: (1) Meteorological data preprocessor; (2) MOVES2010 model processor; and (3) SMOKE 

model processor. 

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The Meteorological data preprocessor (MET4MOVES) prepares spatially and temporally averaged 

temperatures and relative humidity data to set up the meteorological input conditions for 

MOVES2010 and SMOKE using the Meteorology-Chemistry Interface Processor (MCIP) output files. 

The MOVES2010 model processor creates data input files (i.e., runspec) for use in MOVES2010 

that specifies the characteristics of the particular scenario to be modeled, and it reformats the 

resulting MOVES2010 emission rates lookup tables that are suitable for input to SMOKE. The 

SMOKE postprocessor (MOVESMRG) estimates emissions from on-road mobile sources based on 

MOVES2010-based emission rate lookup tables and meteorology data from MET4MOVES. 

For purposes of the proposed study, the study team did not run MOVESMRG. Instead, we provided 

the outputs from MET4MOVES and the MOVES2010 model processor to SEMAP for their use in 

running MOVESMRG. SEMAP then provided the study team with the SMOKE reports from which 

we developed the emissions estimates summaries. 

 

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2.0 COMPONENTS OF THE STUDY 

There were five distinct components to this effort:

• Perform relative humidity (RH) and Reid vapor pressure (RVP) sensitivity experiments; 

• Estimate MOVES and SMOKE meteorology; 

• Estimate on-road mobile source emissions factors using MOVES2010a; 

• Estimate on-road mobile source emissions using SMOKE; and 

• Prepare on-road mobile source emissions estimates summaries from SMOKE reports. 

The study team (AMEC Environment & Infrastructure, Inc. and Alpine Geophysics, LLC) conducted 

all aspects of this project except for the effort required to estimate on-road mobile source emissions

using SMOKE, which was conducted by the University of North Carolina. A brief summary is 

provided for each component here and is more fully discussed within the body of this report, with the 

exception of the component to estimate on-road mobile source emissions using SMOKE. 

2.1 RH and RVP Sensitivity Experiments 

MOVES2010a requires as input the choice of fuel modeling seasons. The modeling seasons are 

chosen based on information such as the fuel characteristics and meteorology. At the time the 

project started, MOVES was just being introduced to the modeling community, and it was unclear 

how sensitive the model would be to variations in these data. As such, SEMAP decided to conduct 

two sensitivity experiments involving two of the parameters: relative humidity (RH) and Reid vapor 

pressure (RVP); to determine how sensitive MOVES emissions estimates were to these parameters. 

2.2 Estimate MOVES and SMOKE Meteorology 

MOVES and SMOKE require estimates of RH and ambient temperature for each group of counties 

associated with a representative county by fuel season. The estimates of RH and ambient 

temperature for use in MOVES2010a and SMOKE were prepared using the MET4MOVES 

component of the SMOKE-MOVES Integration Tool (EPA, 2010). 

2.3 Estimate Emissions Factors Using MOVES2010a 

The study team developed the following six files based on information received from SEMAP: 

• Fuel formulation; 

• Fuel supply; 

• VMT; 

• Inspection and Maintenance (I/M) program; 

• Age distribution; and 

• Vehicle population. 

These data coupled with the meteorology were input to MOVES2010a, which produced the on-road 

mobile source emissions factors. The input data and the on-road mobile source emissions factors 

were subjected to quality assurance review by the study team, the SEMAP QA contractor 

(ENVIRON), and representatives from the SEMAP states. 

2.4 Estimate Emissions Using SMOKE 

This component was performed by researchers at the University of North Carolina (UNC). Please 

refer to other documentation in regards to the details of performing this component of the study. 

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2.5 Prepare Emissions Estimates Summaries from SMOKE Reports 

Researchers at UNC provided SMOKE reports to the study team for use in our efforts to summarize 

the on-road mobile source emissions estimates. The study team developed Excel workbooks with 

Visual Basic for Applications (VBA) scripting to facilitate the ingestion of the SMOKE reports. 

Further, VBA scripts were developed to prepare a number of standard report summaries as well as 

to provide a limited ad-hoc reporting capability so that a user of the Excel workbooks could prepare 

their own report summaries from the SMOKE reports. 

 

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3.0 RELATIVE HUMIDITY (RH) AND REID VAPOR PRESSURE (RVP) 

SENSITIVITY EXPERIMENTS 

MOVES2010a requires the identification of fuel seasons for purposes of generating emissions 

factors. Fuel seasons should be chosen such that the groupings have similar fuel characteristics 

and meteorology. Because the MOVES modeling system was just being introduced to the modeling 

community at the start of this study, it was not clear how the choice of fuel season might impact the 

MOVES2010a results. SEMAP judged that the two critical inputs to the choice of how fuel seasons 

were chosen were the RH and RVP. Using default data supplied with the MOVES modeling system, 

MOVES2010a was run in emissions inventory mode for an April and May 2007 weekday to estimate 

emissions (tons/day) for CO, NOX, VOC, SO 

2

, PM10, and PM2.5. MOVES2010a was also run using 

data supplied by the SEMAP states that was used in-lieu of the MOVES2010a default data for the 

same period and pollutants. 

The RH sensitivity simulations included the following: 

• For April 2007, Mecklenburg County, NC; 

a. Base simulation at 48.98% relative humidity fixed for all hours of the day, 

b. Simulation using national defaults (this was for comparison purposes to estimates 

derived using the SEMAP states-supplied data), 

c. Four sensitivity simulations at +5% RH and +10% RH added to the base simulation, 

• For May 2007, Mecklenburg County, NC; 

a. Base simulation at 55.37% relative humidity fixed for all hours of the day, 

b. Simulation using national defaults (this was for comparison purposes to estimates 

derived using the SEMAP states-supplied data), and 

c. Four sensitivity simulations at +5% RH and +10% RH added to the base simulation. 

The results of the RH runs were compiled into an Excel workbook (on the data disk 

semap/rh_rvp_sensitivity_experiments/37119_2007_04_ozone_emissions_estimates_RH_comparis

on.xls). The exhaust, evaporative, and total emissions estimates for CO, NOX, VOC, SO 

2

, PM10, and 

PM2.5 are compiled in the “RH Emissions Summary” worksheet for both gasoline and diesel fueled 

vehicles. Further, the percent change in emissions estimates due to a +5% and +10% change in RH 

from the base simulation (i.e., 49.98% RH for April 2007 and 55.37% RH for May 2007) were 

provided. The choice of +5% and +10% RH ranges were made by SEMAP and reflect a gross range 

of RH changes seen across the year. A summary of the emissions estimates changes is as follows: 

• For diesel and gasoline VOC, SO 

2

, PM10 and PM2.5, the emissions differences due to +10% 

RH change are non-existent (PM10 and PM2.5 are not affected by changes in RH) or 

negligible (SO 

2

 has less than a 0.01 tons/day difference in emissions which equates to less 

than a 1% difference in emissions, and VOC has less than a 0.20 tons/day difference in 

emissions which equates to less than a 1% difference in emissions whether they are 

evaporative or exhaust); 

• For diesel CO, the emissions differences are negligible due to a +10% RH change (CO has 

less than a 0.20 tons/day difference in emissions which equates to about a 1% difference in 

emissions); 

• For gasoline CO, the emissions differences are small due to a +10% RH change (though CO 

has about a 8 tons/day swing in emissions due to +10% RH change, this equates to less 

than +1.6% overall difference in the emissions); 

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• For diesel NOX, a +5% RH change results in about a +0.50 tons/day change in the emissions 

which equates to about +1.5% change in the emissions. At a +10% RH change, NOX

emissions change by about +1.0 tons/day which equates to about +3% change in the 

emissions. 

• For gasoline NOX, a +5% RH change results in about a +0.75 tons/day change in the 

emissions which equates to about +1.5% change in the emissions. At a +10% RH change, 

NOX emissions changes show a non-linear response in May 2007 with the range of -0.90 

tons/day to +1.7 tons/day change and a more linear response in April 2007 with a +1.5 

tons/day change, which equates to roughly +3% of the base emissions. 

For diesel and gasoline VOC, CO, SO 

2

, PM10 and PM2.5, a +5% RH change or even a +10% RH 

change results in emissions changes that will likely not impact the air quality modeling results. 

However, for NOX a +5% RH change, diesel and gasoline NOX emissions estimates change by 

+1.25 tons/day (+1.35% -- note that an increase in RH results in a decrease in NOX). 

The RVP sensitivity simulations included the following: 

• For April 2007, Mecklenburg County, NC; 

a. Base simulation at 48.98% RH and RVP of 13.5 psi (ran during RH simulation), 

b. Two sensitivity simulations where RVP is set to 15.0 psi and 9.0 psi, 

• For May 2007, Mecklenburg County, NC; 

a. Base simulation at 55.37% RH and RVP of 9.0 psi (ran during RH simulation), and 

b. Two sensitivity simulations where RVP is set to 13.5 psi and 7.8 psi. 

The choice of the RVP range was made by SEMAP and reflects the range of RVPs that are seen the 

fuels across the SEMAP states. The results of the RVP runs were compiled into the attached Excel 

workbook on the data disk 

semap/rh_rvp_sensitivity_experiments/37119_2007_04_ozone_emissions_estimates_RVP_compari

son.xls). The exhaust, evaporative, and total emissions estimates for CO, NOX, VOC, SO 

2

, PM10, 

and PM2.5 are compiled in the “RH Emissions Summary” worksheet for gasoline fueled vehicles as 

diesel is not affected by RVP. Although results for April 2007 with RVP values of 15.0, 13.5, and 9.0

psi and for May 2007 with RVP values of 13.5, 9.0 and 7.8 psi are compiled in the Excel workbook, 

the focus is only on a summary of the comparison for April 2007 between RVP values of 15.0 and 

13.5 psi and for May 2007 between RVP values of 9.0 and 7.8 psi as those are the RVP values of 

interest for the fuel seasons of concern. A summary of the emissions estimates changes is as 

follows: 

• For April 2007 for RVP change of 15.0 psi to base 13.5 psi; 

a. Exhaust VOC, SO 

2

, PM10, and PM2.5 have negligible (VOC) or no change (SO 

2

, PM10, 

PM2.5) due to a change in RVP, 

b. CO emissions decrease with decreasing RVP by 25% (~160 tons/day) of the base CO 

emissions, 

c. NOX emissions decrease with decreasing RVP by about 2% (~1 ton/day) of the base 

NOX emissions, 

d. Evaporative VOC emissions decrease with decreasing RVP by about 50% (~15 

tons/day) of the base evaporative VOC emissions, 

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e. Total VOC emissions decrease with decreasing RVP by about 28% (~15 tons/day) of the 

base total VOC emissions, 

• For May 2007 for RVP change of base 9.0 psi to 7.8 psi; 

a. Exhaust VOC, SO 

2

, PM10, and PM2.5 have negligible (VOC) or no change (SO 

2

, PM10, 

PM2.5) due to a change in RVP, 

b. CO emissions decrease with decreasing RVP by 1.3% (~6 tons/day) of the base CO 

emissions, 

c. NOX emissions decrease with decreasing RVP by about 1.3% (~1 ton/day) of the base 

NOX emissions, 

d. Evaporative VOC emissions decrease with decreasing RVP by about 12% (~2 tons/day) 

of the base evaporative VOC emissions, and 

e. Total VOC emissions decrease with decreasing RVP by about 5% (~2 tons/day) of the 

base total VOC emissions. 

The greatest impact to emissions occurs in the RVP change from 15.0 psi to 13.5 psi with CO and 

VOC exhibiting definite sensitivity. There is less of an impact to CO and VOC emissions when the 

RVP changes from 9.0 psi to 7.8 psi. However, in both cases NOX has about a 1.0 ton/day 

sensitivity which may be important for modeling and policy purposes. 

