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 

January 18, 2012 
Development of Point Source Emission Inventory for 2007 Southeastern States Air Resource Managers, Inc. 

AMEC Project No.: 6066-09-0326.02 January 18, 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................................................................................................................78 

1.12 REFERENCES............................................................................................................79 

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). For the 2007 SEMAP inventory, the base case and 

baseline inventories are one in the same. 

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 
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(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 1.7, 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 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 

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 
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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_8 

Inventory 

Submittal 

Format Data Used for 2007 Inventory 

AL 319 910 NIF ACCESS 2007 data for 328 major facilities; 

2007 data for 613 minor facilities; 

31 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 

76 154 NIF ACCESS 2007 data for 154 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 65 NIF ACCESS 2007 data for 9 Title V facilities 

2006 S/L data 65 facilities, which 

also included the 9 Title V facilities 

NC 

Forsyth 

30 84 EIS ACCESS 2007/08 data for 84 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_8 

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 9 NIF ACCESS 2007 data for 9facilities 

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 South Carolina’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 cases. This check 

was made because MARAMA 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 GADEP 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, out-
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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 

Facility 

Name 

Facility 

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 
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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 
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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 
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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 
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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 

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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 
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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 
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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 
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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 
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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 
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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 
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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 
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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 
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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 
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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 1
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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 
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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 
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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 
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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 
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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 13
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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 
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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 
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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 
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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 
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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 
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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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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 

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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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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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County FIPS 

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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County FIPS 

Facility Name 

Facility ID 

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. 
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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 emi

PM10-PRI and PM25-PRI. Those records were inserted into the database at the time that the other CEM related 
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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 SESARM 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 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. 

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. 

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 
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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. 

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) 
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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. 
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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 
Appendix A 
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 -87.12701007 0001 Alabama Pigments Co 002 -87.12701007 0001 Alabama Pigments Co 888 -87.12701015 0088 SOUTHERN HERITAGE CASKET COMPANY, INC. 001 -85.93001043 0010 American Proteins Inc 002 -86.80901043 0010 American Proteins Inc 005 -86.80901043 0010 American Proteins Inc 006 -86.80901043 0010 American Proteins Inc 007 -86.80901043 0010 American Proteins Inc 010 -86.80901043 0010 American Proteins Inc 011 -86.80901043 0010 American Proteins Inc 888 -86.80901073 010730078 CLUTCH & BRAKE SPECIALTY CO., INC. 002 -86.786401073 010730167 ERGON TERMINALLING, INC. 004 -87.10701073 010730339 SHELBY CONCRETE, INC. 001 -86.81301073 010730503 LAFARGE BUILDING MATERIALS, BIRMINGHAM PLANT 001 -86.81301093 0014 Glen Allen Rail Inc 002 -87.74801093 0014 Glen Allen Rail Inc 888 -87.74801093 0023 King Kutter Inc 001 -87.82001095 0046 Jackson Paving & Construction Company 888 -86.23201097 0010 ExxonMobil Production Company 001 -88.05201097 0010 ExxonMobil Production Company 002 -88.05201097 0010 ExxonMobil Production Company 003 -88.05201097 0010 ExxonMobil Production Company 004 -88.05201097 0010 ExxonMobil Production Company 005 -88.05201097 0010 ExxonMobil Production Company 006 -88.05201097 0010 ExxonMobil Production Company 007 -88.05201097 0010 ExxonMobil Production Company 008 -88.05201097 0010 ExxonMobil Production Company 010 -88.05201097 0010 ExxonMobil Production Company 011 -88.05201097 0010 ExxonMobil Production Company 012 -88.052
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