Though the results of the experiments indicate that there are important sensitivities to changes in RH

and RVP and thus multiple fuel season definitions may be in order, SEMAP determined that a 

summer (i.e., May through September) and winter (January through April and October through 

December) were sufficient for the purposes of the study especially given the significant processing 

times that are necessary to run MOVES2010a. 

 

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4.0 ESTIMATE MOVES AND SMOKE METEOROLOGY 

4.1 DATA INPUTS 

MOVES2010a and SMOKE require estimates of ambient temperature and relative humidity. The 

MET4MOVES component of the SMOKE-MOVES Integration Tool (EPA, 2010) was used to 

facilitate the preparation of the MOVES2010a and SMOKE meteorological data sets. 

MET4MOVES requires the following primary inputs: 

• Representative county cross-reference; 

• Fuel month cross-reference; 

• Gridded surrogates; and 

• Meteorology-Chemistry Interface Processor (MCIP) data sets. 

The representative county-cross reference file was prepared based on information that was supplied 

by SEMAP (Boylan, 2010). Table 4-1 lists the names of the representative counties and the number 

of counties assigned to the representative counties. The 926 counties for the SEMAP states were 

assigned to one of the 39 representative counties. The complete assignment details can be found in 

the SMOKE data files (i.e., mcref_semap_SS_2007.txt where SS is the state abbreviation) located 

on the data disk in the directory semap/edss/data_semap/ge_dat/mcref_files. 

Table 4-1. Names of representative counties by state and the number of counties assigned to the 

representative counties. 

State Representative 

County FIPS Code Number of Counties Assigned 

Alabama Jefferson 01073 2 

Montgomery 01101 65 

Florida 

Escambia 12033 62 

Hillsborough 12057 2 

Miami-Dade 12086 3 

Georgia 

Barrow 13013 7 

Chatham 13051 114 

Floyd 13115 25 

Fulton 13121 13 

Kentucky 

Bullitt 21029 1 

Fayette 21067 114 

Jefferson 21111 1 

Kenton 21117 3 

Oldham 21185 1 

Mississippi Hinds 28049 82 

North Carolina 

Cumberland 37051 40 

Davidson 37057 1 

Duplin 37061 52 

Forsyth 37067 1 

Guilford 37081 1 

Mecklenburg 37119 2 

Orange 37135 1 

Wake 37183 2 

South Carolina Spartanburg 45083 46 

Tennessee 

Davidson 47037 1 

Fayette 47047 2 

Hamilton 47065 1 

KNOX 47093 7 

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State Representative 

County FIPS Code Number of Counties Assigned 

Madison 47113 66 

Marion 47115 1 

Putnam 47141 7 

Rutherford 47149 4 

Shelby 47157 1 

Sullivan 47163 5 

Virginia 

Albemarle 51003 107 

Henrico 51087 7 

Prince William 51153 10 

York 51199 11 

West Virginia Kanawha 54039 55 

The fuel month cross-reference file was prepared based on information supplied by SEMAP (Boylan, 

2010). Two fuel seasons, summer (i.e., May through September) and winter (January through April 

and October through December), were assigned to each representative county. The contents of 

these data sets can be viewed in the files semap/edss/data_semap/ge_dat/fuelmonth_semap_SS.txt 

where SS is the state abbreviation. 

The gridded surrogates were provided as part of the SMOKE distribution. As recommended in the 

User’s Guide (EPA, 2010), surrogates 100 (i.e., population) and 240 (i.e., total road miles) were 

used to derive the representative county meteorology by fuel season. The master surrogate data set 

can be found in semap/edss/data_semap/ge_dat/ SRGDESC.MOVES.NC, which points to the actual 

surrogate files semap/edss/data_semap/ge_dat/Srg_12km_MOVES_SEMAP/USA_100_NOFILL.txt 

and semap/edss/data_semap/ge_dat/Srg_12km_MOVES_SEMAP/USA_240_FILL.txt. 

The MCIP data sets were provided by UNC for each day in 2007. The UNC-supplied MCIP data 

files were post processed to reduce their considerable size to something that was more 

manageable. The post-processed MCIP data sets contain only the ambient temperatures at two 

meters, the pressure, and the water vapor mixing ratio (a surrogate for RH) from the first layer of the 

modeling domain. The actual MCIP data sets can be found in the directory 

semap/edss/data_semap/met with the naming nomenclature of METCOMBO_2007DDD where DDD 

is the Julian day of the file. All MCIP files are in netCDF structures. 

4.2 DATA OUTPUTS 

MET4MOVES produces three output data files: 

• SMOKE-ready meteorological data file; 

• MOVES-ready meteorological file; and 

• Log file. 

The SMOKE-ready meteorological data set contains the temperature and relative humidity estimates 

by county, fuel season month, and calendar month necessary for input to SMOKE. The MOVESready meteorological data set contains the average relative humidity and twenty-four hourly 

temperature estimates by representative county, fuel season month, and temperature profile 

necessary for input to MOVES. The log file contains runtime and error messages from a 

MET4MOVES run and is useful for diagnosing problems should they occur. Examples of the 

meteorological data sets generated by MET4MOVES for this study can be found in 

semap/edss/data_semap/met_out/12k. The MOVES-ready files are named 

MOVES_12km_2007001-2007365_??.txt, and the SMOKE-ready files are named 

SMOKE_12km_2007001-2007365_??.txt where ?? is the two letter state abbreviation. 

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4.3 RUN SCRIPTS 

MET4MOVES is run through Linux C-shell command scripts. Figure 4-1 provides an overview of the 

script names and the primary input and output definitions that are required. Before the user can run 

these scripts, the scripts must be modified to accommodate the directory structure of the user’s 

computer platform. The scripts to run MET4MOVES are located in the directory 

semap/edss/subsys/smoke/scripts/run_semap and have the naming convention of 

run_met4moves.MOVES.semap.??.bat where ?? is the two letter state abbreviation. The following 

command is an example of how to run the script for Alabama: 

% ./run_met4moves.MOVES.semap.AL.bat 

This command will produce copious output so it may advisable to capture this output to log files, 

which can be viewed at the user’s convenience: 

% (./run_met4moves.MOVES.semap.AL.bat > LOG) >& LOG.error 

 

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Figure 4-1. Overview of the C-shell scripts to run MET4MOVES. ?? in the file names refer to the 

two letter state abbreviation. 

 

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5.0 ESTIMATE EMISSIONS FACTORS USING MOVES2010A 

5.1 DATA INPUTS 

The study team prepared MOVES2010a input files for thirty-nine (39) representative counties in the 

SEMAP domain for two fuel seasons (i.e., winter and summer) for the 2007 base year. The input 

files were prepared for use with the emissions rate calculation mode of MOVES2010a. 

The effort included converting default MOBILE6.2 inputs to MOVES2010a inputs using the MOBILE6 

to MOVES2010 conversion tools (OTAQ, 2010c). We also integrated MOVES2010a input files that 

were developed by a variety of organizations from the SEMAP states. 

For each representative county, the following six files were prepared for input to the MOVES2010a 

modeling system: 

• Fuel formulation; 

• Fuel supply; 

• VMT; 

• Inspection and Maintenance (I/M) program; 

• Age distribution; and 

• Vehicle population. 

MOVES2010a also requires the following input data files, the development of which is described 

Chapter 4: 

• Representative county cross-reference; 

• Fuel month cross-reference; and 

• MOVES-ready meteorology. 

The six files that were developed during this component of the study were based on multiple 

exchanges of information between representatives from the SEMAP states and the study team. 

Each file went through multiple iterations before a final set of data files was prepared for each of the 

thirty-nine representative counties. The formats of these files are described in EPA (2010). 

The fuel formulation file contains the characteristics of each fuel, gasoline and diesel, used in the 

representative county including such parameters as RVP, fuel sulfur content, and ethanol content. 

The fuel supply file identifies the specific fuel used during each month of the year and the market 

share that fuel has for each representative county. The VMT file defines the annual VMT by major 

vehicle category for each representative county. The I/M program file defines the inspection and 

maintenance program characteristics for each representative county that was in effect during 2007. 

If no I/M program was in existence, this file is empty. The age distribution file contains the fraction of 

vehicles by vehicle category and model year that comprise the fleet for the base year (i.e., 2007) and

the prior thirty years. The vehicle population contains the vehicle counts for each of the thirteen 

MOVES vehicle categories. 

The input data files can be found on the data disk in the directory semap/smoke_moves_input/?? 

where ?? is the two letter state abbreviation. The naming convention for the input files is as follows 

(where SS is the two digit state code [e.g., 01 for Alabama] and CCC is the three digit county code 

[e.g., 073 for Jefferson County]): 

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• SSCCC_FuelFormulation.csv; 

• SSCCC_FuelSupply.csv; 

• SSCCC_HPMSVTypeVMT.csv; 

• SSCCC_IMCoverage.csv; 

• SSCCC_sourceTypeAgeDistribution.csv; and 

• SSCCC_sourceTypePopulation.csv. 

5.2 QUALITY ASSURANCE OF THE MOVES INPUTS 

The MOVES data input files were delivered to the SEMAP quality assurance contractor and 

representatives from the SEMAP states for review and comment. Though the review of the MOVES 

data input files was expected to take only two or three iterations, in the end, many iterations were 

required over the course of some fifteen months before the MOVES data input files were completely 

correct. This was due in part to problems with the MOVES2010a modeling system itself, in part 

because the SEMAP states had evolving needs that required changes to the data, and in part due to 

issues with the study team not initially fully understanding how MOVES2010a ingested data. 

5.3 MOVES DATA IMPORT AND RUN SPECIFICATION SCRIPTS

MOVES2010a requires that XML script files be constructed in order to run the modeling system. 

The SMOKE-MOVES Integration Tool (EPA, 201) provides the perl script tools necessary to create 

the XML scripts to import the data files described in Section 5.1 and the XML scripts to run the 

MOVES2010a modeling system. Figure 5-1 provides an overview of the data inputs and scripts that 

are necessary to construct the XML files necessary to run the MOVES2010a modeling system. 

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Figure 5-1. Overview of the data inputs and C-shell scripts used to construct the MOVES2010a 

modeling system data import XML and run specification XML scripts. ?? in the file names refer to 

the two letter state abbreviation. SSCCC in the file names refer to the five digit state-county FIPS 

identifier for the representative county. 

For each representative county, the study team built the two input files ??_runcontrol and 

??_repcounty. Further, the study team built the C-shell script 

smoke_moves_runspec_generator.csh to help automate the process of constructing the XML 

scripts. The perl script runspec_generator_v0.31_22Mar2011.pl was the most recent script that was 

available in the SMOKE-MOVES Integration Tool at the time this project was proceeding. 

In order to run the C-shell script to construct the XML files suitable to run the MOVES2010a 

modeling system, the user must modify the two input files, ??_runcontrol and ??_repcounty, to 

conform to the layout of his/her computational platform. The C-shell script is run as follows: 

% source smoke_moves_runspec_generator.csh 

The output of this is a set of XML data importer scripts, XML run specification scripts, C-shell scripts, 

and CSV files, which are output to the directories specified in Figure 5-1. The CSV files represent 

the MOVES-formatted meteorology that is utilized by the XML data importer scripts. 

Though the SMOKE-MOVES Integration Tool prepares the necessary C-shell scripts to run the XML 

files, the result of the effort has all representative counties being run on one platform. In order to 

spread the MOVES2010a runs over multiple machines so that the runs are computationally more 

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efficient, the study team split the SEMAP_??_2007importer.csh and SEMAP_??_2007runspec.csh 

C-shell scripts into multiple C-shell scripts – one for each representative county; hence, there exist

thirty-nine importer C-shell scripts and thirty-nine run specification C-shell scripts that could be run in 

parallel on thirty-nine different computational cores. The naming convention used to identify the split 

C-shell scripts is as follows: 

• SSCCC_importer_MACHINE_CORE.csh; and 

• SSCCC_runspec_MACHINE_CORE.csh. 