2-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

01097 0010 ExxonMobil Production Company 013 -88.05201097 0010 ExxonMobil Production Company 015 -88.05201097 0010 ExxonMobil Production Company 016 -88.05201097 0010 ExxonMobil Production Company 017 -88.05201097 0010 ExxonMobil Production Company 018 -88.05201097 0010 ExxonMobil Production Company 019 -88.05201097 0010 ExxonMobil Production Company 020 -88.05201097 0010 ExxonMobil Production Company 021 -88.05201097 0010 ExxonMobil Production Company 022 -88.05201097 0010 ExxonMobil Production Company 023 -88.05201097 0010 ExxonMobil Production Company 888 -88.05201097 0012 ExxonMobil Production Company 001 -88.04401097 0012 ExxonMobil Production Company 002 -88.04401097 0012 ExxonMobil Production Company 003 -88.04401097 0012 ExxonMobil Production Company 004 -88.04401097 0012 ExxonMobil Production Company 005 -88.04401097 0012 ExxonMobil Production Company 006 -88.04401097 0012 ExxonMobil Production Company 007 -88.04401097 0012 ExxonMobil Production Company 008 -88.04401097 0012 ExxonMobil Production Company 009 -88.04401097 0013 ExxonMobil Production Company 001 -88.12401097 0013 ExxonMobil Production Company 002 -88.12401097 0013 ExxonMobil Production Company 003 -88.12401097 0013 ExxonMobil Production Company 004 -88.12401097 0013 ExxonMobil Production Company 005 -88.12401097 0013 ExxonMobil Production Company 006 -88.12401097 0013 ExxonMobil Production Company 007 -88.12401097 0013 ExxonMobil Production Company 009 -88.12401097 0013 ExxonMobil Production Company 888 -88.12401097 0016 Shell Exploration & Production Company 001 -88.077
Development of Point Source Emission Inventory for 2007 Southeastern States A

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ID Facility Name Release Point ID Long 

01097 0016 Shell Exploration & Production Company 002 -88.07701097 0016 Shell Exploration & Production Company 004 -88.07701097 0016 Shell Exploration & Production Company 005 -88.07701097 0016 Shell Exploration & Production Company 006 -88.07701097 0016 Shell Exploration & Production Company 007 -88.07701097 0025 ExxonMobil Production Company 001 -87.95201097 0025 ExxonMobil Production Company 002 -87.95201097 0025 ExxonMobil Production Company 003 -87.95201097 0025 ExxonMobil Production Company 004 -87.95201097 0025 ExxonMobil Production Company 005 -87.95201097 0025 ExxonMobil Production Company 006 -87.95201097 0025 ExxonMobil Production Company 007 -87.95201097 0025 ExxonMobil Production Company 888 -87.95201097 0038 Mobile Abrasives 003 -88.03101097 0038 Mobile Abrasives 888 -88.03101097 2002 Armstrong World Industries Inc 001 -88.0501097 2002 Armstrong World Industries Inc 002 -88.0501097 2002 Armstrong World Industries Inc 003 -88.0501097 2002 Armstrong World Industries Inc 004 -88.0501097 2002 Armstrong World Industries Inc 005 -88.0501097 2002 Armstrong World Industries Inc 006 -88.0501097 2002 Armstrong World Industries Inc 007 -88.0501097 2002 Armstrong World Industries Inc 008 -88.0501097 2002 Armstrong World Industries Inc 009 -88.0501097 2002 Armstrong World Industries Inc 010 -88.0501097 2002 Armstrong World Industries Inc 011 -88.0501097 2002 Armstrong World Industries Inc 013 -88.0501097 2002 Armstrong World Industries Inc 014 -88.0501097 4019 MoBay Storage Hub, Inc 001 -88.22501097 4019 MoBay Storage Hub, Inc 002 -88.225
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 