Where SSCC is the five digit FIPS state-county code, MACHINE is the name of the computational 

platform, and CORE identifies the surrogate upon which CPU that the C-shell script is to run on the 

MACHINE. 

5.4 QUALITY ASSURANCE OF THE MOVES XML AND C-SHELL SCRIPTS 

The MOVES XML and C-shell scripts were delivered to the SEMAP quality assurance contractor and 

representatives from the SEMAP states for review and comment. Fortunately, the review of the 

MOVES XML and C-shell scripts took only two iterations. OTAQ, the developer of the MOVES 

modeling system, released at least two new versions of the SMOKE-MOVES Integration Tool run 

specification perl scripts which were used to repeat the development of the MOVES XML and Cshell scripts descried in Section 5.3. 

5.5 RUNNING MOVES2010A 

After the XML and C-shell scripts were constructed, it was possible to actually run the MOVES2010a 

modeling system. The first step to running the modeling system was to import the data described in 

Section 5.1. Importing of the data was performed by executing the following command, one each for 

the thirty-nine files on the appropriate MACHINE and CORE: 

% (source SSCCC_importer_MACHINE_CORE.csh > LOG) >& LOG.error 

The method of running the C-shell script in this manner allowed the capture of the copious output 

that was generated during the import of data into the MOVES2010a MySQL data bases, which the 

user can view at his/her leisure and was useful for diagnosing problems when they arose. 

After all thirty-nine C-shell importer scripts were run, the effort to generate the actual on-road mobile 

source emissions factors was performed. This was accomplished by running the following 

command, one each for the thirty-nine files on the appropriate MACHINE and CORE: 

% (source SSCCC_runspec_MACHINE_CORE.csh > LOG) >& LOG.error 

The method of running the C-shell script in this manner allowed the capture of the copious output 

that was generated during the generation of on-road mobile source emissions factors that were 

stored in the MOVES2010a MySQL data bases, which the user can view at his/her leisure and was 

useful for diagnosing problems when they arose. 

5.6 DATA OUTPUTS 

All MOVES2010a input data bases, which resulted from running the C-shell importer scripts, were 

stored in MySQL data bases. There are hundreds of input data bases per representative county as 

this is a necessary requirement of the MOVES2010a modeling system so that the range of 

meteorological conditions were captured. All MOVES2010a emissions factors that were created by 

running the C-shell run specification scripts were stored in MySQL data bases, one per 

representative county for a total of thirty-nine MySQL output data bases. Each MySQL input and 

output data base contained multiple data tables. Descriptions of the contents of the MOVES2010a 

MySQL data bases can be found in OTAQ (2010a). The resulting MOVES2010a input MySQL data 

bases were archived on the data disk in the directory semap/2007_MOVES_MySQL_inputs/?? 

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where ?? is the two letter state identifier. Similarly, the resulting MOVES2010a output MySQL data 

bases were archived on the data disk in the directory semap/2007_MOVES_MySQL_outputs/?? 

where ?? is the two letter state identifier. 

5.7 GENERATION OF THE SMOKE-READY EMISSIONS FACTORS

Until this point, all modeling was performed on Linux machines. Due to unresolved difficulties in 

getting the emissions factors extracted from the Linux based MySQL output data bases using the 

perl scripts supplied with the SMOKE-MOVES Integration Tool (EPA, 2010), all MySQL output data 

bases were transported to a Windows platform where these difficulties were nonexistent. 

Figure 5-2 provides an overview of the input file and the perl script that was used to extract the 

emissions factors from the MySQL output data bases to create the SMOKE-ready emissions factors 

files. The study team built the dbFile_SS, where SS is the two digit state FIPS code, which 

contained the necessary information to run the SMOKE-MOVES Integration Tool (EPA, 2010) 

extraction perl scripts – moves2smkEF_v0.32_24Aug2011.pl and smkEFsum_v0.2_02Aug2011.pl. 

The perl script to extract the MOVES2010a emissions factors from the MySQL output data bases 

was run as follows: 

% perl moves2smkEF_v0.32_24Aug2011.pl –output all dbFile_SS.inp 

where SS is the two digit FIPS state identifier. The output of this perl script was the SMOKE-ready 

emissions factors and was stored in multiple CSV files. 

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Figure 5-2. Overview of the SMOKE-MOVESIntegration perl script and input file that was 

necessary to extract the emissions factors from the MOVES2010a MySQL output data bases. SS 

in the file names refer to the two digit state FIPS identifier. SSCCC in the file names refer to the 

five digit state-county FIPS identifier for the representative county. MM in the file names refer to 

the two digit fuel month identifier. 

5.8 QUALITY ASSURANCE OF THE MOVES OUTPUT EMISSIONS FACTORS 

Excel workbooks with VBA scripts were developed to assist in review of the MOVES2010a 

emissions factors. The workbooks are located on the data disk in the directory 

semap/moves_emissions_factors_qa. Users must be familiar with the VBA scripting language in 

order to utilize these workbooks to facilitate review of other MOVES2010a emissions factors. These 

example workbooks contain the CSV files as described in Section 5.7 for the states of Alabama and 

North Carolina (e.g., worksheet tab ‘rateperdistance_smoke_37051_200’). After the CSV files have 

been loaded into a worksheet, a VBA script was run to generate graphics of the emissions factors for 

each SCC. The graphics provided a quick means of reviewing the thousands of emissions factors 

that were estimated. These workbooks were delivered to representatives of the SEMAP states and 

the SEMAP quality assurance contractor for review. 

Figure 5-3 provides an example of the running exhaust VOC rate per distance emissions factors 

(g/mile) for the 2007 winter season for light duty diesel vehicles on urban interstates for Mecklenburg 

County, North Carolina by temperature and speed bin. Figure 5-4 provides an example of the 

crankcase start exhaust VOC rate per vehicle emissions factors (g/vehicle/hour) for the 2007 winter 

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season for light duty gasoline vehicles on all road types for Jefferson County, Alabama by hour and 

temperature. 

Figure 5-3. Running exhaust VOC rate per distance emissions factors (g/mile) for the 2007 winter 

season for light duty diesel vehicles on urban interstates for Mecklenburg County, North Carolina 

by temperature and speed bin. 

Figure 5-4. Crankcase start exhaust VOC rate per vehicle emissions factors (g/vehicle/hour) for 

the 2007 winter season for light duty gasoline vehicles on all road types for Jefferson County, 

Alabama by hour and temperature. 

As was expected with any new modeling system, issues were found in the initial stages of running 

the MOVES2010a modeling system in regards to the emissions factors it estimated. The graphics 

provided a quick means to identify the issues from which corrections were made to the input data, 

and through the help of the MOVES developers, from which corrections were made to the 

MOVES2010a modeling system. Indeed, OTAQ, the developer of the MOVES modeling system, 

continued to make corrections to MOVES2010a as late as the first quarter of 2012. 

1

3

5

7

9

11

13

15

0.00E+00

2.00E-01

4.00E-01

6.00E-01

8.00E-01

1.00E+00

5

15

25

35

45 55 65 75 85 95

speed bin

g/mile

temperature (F)

8.00E-01-1.00E+00

6.00E-01-8.00E-01

4.00E-01-6.00E-01

2.00E-01-4.00E-01

0.00E+00-2.00E-01

20

40

60

80

0

0.005

0.01

0.015

0.02

0.025

0.03

0.035

0.04

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

temperature (F)

g/veh/hr

hour

0.035-0.04

0.03-0.035

0.025-0.03

0.02-0.025

0.015-0.02

0.01-0.015

0.005-0.01

0-0.005

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Once the emissions factors had been approved by SEMAP, they were delivered to researchers at 

the UNC for their use in estimating on-road mobile source emissions using SMOKE. The data that 

were delivered to UNC are contained on the data disk in the directory 

semap/moves2smoke_windows. The naming convention of the zip archives that were delivered to 

UNC was ??_2007_MOVES2010a_corrected.zip where ?? is the two letter state abbreviation. 

These archives also contain the input data files and perl scripts described in Figure 5-2. 

 

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6.0 DEVELOPMENT OF THE EMISSIONS ESTIMATES REPORTS

Researchers at UNC delivered to the study team the SMOKE reports that were output by the 

SMOKE modeling system. In order to better utilize these data, Excel workbooks with VBA scripts 

were developed to ingest the SMOKE reports, prepare standard reports, and provide the capability 

to the user to develop some limited ad-hoc reports. The Excel emissions summary workbooks can 

be found on the data disk in the directory semap/smoke_emissions_summaries. There is one Excel 

workbook for each SEMAP state. 

6.1 OVERVIEW OF WORKSHEETS 

The SMOKE emissions summary Excel files are macro-enabled workbooks that contain the on-road 

emissions estimates summaries from the SMOKE emissions reports from UNC. Each workbook 

contains the following worksheets: 

• State Summary Report Def - contains information used by an embedded Excel macro to 

build the emissions estimates summary by state for the major vehicle classifications (State 

Summary report) 

• County Summary Report Def - contains information used by an embedded Excel macro to 

build the emissions estimates summary by state and county for the major vehicle 

classifications (State Summary report) 

• Ozone Season Day Report Def - contains information used by an embedded Excel macro to 

build the emissions estimates summary by state for the major vehicle classifications (State 

Summary report) 

• User Poll List - contains the list of pollutants to include in each report 

• SCC - contains a list of SCCs and their description 

• AttLookUp - this is a scratch worksheet used by embedded macros 

• Month?? – monthly summary of the all the SMOKE reports that UNC provided where ?? is 

month of the year (tons/month) 

• State Summary - contains the annual emissions summary for the state (tons/year) 

• State SCC Summary – contains the annual emissions summary for the state by SCC 

(tons/year) 

• County Summary - contains the annual emissions summary by state-county (tons/year) 

• County SCC Summary – contains the annual emissions summary by state-county and SCC 

(tons/year) 

• Annual State Report Summary - contains the annual emissions estimates summary by major 

vehicle category by state (tons/year) 

• Annual County Report Summary - contains the annual emissions estimates summary by 

major vehicle category by state and county (tons/year) 

• Ozone Season Day Summary - contains the emissions estimates summary for an average 

ozone season day by major vehicle category by state (tons/day) 

6.2 OVERVIEW OF EMBEDDED VBA MACROS 

The workbook has the following embedded macros (press Alt-F8) to see a list of these macros: 

• CreateUserReportGroupByStateCounty - this macro creates a report based on user-defined 

parameters. Example worksheets that contain the user-defined parameters include: 

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o State Summary Report Def; 

o County Summary Report Def; 

o Ozone Season Day Report Def 

• DeleteSheet - a macro to delete a worksheet 

• EmissionsByCounty - macro that creates the summaries contained in: 

o County Summary; 

o County SCC Summary 

• EmissionsByState - macro that creates the summaries contained in: 

o State Summary; 

o State SCC Summary 

• ImportSMOKEReports - macro to import the SMOKE reports 

If the user desires to rerun the reporting macros (i.e., EmissionsByState, EmissionByCounty, or 

CreateUserReportGroupByStateCounty), the workbook has to have the macros enabled (which is 

done when the user specifies such when the workbook is first opened). The user then needs to 

press Alt-F8 to get a list of report macros to run, select the report macro, and press run. 