01097 4019 MoBay Storage Hub, Inc 003 -88.22501097 6002 Bender Shipbuilding & Repair Co Inc 888 -88.0401097 6007 Alabama Shipyards Inc 001 -88.03201099 S011 Owens Lumber Company 001 -86.98101113 0018 Boral Bricks 001 -84.99801113 0018 Boral Bricks 002 -84.99801113 0018 Boral Bricks 003 -84.99801113 0018 Boral Bricks 005 -84.99801113 0018 Boral Bricks 006 -84.99801113 0018 Boral Bricks 007 -84.99801113 0018 Boral Bricks 888 -84.99801117 0005 Alabama Power Company 001 -86.45901117 0005 Alabama Power Company 002 -86.4501117 0005 Alabama Power Company 004 -86.4501117 0005 Alabama Power Company 888 -86.45901123 0015 Stone's Throw Landfill 888 -85.83101127 0015 S&M Paving Co. 001 -87.60912009 0090051 NASA 69 -80.6512031 0310010 BAPTIST MEDICAL CENTER 14 -81.66312031 0310213 U S NAVAL STATION MAYPORT 33 -81.40612031 0310213 U S NAVAL STATION MAYPORT 34 -81.41712031 0310213 U S NAVAL STATION MAYPORT 37 -81.41712031 0310325 TRANSFLO TERMINAL SERVICES, INC. 1 -81.72012045 0450002 ARIZONA CHEMICAL COMPANY, LLC 13 -85.30812045 0450002 ARIZONA CHEMICAL COMPANY, LLC 15 -85.30812045 0450002 ARIZONA CHEMICAL COMPANY, LLC 16 -85.30812045 0450002 ARIZONA CHEMICAL COMPANY, LLC 17 -85.30812045 0450002 ARIZONA CHEMICAL COMPANY, LLC 5 -85.30812045 0450002 ARIZONA CHEMICAL COMPANY, LLC 6 -85.30812057 0570094 MOSAIC FERTILIZER, LLC 100 -82.40
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 

12057 0570252 CEMEX 2 -82.43212057 0570252 CEMEX 4 -82.43212069 0694822 MIDDLESEX ASPHALT, L.L.C. 2 -81.90312099 0990350 SOUTH FLORIDA WATER MANAGEMENT DISTRICT 1 -80.44512103 1030011 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 5 -82.60112103 1030011 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 6 -82.60112103 1030011 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 7 -82.60112103 1030011 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 8 -82.60112109 1090022 LUHRS CORPORATION 1 -81.32112113 1130040 ODOM FIBERGLASS, INCORPORATED 1 -87.08713015 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 -81.5513039 03900003 Naval Submarine Base PT02 -81.5513039 03900003 Naval Submarine Base PT03 -81.5513039 03900003 Naval Submarine Base PT04 -81.5513039 03900003 Naval Submarine Base PT05 -81.5513039 03900003 Naval Submarine Base PT06 -81.5513039 03900003 Naval Submarine Base PT07 -81.5513039 03900003 Naval Submarine Base PT08 -81.5513039 03900003 Naval Submarine Base PT09 -81.5513039 03900003 Naval Submarine Base PT10 -81.5513039 03900003 Naval Submarine Base PT11 -81.5513039 03900003 Naval Submarine Base PT12 -81.5513039 03900003 Naval Submarine Base PT13 -81.5513039 03900003 Naval Submarine Base PT14 -81.55
Development of Point Source Emission Inventory for 2007 Southeastern States A

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State Fac 

ID Facility Name Release Point ID Long 

13039 03900003 Naval Submarine Base PT15 -81.5513039 03900003 Naval Submarine Base PT16 -81.5513045 04500052 Southwire Company Carrollton Utility Products Plant F722 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN11 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN12 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN13 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN15 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN16 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN17 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN18 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN2 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN3 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN4 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN5 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN6 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant FAN7 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S205 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S280 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S281 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S296 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S297 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S501 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S504 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S507 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S510 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S513 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S516 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S721 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S745 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant S760 -85.062
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

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FIPS 

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State Fac 

ID Facility Name Release Point ID Long 

13045 04500052 Southwire Company Carrollton Utility Products Plant S761 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant SCS12 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant SCS13 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant SCS14 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant SCS5 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant SCS6 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant SCS7 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant SCS8 -85.06213045 04500052 Southwire Company Carrollton Utility Products Plant SCS9 -85.06213049 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
Development of Point Source Emission Inventory for 2007 Southeastern States A

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8-A 

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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 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S10 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S11 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S12 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S13 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S14 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S2 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S3 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S4 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S5 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S6 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S7 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S8 -81.1213051 05100148 ARIZONA CHEMICAL CORP. S9 -81.1213051 05100152 Savannah Resource Recovery (Montaney) ST01 -81.0213051 05100152 Savannah Resource Recovery (Montaney) ST02 -81.0213063 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 -82.7713065 06500005 Bway Manufacturing Inc S1 -82.7713065 06500005 Bway Manufacturing Inc S13 -82.7713065 06500005 Bway Manufacturing Inc S15 -82.7713065 06500005 Bway Manufacturing Inc S16 -82.7713065 06500005 Bway Manufacturing Inc S2 -82.7713065 06500005 Bway Manufacturing Inc S20 -82.77
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