For the report macro CreateUserReportGroupByStateCounty, the system will ask for the name of the 

worksheet (e.g., State Summary Report Def; County Summary Report Def; Ozone Season Day 

Report Def) that contains the information to generate the user-defined report. The system will also 

ask if the user wants to aggregate the pollutants. If the user responds “Yes," the system will use the 

chemical list from Column B of the User Poll List worksheet. If the user responds "No," the system 

will use the chemical list from Column A of the User Poll List worksheet. 

For the report macros EmissionsByState and EmissionsByCounty, The system will ask if the user 

wants to aggregate the pollutants. If the user responds "Yes," the system will use the chemical list 

from Column B of the User Poll List worksheet. If the user responds "No," the system will use the 

chemical list from Column A of the User Poll List worksheet. 

6.3 USER POLL LIST WORKSHEET 

The User Poll List worksheet has two columns. The chemicals in Column A name all the pollutants 

that exist in the UNC data sets and the order that the chemicals are to be reported in the Month01 

through Month12 worksheets. Column B lists the reduced set of "aggregated" chemicals and the 

order that they are to appear in summary reports. The embedded macros use Column A or Column 

B based on the user's response to whether to aggregate the chemicals (use Column B) or not to 

aggregate the chemicals (use Column A). 

The chemicals in Column B can be used to aggregate other values into a single value. In the current 

worksheet, NOX is estimated as 1.533*NO + NO2. Another example how this aggregation can be 

applied would be to make an entry in Column B for PM10 as follows: 

PM10=PMC+PMFINE 

In order for this to appear in the reports, the user would have to rerun the macros as discussed in 

Section 6.2 

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6.4 USER-DEFINED REPORTS 

The worksheets -- State Summary Report Def; County Summary Report Def; and Ozone Season 

Day Report Def -- contain information that is used by the embedded macro 

"CreateUserReportGroupByStateCounty " to prepare emissions estimates summary reports. In 

order to run the macro, certain cells need to be populated by the user as follows: 

• C1 - name of the report (a worksheet is created with this name and can be no longer than 31 

characters -- an Excel limitation). 

• G1 - keyword STATE or COUNTY (STATE indicates that the macro will estimate the 

emissions for the entire state; COUNTY indicates that the macro will estimate the emissions 

by state-county combination). 

• C2, D2, E2, ..., N2 - the names of the Month?? worksheets to use in compiling the emissions 

estimates report. 

• C3 - units of the emissions estimates (e.g., tons/day). 

• C4 - emissions divisor (this divisor [d] is applied to all emissions estimates [e] in the form of 

[e] divided by [d]. for example, if you wanted an annual average day emissions estimate, in 

Cells C2 through N2 you would list Month01, Month02, ..., Month12 and in Cell C4 you would 

enter 365. 

• A5, B5, C5, ...., n - category names for the grouped SCCs. 

• A6, A7, A8, ... n - for each category listed in A5, B5, C5, and so on, the list B6, B7, B8, ... n 

of SCCs that are to be included in the grouping. If a “?” is specified in the SCC sequence, it 

is treated as a wildcard thus matching any value in that position. For any SCC that is not 

captured, the system will report these emissions estimates under the "Other" category and 

will list these SCCs on the report definition worksheet. 

6.5 EXECUTION SPEED OF MACROS 

The embedded macros do take time to run depending on the complexity of the report that is being 

generated. On a four-core Windows 7 machine, with each CPU operating at 2.4GHz, it takes 

roughly sixty minutes each for the EmissionsByState and EmissionsByCounty macros to run to 

completion. For the example user-defined reports included in the workbooks, the 

CreateUserReportGroupByStateCounty macro takes anywhere from thirty minutes to seventy-five 

minutes to run. 

In each case, the status bar, which is located in the lower left-hand corner of the Excel screen, 

indicates the worksheet, state/county, SCC, and chemical that the macro is currently summarizing. 

If at some point the user decides to run an embedded macro and the status bar does not change 

every five or ten seconds, it is highly likely that Excel has locked up and will need to be restarted. 

Therefore, it is imperative that as the user completes each task with each workbook, that the 

workbook be saved. 

6.6 EMISSIONS ESTIMATES SUMMARIES 

Summaries of the annual, SEMAP state-wide emissions estimates were prepared. Table 6-1 shows 

the annual on-road mobile source emissions estimates by state for the on-network and off-network 

contributions by pollutant for gasoline fueled vehicles. Table 6-2 shows the annual on-road mobile 

source emissions estimates by state for the on-network and off-network contributions by pollutant for 

diesel fueled vehicles. Table 6-3 shows the annual on-road mobile source emissions estimates by 

state for the on-network and off-network contributions by pollutant for gasoline and diesel fueled 

vehicles. Table 6-4 shows the annual on-road mobile source emissions estimates by state and 

vehicle category. Table 6-5 shows the ozone season day on-road mobile source emissions 

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estimates by state and vehicle category. Figure 6-1 shows the percent contribution by state and fuel 

to the annual on-road mobile source emissions estimates. 

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Table 6-1. Annual on-road mobile source emissions summary by state and network from gasoline fueled vehicles 

State Network CO NOX VOC- EVP VOC- EXH VOC- TOT SO2 NH3 PM25 EXH PM25 BRAKE PM25 TIRE PM25- TOT PM

E

AL Off 387,407 25,615 11,619 33,446 45,065 52 - 327 - - 327 

On 497,401 71,523 6,603 19,439 26,042 1,173 2,703 779 382 106 1,266 State Total 884,807 97,138 18,222 52,885 71,106 1,225 2,703 1,106 382 106 1,593 1

FL Off 809,843 76,911 41,592 82,665 124,257 137 - 584 - - 584 

On 1,694,406 235,921 24,613 60,164 84,777 4,157 9,329 1,873 1,368 323 3,563 2State Total 2,504,249 312,832 66,205 142,830 209,034 4,295 9,329 2,457 1,368 323 4,147 2

GA Off 609,671 51,131 20,688 59,619 80,307 177 - 665 - - 665 

On 1,244,981 173,157 15,373 53,539 68,912 5,567 5,144 1,793 609 165 2,566 1State Total 1,854,653 224,288 36,061 113,158 149,220 5,744 5,144 2,458 609 165 3,232 2

KY Off 340,582 19,073 7,523 27,367 34,890 42 - 360 - - 360 

On 345,203 52,819 4,188 12,254 16,442 758 2,075 703 209 65 977 State Total 685,785 71,892 11,711 39,621 51,332 800 2,075 1,062 209 65 1,337 1

MS Off 251,279 16,132 7,913 20,609 28,522 32 - 203 - - 203 

On 255,223 38,788 3,293 8,777 12,070 651 1,703 394 161 55 610 State Total 506,503 54,920 11,206 29,385 40,592 683 1,703 598 161 55 814 

NC Off 904,378 39,809 24,160 58,037 82,197 94 - 743 - - 743 

On 1,174,460 144,496 9,681 35,874 45,555 2,098 4,879 1,982 372 134 2,488 2State Total 2,078,838 184,305 33,840 93,912 127,752 2,192 4,879 2,725 372 134 3,231 2

SC Off 296,250 18,735 8,552 22,732 31,283 42 - 221 - - 221 

On 427,817 56,305 4,450 13,519 17,969 999 2,189 585 248 71 904 State Total 724,067 75,041 13,001 36,251 49,252 1,041 2,189 806 248 71 1,124 

TN Off 518,448 28,711 17,466 36,796 54,262 66 - 450 - - 450 

On 646,534 87,701 5,780 19,630 25,410 1,290 3,096 1,012 211 77 1,300 1State Total 1,164,983 116,412 23,246 56,426 79,671 1,356 3,096 1,462 211 77 1,750 1

VA Off 643,629 33,501 15,388 51,011 66,399 64 - 708 - - 708 

On 522,601 76,084 7,917 17,137 25,054 1,030 3,884 1,328 244 104 1,676 1State Total 1,166,230 109,585 23,305 68,148 91,453 1,093 3,884 2,036 244 104 2,384 2

WV Off 181,756 8,379 3,399 12,392 15,791 22 - 174 - - 174 

On 166,960 22,464 1,604 5,195 6,800 371 833 328 82 26 436 State Total 348,716 30,843 5,004 17,587 22,591 393 833 503 82 26 611 

SEMAP Off 4,943,243 317,997 158,299 404,674 562,973 728 - 4,436 - - 4,436 4

On 6,975,587 959,259 83,502 245,528 329,030 18,094 35,836 10,776 3,885 1,126 15,787 11Total 11,918,830 1,277,256 241,801 650,202 892,003 18,822 35,836 15,212 3,885 1,126 20,223 16

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Table 6-2. Annual on-road mobile source emissions summary by state and network from diesel fueled vehicles (to

State Network CO NOX VOC- EVP VOC- EXH VOC- TOT SO2 NH3 PM25 EXH PM25 BRAKE PM25 TIRE PM25- TOT PM

E

AL 

Off 5,448 10,117 - 2,320 2,320 12 0 190 - - 190 

On 19,195 65,412 - 3,652 3,652 272 120 3,986 96 22 4,104 4State Total 24,643 75,530 - 5,971 5,971 284 120 4,176 96 22 4,294 4

FL 

Off 12,015 20,460 - 4,894 4,894 28 0 496 - - 496 

On 49,187 165,643 - 8,968 8,968 829 347 9,490 291 56 9,837 9State Total 61,202 186,103 - 13,863 13,863 857 347 9,986 291 56 10,333 10

GA 

Off 7,530 13,051 - 3,009 3,009 16 0 250 - - 250 

On 47,208 159,498 - 8,686 8,686 647 271 9,912 239 48 10,199 10State Total 54,738 172,549 - 11,694 11,694 663 271 10,162 239 48 10,449 10

KY 

Off 4,667 9,086 - 2,038 2,038 10 0 157 - - 157 

On 13,559 52,447 - 2,513 2,513 211 97 2,806 49 14 2,868 2State Total 18,226 61,533 - 4,551 4,551 222 97 2,963 49 14 3,026 3

MS 

Off 4,380 8,054 - 1,848 1,848 10 0 170 - - 170 

On 14,493 54,251 - 2,667 2,667 227 106 3,012 50 15 3,078 3State Total 18,873 62,305 - 4,514 4,514 237 106 3,182 50 15 3,248 3

NC 

Off 12,244 24,555 - 5,568 5,568 28 0 444 - - 444 

On 19,890 71,809 - 3,744 3,744 314 174 3,639 47 20 3,706 3State Total 32,134 96,364 - 9,312 9,312 342 174 4,083 47 20 4,150 4

SC 

Off 3,599 6,724 - 1,542 1,542 8 0 122 - - 122 

On 17,809 62,715 - 3,229 3,229 264 114 3,640 89 18 3,748 3State Total 21,408 69,439 - 4,771 4,771 272 114 3,763 89 18 3,870 3

TN 

Off 4,964 9,482 - 2,147 2,147 11 0 170 - - 170 

On 27,718 122,910 - 4,995 4,995 490 226 5,777 57 27 5,861 5State Total 32,682 132,392 - 7,142 7,142 501 226 5,947 57 27 6,031 6

VA 

Off 3,188 5,333 - 1,201 1,201 7 0 122 - - 122 

On 19,493 81,825 - 3,644 3,644 329 157 3,930 55 21 4,006 4State Total 22,681 87,159 - 4,845 4,845 335 157 4,052 55 21 4,128 4

WV 

Off 3,308 7,168 - 1,562 1,562 8 0 116 - - 116 

On 5,558 21,957 - 1,052 1,052 87 42 1,174 19 6 1,199 1State Total 8,865 29,125 - 2,614 2,614 95 42 1,290 19 6 1,315 1