9-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

13065 06500005 Bway Manufacturing Inc S3 -82.7713065 06500005 Bway Manufacturing Inc S9 -82.7713067 06700032 Marathon Petroleum Company LLC - Powder Springs Terminal FUG -84.6313067 06700032 Marathon Petroleum Company LLC - Powder Springs Terminal VCS -84.6313073 07300003 Quebecor World Kri Inc. FUG -82.1113073 07300003 Quebecor World Kri Inc. S1 -82.1113073 07300003 Quebecor World Kri Inc. S10 -82.1113073 07300003 Quebecor World Kri Inc. S11 -82.1113073 07300003 Quebecor World Kri Inc. S12 -82.1113081 08100054 Norbord Georgia Inc S001 -83.8013081 08100054 Norbord Georgia Inc S003 -83.8013081 08100054 Norbord Georgia Inc S004 -83.8013081 08100054 Norbord Georgia Inc S010 -83.8013081 08100054 Norbord Georgia Inc S011 -83.8013081 08100054 Norbord Georgia Inc S012 -83.8013081 08100054 Norbord Georgia Inc S013 -83.8013081 08100054 Norbord Georgia Inc S063 -83.8013089 08900085 Magellan Terminal Holdings, L.P. - Doraville I Terminal FUG -84.26913089 08900085 Magellan Terminal Holdings, L.P. - Doraville I Terminal S1 -84.26913089 08900128 Transmontaigne Terminaling Inc CGLK -84.27313089 08900128 Transmontaigne Terminaling Inc FUG -84.27313089 08900128 Transmontaigne Terminaling Inc ST8501 -84.27313089 08900128 Transmontaigne Terminaling Inc ST8502 -84.27313089 08900128 Transmontaigne Terminaling Inc ST8504 -84.27313089 08900128 Transmontaigne Terminaling Inc ST8505 -84.27313089 08900128 Transmontaigne Terminaling Inc ST8506 -84.27313089 08900128 Transmontaigne Terminaling Inc ST8507 -84.27313089 08900128 Transmontaigne Terminaling Inc ST8509 -84.27313089 08900128 Transmontaigne Terminaling Inc ST8510 -84.27313089 08900128 Transmontaigne Terminaling Inc ST8515 -84.273
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

10-A 

FIPS 

Code

State Fac 

ID Facility Name Release Point ID Long 

13089 08900128 Transmontaigne Terminaling Inc ST8516 -84.27313089 08900128 Transmontaigne Terminaling Inc STLOAD -84.27313089 08900128 Transmontaigne Terminaling Inc STVCU -84.27313089 08900128 Transmontaigne Terminaling Inc STVRU -84.27313095 09500010 MillerCoors LLC F036 -84.0813095 09500010 MillerCoors LLC S001 -84.0813095 09500010 MillerCoors LLC S003 -84.0813095 09500010 MillerCoors LLC S034 -84.0813099 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
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

11-A 

FIPS 

Code

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 -85.013115 11500077 Metal Container Corporation 30 -85.013115 11500077 Metal Container Corporation 32 -85.013115 11500077 Metal Container Corporation 37 -85.013115 11500077 Metal Container Corporation 44 -85.013115 11500077 Metal Container Corporation 61 -85.013115 11500077 Metal Container Corporation FUG -85.013115 11500077 Metal Container Corporation FUG2 -85.013121 12100807 Delta Airlines - General Office Facilities S1 -84.423
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

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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 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 16 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 18 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 2 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 21 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 22 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 23 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 27 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 29 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 35 -82.4413125 12500001 Thiele Kaolin Co Reedy Creek Div 4 -82.4413127 12700002 Hercules Inc EAS1 -81.4813127 12700002 Hercules Inc EAS3 -81.4813127 12700002 Hercules Inc EAS4 -81.4813127 12700002 Hercules Inc EAS5 -81.4813127 12700002 Hercules Inc EBS1 -81.4813127 12700002 Hercules Inc FUG -81.4813127 12700002 Hercules Inc HRS4 -81.4813127 12700002 Hercules Inc HRS7 -81.4813127 12700002 Hercules Inc LR02 -81.4813127 12700002 Hercules Inc LRS1 -81.4813127 12700002 Hercules Inc PAS1 -81.4813127 12700002 Hercules Inc PS09 -81.4813127 12700002 Hercules Inc PS10 -81.4813127 12700002 Hercules Inc PXS1 -81.4813127 12700002 Hercules Inc RS1 -81.4813127 12700002 Hercules Inc SAS4 -81.48
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