SEMAP 

Off 61,342 114,033 - 26,129 26,129 138 0 2,238 - - 2,238 2

On 234,110 858,467 - 43,148 43,148 3,670 1,654 47,366 993 246 48,606 48Total 295,453 972,499 - 69,277 69,277 3,808 1,654 49,604 993 246 50,844 51

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Table 6-3. Annual on-road mobile source emissions summary by state and network from gasoline and diesel fuele

State Network CO NOX VOC- EVP VOC- EXH VOC- TOT SO2 NH3 PM25 EXH PM25 BRAKE PM25 TIRE PM25- TOT PM

E

AL 

Off 392,855 35,732 11,619 35,765 47,384 64 0 517 - - 517 

On 516,595 136,935 6,603 23,090 29,694 1,445 2,823 4,765 478 127 5,370 4State Total 909,450 172,668 18,222 58,856 77,078 1,509 2,823 5,282 478 127 5,887 5

FL 

Off 821,857 97,371 41,592 87,559 129,151 165 0 1,080 - - 1,080 1

On 1,743,593 401,565 24,613 69,133 93,746 4,987 9,676 11,362 1,659 379 13,400 11State Total 2,565,451 498,935 66,205 156,692 222,897 5,151 9,676 12,442 1,659 379 14,480 12

GA 

Off 617,202 64,183 20,688 62,628 83,316 193 0 915 - - 915 

On 1,292,189 332,655 15,373 62,225 77,598 6,214 5,416 11,705 848 213 12,765 12State Total 1,909,391 396,837 36,061 124,853 160,914 6,407 5,416 12,620 848 213 13,681 13

KY 

Off 345,249 28,160 7,523 29,405 36,928 53 0 517 - - 517 

On 358,762 105,266 4,188 14,767 18,955 969 2,172 3,508 258 79 3,845 3State Total 704,011 133,425 11,711 44,172 55,883 1,022 2,172 4,026 258 79 4,363 4

MS 

Off 255,659 24,186 7,913 22,456 30,369 42 0 373 - - 373 

On 269,716 93,039 3,293 11,443 14,737 877 1,809 3,407 211 70 3,688 3State Total 525,375 117,225 11,206 33,899 45,106 920 1,809 3,780 211 70 4,061 3

NC 

Off 916,622 64,364 24,160 63,606 87,766 122 0 1,187 - - 1,187 1

On 1,194,351 216,305 9,681 39,618 49,299 2,412 5,053 5,621 419 154 6,194 5State Total 2,110,972 280,670 33,840 103,224 137,064 2,534 5,053 6,808 419 154 7,381 7

SC 

Off 299,849 25,460 8,552 24,274 32,826 50 0 343 - - 343 

On 445,626 119,020 4,450 16,748 21,198 1,263 2,303 4,225 337 89 4,652 4State Total 745,475 144,480 13,001 41,022 54,023 1,313 2,303 4,568 337 89 4,994 4

TN 

Off 523,412 38,193 17,466 38,943 56,409 77 0 621 - - 621 

On 674,253 210,611 5,780 24,624 30,404 1,780 3,322 6,789 268 104 7,161 7State Total 1,197,665 248,804 23,246 63,567 86,813 1,857 3,322 7,409 268 104 7,781 7

VA 

Off 646,816 38,835 15,388 52,212 67,600 70 0 830 - - 830 

On 542,095 157,909 7,917 20,781 28,698 1,358 4,041 5,258 299 125 5,682 5State Total 1,188,911 196,744 23,305 72,992 96,297 1,429 4,041 6,088 299 125 6,512 6

WV 

Off 185,064 15,547 3,399 13,955 17,354 30 0 291 - - 291 

On 172,517 44,421 1,604 6,247 7,852 458 875 1,502 101 32 1,635 1State Total 357,581 59,968 5,004 20,202 25,205 487 875 1,793 101 32 1,926 1

SEMAP 

Off 5,004,586 432,030 158,299 430,803 589,102 866 0 6,674 - - 6,674 7

On 7,209,697 1,817,725 83,502 288,677 372,179 21,763 37,490 58,142 4,879 1,372 64,393 60Total 12,214,283 2,249,755 241,801 719,480 961,281 22,629 37,490 64,816 4,879 1,372 71,067 67

WV SIP Revision: Regional Haze 5-Year Periodic Report 
2007 MOVES2010a On-road Mobile Source Emissions Factors for the 

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30 

Table 6-4. Annual on-road mobile source emissions summary by state and vehicle category (tons/year). 

State Category CO NOX VOC- EVP VOC- EXH VOC- TOT SO2 NH3 PM25 EXH PM25 BRAKE PM25 TIRE PM25- TOT PM

E

AL 

LDGV 308,556 39,989 8,526 18,583 27,109 602 1,621 471 167 60 698 

LDGT1 344,599 34,831 5,311 21,184 26,494 377 686 397 121 27 546 LDGT2 118,354 11,965 1,825 7,278 9,102 130 236 137 42 9 188 HDGV 106,231 10,094 1,315 5,362 6,677 111 149 90 52 9 150 MC 7,068 259 1,245 479 1,724 5 11 11 0 0 11 LDDV 24 80 - 7 7 1 0 6 0 0 7 LDDT 328 486 - 65 65 2 2 31 1 0 31 HDDV 24,148 74,730 - 5,885 5,885 281 118 4,126 95 21 4,242 4BUSES 143 234 - 15 15 1 0 13 0 0 14 State Total 909,450 172,668 18,222 58,856 77,078 1,509 2,823 5,282 478 127 5,887 5

FL 

LDGV 1,165,545 155,634 40,230 64,227 104,457 2,269 5,944 1,365 669 195 2,229 1

LDGT1 866,109 104,419 13,777 50,203 63,979 1,373 2,325 724 477 87 1,287 LDGT2 349,727 40,252 6,152 22,123 28,274 478 799 278 164 30 472 HDGV 102,620 11,865 1,167 4,917 6,084 161 235 67 58 10 135 MC 20,248 662 4,880 1,360 6,240 13 26 23 0 1 24 LDDV 239 482 - 66 66 2 1 83 1 0 84 LDDT 1,885 2,716 - 336 336 9 6 155 3 1 158 HDDV 57,365 176,595 - 13,213 13,213 824 331 9,377 277 54 9,708 9BUSES 1,713 6,311 - 247 247 21 9 370 11 2 383 State Total 2,565,451 498,935 66,205 156,692 222,897 5,151 9,676 12,442 1,659 379 14,480 12

GA 

LDGV 588,537 69,139 15,807 39,760 55,568 2,121 2,267 967 191 71 1,229 1

LDGT1 767,539 95,064 11,667 45,339 57,005 2,192 1,763 914 247 56 1,217 LDGT2 365,564 46,099 5,346 20,925 26,271 1,082 884 440 123 28 591 HDGV 117,805 13,391 1,440 6,066 7,505 328 217 117 48 9 174 MC 15,208 595 1,802 1,069 2,871 22 14 19 0 0 20 LDDV 41 115 - 13 13 1 0 16 0 0 16 LDDT 1,039 1,439 - 204 204 6 6 100 2 1 102 HDDV 51,873 166,257 - 11,181 11,181 642 258 9,760 228 46 10,035 10BUSES 1,786 4,738 - 297 297 14 7 286 8 2 296 State Total 1,909,391 396,837 36,061 124,853 160,914 6,407 5,416 12,620 848 213 13,681 13

KY 

LDGV 253,054 29,550 5,799 15,649 21,448 389 1,218 460 95 37 592 

LDGT1 271,656 27,417 3,406 15,873 19,279 263 577 392 76 19 486 LDGT2 79,701 7,620 970 4,460 5,430 80 157 110 18 5 133 HDGV 75,889 7,112 771 3,346 4,116 65 116 92 20 4 117 MC 5,485 193 764 294 1,058 3 8 9 0 0 9 LDDV 15 47 - 5 5 0 0 4 0 0 4 LDDT 178 272 - 39 39 1 1 18 0 0 18 HDDV 17,912 60,986 - 4,494 4,494 220 95 2,929 48 14 2,991 3BUSES 121 228 - 14 14 1 0 12 0 0 13 State Total 704,011 133,425 11,711 44,172 55,883 1,022 2,172 4,026 258 79 4,363 4

WV SIP Revision: Regional Haze 5-Year Periodic Report 
2007 MOVES2010a On-road Mobile Source Emissions Factors for the 

Southeastern Modeling Analysis and Planning (SEMAP) States 

31 

Table 6-4. (continued) 

State Category CO NOX VOC- EVP VOC- EXH VOC- TOT SO2 NH3 PM25 EXH PM25 BRAKE PM25 TIRE PM25- TOT PM

E

MS 

LDGV 213,453 28,659 5,491 11,941 17,432 438 1,249 307 101 40 448 

LDGT1 222,004 21,007 3,522 13,825 17,348 200 378 228 49 13 290 LDGT2 14,572 1,379 231 908 1,139 13 25 15 3 1 19 HDGV 53,165 3,755 779 2,517 3,295 30 46 43 8 2 53 MC 3,309 120 1,183 195 1,378 2 5 4 0 0 4 LDDV 113 389 - 32 32 3 2 28 1 0 29 LDDT 564 831 - 114 114 4 4 53 1 0 55 HDDV 17,636 59,216 - 4,278 4,278 224 98 3,000 47 14 3,060 3BUSES 559 1,870 - 91 91 6 3 101 2 1 103 State Total 525,375 117,225 11,206 33,899 45,106 920 1,809 3,780 211 70 4,061 3

NC 

LDGV 533,163 47,517 13,084 26,813 39,896 745 1,995 748 113 56 916 

LDGT1 1,022,227 87,755 13,341 45,835 59,175 909 1,843 1,258 161 49 1,468 1LDGT2 352,587 30,877 4,508 15,606 20,115 324 659 440 58 18 516 HDGV 144,284 17,376 885 4,524 5,409 200 353 250 40 11 301 MC 26,577 781 2,022 1,134 3,157 13 28 29 0 0 30 LDDV 134 315 - 54 54 2 1 55 0 0 55 LDDT 868 1,268 - 178 178 6 7 93 1 0 94 HDDV 30,443 93,628 - 9,010 9,010 331 165 3,880 45 19 3,944 4BUSES 688 1,153 - 69 69 4 2 56 1 0 57 State Total 2,110,972 280,670 33,840 103,224 137,064 2,534 5,053 6,808 419 154 7,381 7

SC 

LDGV 260,091 29,266 6,621 13,634 20,254 441 1,169 347 95 35 478 

LDGT1 287,913 29,417 3,527 14,470 17,997 388 667 291 99 23 413 LDGT2 106,943 11,163 1,276 5,246 6,522 151 260 111 39 9 158 HDGV 59,943 4,905 664 2,436 3,101 56 81 45 15 3 64 MC 9,177 290 914 465 1,379 6 13 11 0 0 11 LDDV 19 64 - 5 5 1 0 5 0 0 5 LDDT 336 508 - 66 66 2 2 31 1 0 32 HDDV 20,467 66,849 - 4,600 4,600 263 109 3,607 85 18 3,710 3BUSES 586 2,018 - 100 100 6 3 120 3 1 124 State Total 745,475 144,480 13,001 41,022 54,023 1,313 2,303 4,568 337 89 4,994 4

TN 

LDGV 394,567 38,209 12,192 22,688 34,880 481 1,331 549 66 32 647 

LDGT1 494,334 52,166 6,335 22,151 28,486 590 1,209 601 98 30 729 LDGT2 169,330 17,853 2,173 7,595 9,769 202 413 206 34 10 250 HDGV 93,538 7,768 1,113 3,443 4,556 76 126 91 14 4 108 MC 13,213 416 1,432 548 1,981 7 16 15 0 0 16 LDDV 91 338 - 24 24 3 2 24 1 0 25 LDDT 22 37 - 8 8 0 - 2 - - 2 HDDV 32,040 130,331 - 7,028 7,028 493 222 5,834 55 26 5,915 6BUSES 529 1,685 - 83 83 5 2 88 2 0 90 State Total 1,197,665 248,804 23,246 63,567 86,813 1,857 3,322 7,409 268 104 7,781 7

WV SIP Revision: Regional Haze 5-Year Periodic Report 
2007 MOVES2010a On-road Mobile Source Emissions Factors for the 

Southeastern Modeling Analysis and Planning (SEMAP) States 

32 

Table 6-4. (concluded) 

State Category CO NOX VOC- EVP VOC- EXH VOC- TOT SO2 NH3 PM25 EXH PM25 BRAKE PM25 TIRE PM25- TOT PM

EX

VA 

LDGV 598,031 66,894 13,931 32,698 46,629 816 3,258 1,332 185 86 1,604 1

LDGT1 327,314 24,760 4,693 20,920 25,613 159 368 406 33 10 449 LDGT2 168,614 12,757 2,418 10,777 13,194 82 189 210 17 5 232 HDGV 62,787 4,856 715 3,233 3,948 33 58 74 9 2 84 MC 9,485 318 1,548 520 2,068 4 11 14 0 0 15 LDDV 86 264 - 29 29 2 1 31 0 0 31 LDDT 562 879 - 135 135 4 4 55 1 0 56 HDDV 19,973 79,351 - 4,349 4,349 309 142 3,614 47 18 3,680 3BUSES 2,060 6,664 - 332 332 20 10 352 7 2 361 State Total 1,188,911 196,744 23,305 72,992 96,297 1,429 4,041 6,088 299 125 6,512 6

WV 

LDGV 103,227 10,280 1,907 5,337 7,244 160 424 168 31 13 212 

LDGT1 183,906 14,607 2,063 9,630 11,693 158 279 242 35 9 287 LDGT2 43,824 4,173 446 2,055 2,501 52 95 65 12 3 80 HDGV 13,112 1,647 57 359 416 20 30 21 4 1 25 MC 4,648 136 530 207 737 2 5 6 0 0 7 LDDV 23 58 - 11 11 0 0 7 0 0 7 LDDT 115 180 - 25 25 1 1 12 0 0 12 HDDV 8,474 28,126 - 2,539 2,539 91 40 1,231 18 5 1,255 1BUSES 252 761 - 39 39 2 1 39 1 0 40 State Total 357,581 59,968 5,004 20,202 25,205 487 875 1,793 101 32 1,926 1

SEMAP 

LDGV 4,418,223 515,137 123,588 251,328 374,917 8,462 20,475 6,714 1,714 625 9,053 7

LDGT1 4,787,601 491,444 67,641 259,430 327,070 6,609 10,095 5,453 1,396 323 7,172 5LDGT2 1,769,215 184,137 25,345 96,972 122,317 2,593 3,717 2,012 508 118 2,639 2HDGV 829,375 82,768 8,907 36,201 45,108 1,080 1,412 890 266 56 1,212 MC 114,416 3,771 16,320 6,271 22,592 77 136 143 1 3 147 LDDV 785 2,153 - 245 245 15 8 258 4 1 263 LDDT 5,897 8,615 - 1,169 1,169 36 32 549 9 3 560 HDDV 280,332 936,069 - 66,576 66,576 3,677 1,578 47,359 945 235 48,539 48BUSES 8,439 25,662 - 1,287 1,287 80 36 1,438 35 7 1,480 1Total 12,214,283 2,249,755 241,801 719,480 961,281 22,629 37,490 64,816 4,879 1,372 71,067 67

WV SIP Revision: Regional Haze 5-Year Periodic Report 
2007 MOVES2010a On-road Mobile Source Emissions Factors for the 

Southeastern Modeling Analysis and Planning (SEMAP) States 

33 

Table 6-5. Ozone season day on-road mobile source emissions summary by state and vehicle category (tons/day)

State Category CO NOX VOC- EVP VOC- EXH VOC- TOT SO2 NH3 PM25 EXH PM25 BRAKE PM25 TIRE PM25- TOT PM

E

AL 

LDGV 810.0 112.9 25.2 46.5 71.7 1.7 4.6 1.0 0.5 0.2 1.7 

LDGT1 915.8 97.5 15.9 55.0 70.9 1.1 2.0 0.8 0.3 0.1 1.3 LDGT2 313.8 33.4 5.5 18.9 24.3 0.4 0.7 0.3 0.1 0.0 0.4 HDGV 276.6 26.7 3.8 14.0 17.8 0.3 0.4 0.2 0.1 0.0 0.3 MC 17.5 0.6 3.7 1.3 5.0 0.0 0.0 0.0 0.0 0.0 0.0 LDDV 0.1 0.2 - 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 LDDT 1.0 1.4 - 0.2 0.2 0.0 0.0 0.1 0.0 0.0 0.1 HDDV 67.1 193.6 - 15.9 15.9 0.8 0.3 11.3 0.3 0.1 11.6 BUSES 0.4 0.6 - 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 State Total 2,402.2 466.8 54.2 151.8 206.0 4.3 8.0 13.8 1.3 0.4 15.5 

FL 

LDGV 3,244.6 441.6 108.2 176.6 284.9 6.6 16.8 3.5 1.9 0.6 6.0 

LDGT1 2,398.5 296.0 37.2 139.0 176.1 4.0 6.6 1.9 1.3 0.2 3.5 LDGT2 946.0 112.7 16.5 60.6 77.0 1.4 2.2 0.7 0.5 0.1 1.2 HDGV 274.7 32.1 3.1 13.4 16.6 0.5 0.6 0.2 0.2 0.0 0.4 MC 50.5 1.7 12.6 3.7 16.3 0.0 0.1 0.1 0.0 0.0 0.1 LDDV 0.7 1.3 - 0.1 0.1 0.0 0.0 0.2 0.0 0.0 0.2 LDDT 5.4 7.4 - 0.8 0.8 0.0 0.0 0.4 0.0 0.0 0.4 HDDV 159.6 467.1 - 36.2 36.2 2.3 0.9 25.7 0.8 0.1 26.6 BUSES 4.7 16.6 - 0.7 0.7 0.1 0.0 1.0 0.0 0.0 1.0 State Total 7,084.8 1,376.5 177.6 431.0 608.6 14.8 27.3 33.6 4.6 1.1 39.4 

GA 

LDGV 1,742.2 221.9 44.7 106.4 151.0 10.6 6.5 2.1 0.5 0.2 2.8 

LDGT1 2,416.8 293.2 33.1 133.0 166.2 11.0 5.0 2.0 0.7 0.2 2.9 LDGT2 1,162.4 141.8 15.1 62.0 77.1 5.4 2.5 1.0 0.3 0.1 1.4 HDGV 361.8 39.8 4.0 18.0 21.9 1.6 0.6 0.2 0.1 0.0 0.4 MC 48.7 2.0 5.0 3.5 8.5 0.1 0.0 0.0 0.0 0.0 0.0 LDDV 0.1 0.3 - 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 LDDT 3.1 4.0 - 0.6 0.6 0.0 0.0 0.3 0.0 0.0 0.3 HDDV 144.2 431.2 - 30.4 30.4 1.8 0.7 26.7 0.6 0.1 27.5 BUSES 4.9 12.2 - 0.8 0.8 0.0 0.0 0.8 0.0 0.0 0.8 State Total 5,884.2 1,146.5 101.9 354.6 456.5 30.6 15.4 33.1 2.4 0.6 36.1 

KY 

LDGV 585.4 81.0 17.6 35.7 53.3 1.1 3.5 0.8 0.3 0.1 1.2 

LDGT1 668.4 75.4 10.4 39.8 50.2 0.7 1.7 0.7 0.2 0.1 1.0 LDGT2 193.6 21.0 3.0 11.2 14.1 0.2 0.4 0.2 0.1 0.0 0.3 HDGV 185.7 18.5 2.3 8.5 10.8 0.2 0.3 0.2 0.1 0.0 0.2 MC 12.3 0.5 2.4 0.8 3.2 0.0 0.0 0.0 0.0 0.0 0.0 LDDV 0.0 0.1 - 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 LDDT 0.5 0.7 - 0.1 0.1 0.0 0.0 0.0 0.0 0.0 0.0 HDDV 49.4 157.5 - 12.1 12.1 0.6 0.3 8.0 0.1 0.0 8.2 BUSES 0.3 0.6 - 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 State Total 1,695.6 355.3 35.6 108.1 143.8 2.9 6.2 10.0 0.7 0.2 10.9 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
2007 MOVES2010a On-road Mobile Source Emissions Factors for the 

Southeastern Modeling Analysis and Planning (SEMAP) States 

34 

Table 6-5. (continued) 

State Category CO NOX VOC- EVP VOC- EXH VOC- TOT SO2 NH3 PM25 EXH PM25 BRAKE PM25 TIRE PM25- TOT PM

E

MS 

LDGV 569.7 80.8 16.2 30.7 46.9 1.3 3.6 0.7 0.3 0.1 1.1 

LDGT1 575.3 58.1 10.6 36.0 46.6 0.6 1.1 0.5 0.1 0.0 0.6 LDGT2 37.7 3.8 0.7 2.4 3.1 0.0 0.1 0.0 0.0 0.0 0.0 HDGV 134.3 9.9 2.3 6.5 8.8 0.1 0.1 0.1 0.0 0.0 0.1 MC 7.9 0.3 3.6 0.5 4.1 0.0 0.0 0.0 0.0 0.0 0.0 LDDV 0.3 1.1 - 0.1 0.1 0.0 0.0 0.1 0.0 0.0 0.1 LDDT 1.7 2.3 - 0.3 0.3 0.0 0.0 0.1 0.0 0.0 0.1 HDDV 48.9 152.6 - 11.5 11.5 0.6 0.3 8.2 0.1 0.0 8.4 BUSES 1.5 4.8 - 0.2 0.2 0.0 0.0 0.3 0.0 0.0 0.3 State Total 1,377.3 313.6 33.3 88.2 121.5 2.6 5.2 10.0 0.6 0.2 10.8 

NC 

LDGV 1,156.5 128.8 34.7 63.4 98.1 2.2 5.7 1.5 0.3 0.2 2.0 

LDGT1 2,459.1 238.6 35.6 118.8 154.3 2.6 5.3 2.5 0.5 0.1 3.1 LDGT2 851.4 83.8 12.0 40.6 52.6 0.9 1.9 0.9 0.2 0.1 1.1 HDGV 359.2 44.8 2.4 12.4 14.8 0.6 1.0 0.5 0.1 0.0 0.6 MC 56.0 1.9 5.1 3.0 8.2 0.0 0.1 0.1 0.0 0.0 0.1 LDDV 0.3 0.8 - 0.1 0.1 0.0 0.0 0.1 0.0 0.0 0.2 LDDT 2.6 3.5 - 0.5 0.5 0.0 0.0 0.3 0.0 0.0 0.3 HDDV 84.8 241.2 - 24.5 24.5 0.9 0.5 10.6 0.1 0.1 10.8 BUSES 1.9 2.9 - 0.2 0.2 0.0 0.0 0.2 0.0 0.0 0.2 State Total 4,971.8 746.4 89.9 263.3 353.2 7.3 14.4 16.7 1.2 0.4 18.3 