13-A 

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ID Facility Name Release Point ID Long 

13127 12700002 Hercules Inc SAS5 -81.4813127 12700002 Hercules Inc SC40 -81.4813127 12700002 Hercules Inc SP06 -81.4813127 12700002 Hercules Inc SPS1 -81.4813127 12700002 Hercules Inc TR08 -81.4813127 12700002 Hercules Inc TRS3 -81.4813127 12700002 Hercules Inc VS03 -81.4813127 12700002 Hercules Inc VSTACK -81.4813127 12700027 Georgia-Pacific Corporation PS1 -81.5413127 12700027 Georgia-Pacific Corporation PS2 -81.5413127 12700027 Georgia-Pacific Corporation PS3 -81.5413127 12700027 Georgia-Pacific Corporation S201 -81.5413127 12700027 Georgia-Pacific Corporation S202 -81.5413127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT C201 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT C301 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT C401 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT C402 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT CDBH -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT GYBH -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU1 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU2 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU3 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU4 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU5 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KBU6 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT KILN -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT PLBH -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT PLOC -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT RMB1 -81.4813127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT RMB2 -81.48
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

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ID Facility Name Release Point ID Long 

13127 12700028 G-P GYPSUM CORP. - BRUNSWICK PLANT RMB3 -81.4813139 13900075 Indalex America Inc FUG1 -83.8513139 13900075 Indalex America Inc PL1 -83.8513139 13900075 Indalex America Inc RTO1 -83.8513175 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 -83.10113175 17500035 Gilman Paper Co KL02 -83.10113175 17500035 Gilman Paper Co KL03 -83.10113213 21300034 Kgen Murray 1 & 2 LLC AUXB1 -84.91813213 21300034 Kgen Murray 1 & 2 LLC AUXB2 -84.91813213 21300034 Kgen Murray 1 & 2 LLC CT1 -84.91813213 21300034 Kgen Murray 1 & 2 LLC CT2 -84.91813213 21300034 Kgen Murray 1 & 2 LLC CT3 -84.91813213 21300034 Kgen Murray 1 & 2 LLC CT4 -84.91813237 23700010 Rayonier Inc- Eatonton Sawmill DKF1 -83.3613237 23700010 Rayonier Inc- Eatonton Sawmill DKF2 -83.3613237 23700010 Rayonier Inc- Eatonton Sawmill PBS1 -83.3613237 23700010 Rayonier Inc- Eatonton Sawmill PMF1 -83.3613237 23700010 Rayonier Inc- Eatonton Sawmill SM01 -83.36
Development of Point Source Emission Inventory for 2007 Southeastern States A