SC 

LDGV 643.5 80.6 18.2 34.4 52.7 1.3 3.3 0.7 0.3 0.1 1.1 

LDGT1 739.0 81.4 9.7 38.2 48.0 1.1 1.9 0.6 0.3 0.1 1.0 LDGT2 275.2 30.8 3.5 13.9 17.4 0.4 0.7 0.2 0.1 0.0 0.4 HDGV 147.0 12.8 1.8 6.3 8.1 0.2 0.2 0.1 0.0 0.0 0.1 MC 21.0 0.7 2.4 1.3 3.7 0.0 0.0 0.0 0.0 0.0 0.0 LDDV 0.1 0.2 - 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 LDDT 1.0 1.4 - 0.2 0.2 0.0 0.0 0.1 0.0 0.0 0.1 HDDV 56.8 172.8 - 12.5 12.5 0.7 0.3 9.9 0.2 0.0 10.2 BUSES 1.6 5.2 - 0.3 0.3 0.0 0.0 0.3 0.0 0.0 0.3 State Total 1,885.1 385.9 35.7 107.1 142.8 3.8 6.5 12.0 0.9 0.3 13.2 

TN 

LDGV 820.5 102.5 33.4 52.3 85.7 1.4 3.8 1.0 0.2 0.1 1.3 

LDGT1 1,210.5 142.2 17.5 57.8 75.4 1.7 3.5 1.2 0.3 0.1 1.5 LDGT2 412.6 48.4 6.0 19.8 25.8 0.6 1.2 0.4 0.1 0.0 0.5 HDGV 214.5 20.1 3.0 8.7 11.8 0.2 0.3 0.2 0.0 0.0 0.2 MC 27.5 1.0 3.9 1.5 5.4 0.0 0.0 0.0 0.0 0.0 0.0 LDDV 0.3 0.9 - 0.1 0.1 0.0 0.0 0.1 0.0 0.0 0.1 LDDT 0.1 0.1 - 0.0 0.0 0.0 - 0.0 - - 0.0 HDDV 88.5 337.7 - 19.0 19.0 1.4 0.6 16.0 0.1 0.1 16.2 BUSES 1.4 4.4 - 0.2 0.2 0.0 0.0 0.2 0.0 0.0 0.2 State Total 2,775.8 657.2 63.8 159.5 223.3 5.3 9.4 19.1 0.8 0.3 20.1 

WV SIP Revision: Regional Haze 5-Year Periodic Report 
2007 MOVES2010a On-road Mobile Source Emissions Factors for the 

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Table 6-4. (concluded) 

State Category CO NOX VOC- EVP VOC- EXH VOC- TOT SO2 NH3 PM25 EXH PM25 BRAKE PM25 TIRE PM25- TOT PM

E

VA 

LDGV 1,442.5 182.3 39.9 77.7 117.6 2.4 9.3 2.5 0.5 0.2 3.3 2.7 

LDGT1 737.3 66.4 13.5 50.3 63.8 0.5 1.1 0.7 0.1 0.0 0.8 0.8 LDGT2 379.1 34.1 7.0 25.9 32.8 0.2 0.5 0.4 0.0 0.0 0.4 0.4 HDGV 142.7 12.5 2.0 7.8 9.9 0.1 0.2 0.1 0.0 0.0 0.2 0.1 MC 20.6 0.8 4.3 1.3 5.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 LDDV 0.2 0.7 - 0.1 0.1 0.0 0.0 0.1 0.0 0.0 0.1 0.1 LDDT 1.6 2.3 - 0.3 0.3 0.0 0.0 0.2 0.0 0.0 0.2 0.2 HDDV 54.8 205.9 - 11.7 11.7 0.9 0.4 9.9 0.1 0.1 10.1 10.2 BUSES 5.6 17.3 - 0.9 0.9 0.1 0.0 1.0 0.0 0.0 1.0 1.0 State Total 2,784.4 522.4 66.7 175.9 242.6 4.1 11.5 14.8 0.8 0.4 16.0 15.5 

WV 

LDGV 212.8 27.7 5.5 11.7 17.2 0.5 1.2 0.3 0.1 0.0 0.4 0.3 

LDGT1 401.0 39.4 6.0 23.1 29.1 0.5 0.8 0.4 0.1 0.0 0.5 0.4 LDGT2 100.5 11.3 1.3 5.1 6.4 0.1 0.3 0.1 0.0 0.0 0.2 0.1 HDGV 31.2 4.2 0.2 1.0 1.1 0.1 0.1 0.0 0.0 0.0 0.0 0.0 MC 9.4 0.3 1.5 0.5 2.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 LDDV 0.1 0.1 - 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 LDDT 0.3 0.5 - 0.1 0.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 HDDV 23.3 72.8 - 6.9 6.9 0.3 0.1 3.4 0.1 0.0 3.4 3.5 BUSES 0.7 2.0 - 0.1 0.1 0.0 0.0 0.1 0.0 0.0 0.1 0.1 State Total 779.3 158.3 14.5 48.5 63.0 1.4 2.5 4.4 0.3 0.1 4.8 4.6 

SEMAP 

LDGV 11,227.7 1,460.0 343.6 635.4 979.0 29.0 58.3 14.1 4.9 1.8 20.8 15.4 

LDGT1 12,521.8 1,388.2 189.5 691.1 880.6 23.7 28.8 11.3 4.0 0.9 16.2 12.3 LDGT2 4,672.2 521.1 70.5 260.2 330.7 9.8 10.6 4.2 1.4 0.3 5.9 4.5 HDGV 2,127.7 221.4 25.0 96.6 121.6 3.7 3.9 1.8 0.7 0.2 2.6 1.9 MC 271.3 10.0 44.6 17.4 61.9 0.3 0.4 0.3 0.0 0.0 0.3 0.3 LDDV 2.2 5.7 - 0.5 0.5 0.0 0.0 0.7 0.0 0.0 0.7 0.7 LDDT 17.4 23.7 - 3.0 3.0 0.1 0.1 1.5 0.0 0.0 1.5 1.5 HDDV 777.2 2,432.3 - 180.5 180.5 10.3 4.3 129.6 2.6 0.6 132.8 133.BUSES 23.0 66.5 - 3.4 3.4 0.2 0.1 3.9 0.1 0.0 4.1 4.1 Total 31,640.4 6,128.9 673.2 1,888.1 2,561.3 77.1 106.4 167.5 13.7 3.9 185.0 174.

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Figure 6-1. Percentage contribution by state and fuel to annual on-road mobile source emissions estimates.

AL Diesel, 24,643 , 0%

AL Gasoline, 

884,807 , 7%

FL Diesel, 61,202 , 1%

FL Gasoline, 2,504,249 , 

21%

GA Diesel, 54,738 , 0%

GA Gasoline, 1,854,653 , 

15%

KY Diesel, 18,226 , 0% KY Gasoline, 685,785 , 6% MS Diesel, 18,873 , 0% MS Gasoline, 506,503 , 4%

NC Diesel, 32,134 , 0%

NC Gasoline, 2,078,838 , 

17%

SC Diesel, 21,408 , 0%

SC Gasoline, 724,067 , 

6%

TN Diesel, 32,682 , 0%

TN Gasoline, 1,164,983 , 

10%

VA Diesel, 22,681 , 0% VA Gasoline, 

1,166,230 , 10%

WV Diesel, 8,865 , 0%

WV Gasoline, 

348,716 , 3%

CO

AL Diesel, 75,530 , 3%

AL Gasoline, 97,138 , 4%

FL Diesel, 

186,103 , 8%

FL Gasoline, 312,832 , 

14%

GA Diesel, 172,549 , 

8%

GA Gasoline, 

224,288 , 10%

KY Gasoline, 71,892 , 3% KY Diesel, 61,533 , 3%

MS Diesel, 62,305 , 3%

MS Gasoline, 54,920 , 2%

NC Diesel, 96,364 , 4%

NC Gasoline, 184,305 , 

8%

SC Diesel, 69,439 , 3%

SC Gasoline, 75,041 , 3%

TN Diesel, 

132,392 , 6%

TN Gasoline, 116,412 , 

5%

VA Diesel, 87,159 , 4%

VA Gasoline, 

109,585 , 5%

WV Diesel, 

29,125 , 1% WV Gasoline, 30,843 , 

1%

NOX

AL Diesel, 5,971 , 1%

AL Gasoline, 

71,106 , 7%

FL Diesel, 13,863 , 1%

FL Gasoline, 209,034 , 

22%

GA Diesel, 11,694 , 1%

GA Gasoline, 149,220 , 

16%

KY Diesel, 4,551 , 0%

KY Gasoline, 51,332 , 5%

MS Diesel, 4,514 , 0%

MS Gasoline, 40,592 , 4%

NC Diesel, 9,312 , 1%

NC Gasoline, 127,752 , 

13%

SC Diesel, 4,771 , 0%

SC Gasoline, 49,252 , 5%

TN Diesel, 7,142 , 1% TN Gasoline, 79,671 

, 8%

VA Diesel, 4,845 , 1% VA Gasoline, 

91,453 , 10%

WV Diesel, 2,614 , 0%

WV Gasoline, 22,591 , 

2%

VOC-TOT

AL Die

AL 

FL G

GA Gasoline, 5,7

KY Diesel, 222 , 1%

KY Gasoline, 800 , 4%

MS Diesel, 237 , 1%

MS Gasoline, 683 , 3%

NC Diesel, 342 , 2%

NC Gasoline, 2,192 , 10%

SC Diesel, 272 , 1%

SC Gasoline, 1,041 , 5%

TN Diesel, 501 , 2%

TN 

Gasoline, 

1,356 , 6%

VA Diesel, 335 , 1%

VA Gasoline, 1,093 , 5%

WV Diesel, 95 , 0%

WV Gasoline, 

393 , 2% SO2

AL Diesel, 120 , 0%

AL Gasoline, 

2,703 , 7%

FL Diesel, 347 , 1%

FL Gasoline, 9,329 , 25%

GA Gasoline, 5,144 , 14% GA Diesel, 271 , 1%

KY Diesel, 97 , 0%

KY 

Gasoline, 

2,075 , 6%

MS Diesel, 

MS Gasoline, 1,703 , 5% 106 , 0%

NC Diesel, 174 , 0%

NC Gasoline, 4,879 , 13%

SC Diesel, 114 , 0%

SC Gasoline, 2,189 , 6%

TN Diesel, 226 , 1%

TN Gasoline, 3,096 , 

8%

VA Diesel, 157 , 0% VA Gasoline, 3,884 , 

10%

WV Diesel, 42 , 0%

WV Gasoline, 833 , 2% NH3

AL Diesel, 

4,294 , 6%

AL Gasoline, 1,593 , 2%

FL Diesel, 10,333 , 15%

FL Gasoline, 4,147 , 6%

GA Diesel, 10,449 , 15%

GA Gasoline, 3,232 , 5%

KY Diesel, 

3,026 , 4% KY Gasoline, 1,337 , 2%

MS Diesel, 3,248 , 5%

MS Gasoline, 814 , 1%

NC Diesel, 4,150 , 6%

NC Gasoline, 3,231 , 5%

SC Diesel, 3,870 , 5%

SC Gasoline, 1,124 , 2%

TN Diesel, 6,031 , 8%

TN Gasoline, 1,750 , 2% VA Diesel, 

4,128 , 6%

VA Gasoline, 2,384 , 3%

WV Diesel, 1,315 , 2% WV Gasoline, 611 , 1%

PM25-TOT

AL Diesel, 

4,762 , 5%

A

FL D

FL 

GA Die

GA 

Gasoline, 

5,682 , 6%

KY Gasoline, 2,225 , 2% KY Diesel, 3,299 , 4%

MS Diesel, 3,536 , 4%

MS Gasoline, 1,494 , 2%

NC Diesel, 4,472 , 5%

NC Gasoline, 

4,939 , 5%

SC Diesel, 4,297 , 5%

SC Gasoline, 2,116 , 2%

TN Diesel, 6,461 , 7%

TN Gasoline, 2,716 , 3%

VA Diesel, 4,473 , 5%

VA Gasoline, 3,578 , 4%

WV Diesel, 

1,428 , 2% WV Gasoline, 968 , 1%

PM10-TOT

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7.0 DATA DISK 

A data disk containing an archive of the information developed during the study was prepared. The 

contents of the archive are described in Table 7-1.

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Table 7-1. Description of data disk archive for the SEMAP 2007 MOVES2010a study. semap (directory) | |-- 2007_MOVES_MySQL_inputs MySQL input data base archives of MOVES2010a runs | |-- 2007_MOVES_MySQL_outputs MySQL output data base archives of MOVES2010a runs | |-- edss (directory) SMOKE files files for use with MET4MOVES | | | |-- data_semap (directory) | | | | | |-- ge_data (directory) | | | | | | | |-- fuelmonth_semap_??.txt Fuel month cross-reference file for use in MET4MOVES and MOV| | | | | | | |-- mcref_semap_??_2007.txt Representative county cross-reference file for use in MET4MO| | | | | | | |-- GRDDESC Standard SMOKE grid definition file used by MET4MOVEs | | | | | | | |-- SRGDESC.MOVES.NC Standard SMOKE spatial surrogates definition file used by ME| | | | | | | |-- Srg_12km_MOVES_SEMAP (directory) containing standard SMOKE spatial surrogates use| | | | | | | |-- metlist.met4moves.lst File containing list of netCDF MCIP files for use by MET4MOV| | | | | |-- inventory (directory) | | | | | | | |-- MOVES_2007 (directory) | | | | | | | | | |-- mobile (directory) files for use by UNC in SMOKE modeling | | | | | | | | | |-- onroad_dat (directory) files for use by UNC in SMOKE modeling | | | | | |-- met (directory) containing netCDF MCIP files for MET4MOVES (refe| | | metlist.met4moves.lst) | | |-- met_out (directory) | | | | | | | |-- 12k (directory) containing output from MET4MOVES (SMOKE and MOVE| | | data sets) | | |-- run_MOVES_2007 (directory) | | | | | | | |-- static (directory) | | | | | | | | | |-- logs (directory) containing diagnostic log files output by MET4MO| | | |-- subsys (directory) | | | | | |-- smoke (directory) | | | | | | | |-- assigns_semap (directory) | | | | | | | | | |-- ASSIGNS.MOVES.cmaq.cb05p25tx.semap.12k SMOKE ASSIGNS file used by MET4MOVES | | | | | | | |-- scripts (directory) 

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| | | | | | | | | |-- run_met4moves.MOVES.semap.??.bat C-shell scripts to run MET4MOVES | |-- moves2smoke_windows (directory) containing MOVES2010a emissions factors archives | Also contains Windows-based scripts to extract M| factors from MySQL output data base archnives. | |-- moves2moke_linux (directory) containing example scripts and results from runn| extraction procedures on a linux platform (still | |-- moves_emissions_factors_qa (directory) containing example Excel workbooks with VBA macr| MOVES2010a emissions factors and develop consoli| QA purposes. | |-- rh_rvp_sensitivity_experiments (directory) containing Consolidated Excel workbooks summariz| MOVES2010a sensitivity experiments. | |-- smoke_moves_input (directory) containing the MOVES2010a data inputs developed | | | |-- ?? (directories) one directory per state | | | | | |-- SSCCC_FuelFormulation.csv MOVES2010a fuel formulation input file | | | | | |-- SSCCC_FuelSupply.csv MOVES2010a fuel supply input file | | | | | |-- SSCCC_HPMSVTypeVMT.csv MOVES2010a annual VMT input file | | | | | |-- SSCCC_IMCoverage.csv MOVES2010a I/M input file | | | | | |-- SSCCC_sourceTypeAgeDistribution.csv MOVES2010a mode year age distribution input file | | | | | |-- SSCCC_sourceTypePopulatin.csv MOVES2010a vehicle population count input file | | | | | |-- MOVES_12km_2007001-2007365_??.txt MOVES2010a meteorological input file (replicated from met_ou| | | | | |-- SMOKE_12km_2007001-2007365_??.txt SMOKE meteorological input file (replicated from met_out/12k| |-- smoke_moves_input_qa (directory) MOVES2010a input QA results | | | |-- ?? (directories) one directory per state | |-- smoke_moves_output (directory) containing SMOKE-MOVES Integration Tool Run Spec| | results | | | |-- ?? (directories) one directory per state | | | | | |-- dummy*csv Standard SMOKE-MOVES Integration Tool files | | | | | |-- *imp.xml MOVES2010a XML data import scripts from SMOKE-MOVES Integrat| | | Run Specification Generator | | | | | |-- *mrs.xml MOVES2010a XML run specification scripts from SMOKE-MOVES In| | | Tool Run Specification Generator | | | | | |-- *.csv MOVES2010a compatible meteorological file from SMOKE-MOVES I

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| | | Tool Run Specification Generator | | | | | |-- jobs (directory) | | | | | | | |-- SEMAP_??_2007importer.csh MOVES2010a C-shell data importer script from SMOKE-MOVES Int| | | | Tool Run Specification Generator | | | | | | | |-- SEMAP_??_2007runspec.csh MOVES2010a C-shell eun specification script from SMOKE-MOVES | | | | Tool Run Specification Generator | | | | | | | |-- SSCCC_importer_MACHINE_CORE.csh C-shell script to run MOVES2010a data import on a specific M| | | | | | | |-- SSCCC_runspec_MACHINE_CORE.csh C-shell script to run MOVES2010a run specification on a spec| |-- smoke_moves_script (directory) SMOKE-MOVES Integration Tool scripts to generate | | C-shell scripts | | | |-- ?? (directories) one directory per state | | | | | |-- ??_repcounty Representative county definition file for SMOKE-MOVES Integr| | | | | |-- ??_runcontrol Run control file for the SMOKE-MOVES Integration Tool | | | | | |-- smoke_moves_runspec_generator.csh C-shell script to run the SMOKE-MOVES Integration Tool | | | |-- runspec_generator_v0.31_22Mar2011_early_NLEV.pl SMOKE-MOVES Tool Integration perl script for NLEV states (us| | | |-- runspec_generator_v0.31_22Mar2011.pl SMOKE-MOVES Tool Integration perl script 

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8.0 Conclusion 

EPA’s Motor Vehicle Emissions Simulator (MOVES) version 2010a was used in an on-road mobile 

source emissions modeling study for thirty-nine representative counties in ten SEMAP states. There 

were five distinct components to the effort: 

• Perform relative humidity (RH) and Reid vapor pressure (RVP) sensitivity experiments; 

• Estimate MOVES and SMOKE meteorology; 

• Estimate on-road mobile source emissions factors using MOVES2010a; 

• Estimate on-road mobile source emissions using SMOKE; and 

• Prepare on-road mobile source emissions estimates summaries from SMOKE reports. 

The purpose for conducting the sensitivity experiments was to determine how responsive the 

modeling system was to changes in RH and RVP, the results of which were used to help guide the 

choice of fuel seasons to model. It was found that for diesel and gasoline VOC, CO, SO 

2

, PM10 and 

PM2.5, a +5% RH change or even a +10% RH change results in emissions changes that will likely 

not impact the air quality modeling results. However, for NOX in a typical county, a +5% RH change 

resulted in diesel and gasoline NOX emissions estimates changing by +1.25 tons/day (+1.35% -- 

note that an increase in RH results in a decrease in NOX). Further, it was discovered that the 

greatest impact to emissions occurs in an RVP change from 15.0 psi to 13.5 psi with CO and VOC 

exhibiting definite sensitivity. There is less of an impact to CO and VOC emissions when the RVP 

changes from 9.0 psi to 7.8 psi. However, in both cases NOX has about a 1.0 ton/day sensitivity in a 

typical county, which may be important for modeling and policy purposes. 

Using the MET4MOVES component of the SMOKE-MOVES Integration Tool, estimates of RH and 

ambient temperature for use in MOVES2010a and SMOKE were prepared. The two important 

inputs to MET4MOVES were the fuel month cross-reference file and the representative county 

cross-reference file, both which were developed jointly by the study team and SEMAP. 

Six additional MOVES2010a input files were developed by the study team based on information 

provided by SEMAP: 

• Fuel formulation; 

• Fuel supply; 

• VMT; 

• Inspection and Maintenance (I/M) program; 

• Age distribution; and 

• Vehicle population. 

These data coupled with the meteorology were input to MOVES2010a, which produced the on-road 

mobile source emissions factors. The on-road mobile source emissions factors were subjected to 

quality assurance review by the study team, the SEMAP QA contractor (ENVIRON), and 

representatives from the SEMAP states. The emissions factors and attendant data were delivered 

to researchers at UNC who ran SMOKE to estimate on-road mobile source emissions. 

Researchers at UNC provided SMOKE reports to the study team for use in summarizing the on-road 

mobile source emissions estimates. The study team developed Excel workbooks with VBA scripting 

to facilitate the ingestion of the SMOKE reports. Further, VBA scripts were developed to prepare a 

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number of standard report summaries as well as to provide a limited ad-hoc reporting capability so 

that a user of the Excel workbooks can prepare his/her own report summaries from the SMOKE 

reports. Various tabular and graphical reports were prepared for use by SEMAP. 

 

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9.0 REFERENCES 

Boylan, J., (2010). Final SEMAP MOVES Representative Counties. Excel spreadsheet 

(SEMAP_Representative Counties4.xls) delivered via email 20-Dec. 

EPA, 2010. “User’s Guide for the SMOKE–MOVES Integration Tool.” Prepared for: Rich Mason, 

U.S. EPA, OAQPS, C339-02, USEPA Mailroom, Research Triangle Park, NC 27711. 

Prepared by: B.H. Baek, Institute for the Environment, The University of North Carolina at 

Chapel Hill, 137 E. Franklin St., CB 6116, Chapel Hill, NC 27599-6116, and Alison 

DenBleyker, ENVIRON, 773 San Marin Drive, Suite 2115, Novato, CA 94998. Contract No: 

EP-D-07-102, Work Assignment: 3-03. July 14. www.smoke-model.org/smoke_moves_tool. 

HPMS, 2009. National Transportation Atlas Data Base. Research and Technology Innovation 

Administration, Bureau of Transportation Statistics. 

www.bts.gov/publications/national_transportation_atlas_database/2009/ 

HPMS, 2010. National Transportation Atlas Data Base. Research and Technology Innovation 

Administration, Bureau of Transportation Statistics. 

www.bts.gov/publications/national_transportation_atlas_database/2010/ 

NHPN, 2007. The National Highway Planning Network. US Department of Transportation, Federal 

Highway Administration. www.fhwa.dot.gov/planning/nhpn/ 

ORD, 2009. “Meteorology-Chemistry Interface Preprocessor Release Notes,” U.S. Environmental 

Protection Agency, Office of Research and Development, Research Triangle Park, NC, 

October. 

OTAQ, 2010a. “Motor Vehicle Emission Simulator (MOVES) 2010a: User Guide,” EPA-420-B-10-

036, U.S. Environmental Protection Agency, Office of Transportation and Air Quality, 

Research Triangle Park, NC, August. 

(www.epa.gov/otaq/models/moves/MOVES2010a/420b10036.pdf) 

OTAQ, 2010b. MOVES (Motor Vehicle Emission Simulator). U.S. Environmental Protection 

Agency, Office of Transportation and Air Quality, Research Triangle Park, NC, August. 

(www.epa.gov/otaq/models/moves/index.htm) 

OTAQ, 2010c. Tools for MOVES. .S. Environmental Protection Agency, Office of Transportation 

and Air Quality, Research Triangle Park, NC, September 8. 

www.epa.gov/otaq/models/moves/tools.html 

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