AMEC Project No.: 6066-09-0326.02 

15-A 

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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 -81.9813245 24500023 Occidental Chemical Co STK2 -81.9813245 24500068 Procter & Gamble Manufacturing Co G001 -82.0013245 24500068 Procter & Gamble Manufacturing Co G002 -82.0013245 24500068 Procter & Gamble Manufacturing Co G003 -82.0013245 24500068 Procter & Gamble Manufacturing Co G004 -82.0013245 24500068 Procter & Gamble Manufacturing Co P045 -82.0013245 24500068 Procter & Gamble Manufacturing Co P057 -82.0013245 24500068 Procter & Gamble Manufacturing Co P086 -82.0013261 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
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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 -84.3813269 26900016 Taylor County LFGTE Power Station S02 -84.3813269 26900016 Taylor County LFGTE Power Station S03 -84.3813269 26900016 Taylor County LFGTE Power Station S04 -84.3813275 27500008 Hood Industries, Inc. B2 -83.9813275 27500008 Hood Industries, Inc. B3 -83.9813275 27500008 Hood Industries, Inc. B4 -83.9813275 27500008 Hood Industries, Inc. DK1 -83.9813275 27500008 Hood Industries, Inc. DK2 -83.9813275 27500008 Hood Industries, Inc. DK3 -83.9813275 27500008 Hood Industries, Inc. FUG -83.9813275 27500008 Hood Industries, Inc. PMC1 -83.9813275 27500008 Hood Industries, Inc. PMC2 -83.9813313 31300084 Shaw Industries Inc. Plant No.: 4 BS02 -84.9613313 31300084 Shaw Industries Inc. Plant No.: 4 BS03 -84.9613313 31300084 Shaw Industries Inc. Plant No.: 4 BS04 -84.9613313 31300084 Shaw Industries Inc. Plant No.: 4 LS02 -84.9613313 31300084 Shaw Industries Inc. Plant No.: 4 LS03 -84.9621003 00002 Irving Materials Inc 01--02 -86.18721003 00002 Irving Materials Inc 02--02 -86.18721003 00002 Irving Materials Inc 03--02 -86.18721003 00002 Irving Materials Inc 05--02 -86.18721003 00002 Irving Materials Inc 06--02 -86.18721003 00002 Irving Materials Inc 06--03 -86.18721003 00002 Irving Materials Inc 06--04 -86.18721003 00002 Irving Materials Inc 07--01 -86.18721015 00069 Camco Chemical Co 001 -84.6
Development of Point Source Emission Inventory for 2007 Southeastern States A

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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 -84.621015 00118 Diversified Structural Composites 003 -84.621015 00118 Diversified Structural Composites 005 -84.621015 00118 Diversified Structural Composites 006 -84.621015 00118 Diversified Structural Composites MP11 -84.621015 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
Development of Point Source Emission Inventory for 2007 Southeastern States A

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ID Facility Name Release Point ID Long 

21025 00033 Begley Properties LLC 001 -83.41821025 00033 Begley Properties LLC 002 -83.41821037 00051 Freeport Mcmoran Resource 001 -84.3521037 00051 Freeport Mcmoran Resource 002 -84.3521037 00097 DDA Partnership 001 -84.46321045 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 -84.9421045 00028 Casey Furniture Mfg, Llc 002 -84.9421045 00028 Casey Furniture Mfg, Llc 003 -84.9421045 00028 Casey Furniture Mfg, Llc 004 -84.9421045 00028 Casey Furniture Mfg, Llc 005 -84.9421051 00034 Chas Coal LLC - Red Bird Prep Plant 001 -83.5321051 00034 Chas Coal LLC - Red Bird Prep Plant 002 -83.5321051 00034 Chas Coal LLC - Red Bird Prep Plant 003 -83.5321051 00034 Chas Coal LLC - Red Bird Prep Plant 004 -83.5321057 00005 Albany Redi-Mix 001 -85.3621057 00005 Albany Redi-Mix 002 -85.3621057 00005 Albany Redi-Mix 003 -85.3621071 00154 Chesapeake Appalachia LLC - Warco Transmission Station E01 -82.721071 00154 Chesapeake Appalachia LLC - Warco Transmission Station E02 -82.721071 00154 Chesapeake Appalachia LLC - Warco Transmission Station E03A -82.721071 00154 Chesapeake Appalachia LLC - Warco Transmission Station E03B -82.721071 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 -82.721071 00159 EQT Gathering LLC - Maytown Compressor Station 002 -82.721073 00079 Rogers Group Inc Portable Crush Plant 3 001 -84.21073 00079 Rogers Group Inc Portable Crush Plant 3 002 -84.21073 00079 Rogers Group Inc Portable Crush Plant 3 003 -84.
Development of Point Source Emission Inventory for 2007 Southeastern States A

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21073 00079 Rogers Group Inc Portable Crush Plant 3 004 -84.21073 00079 Rogers Group Inc Portable Crush Plant 3 005 -84.21073 00079 Rogers Group Inc Portable Crush Plant 3 006 -84.21073 00079 Rogers Group Inc Portable Crush Plant 3 007 -84.21077 00025 Sterling Ventures LLC 01--01 -84.721077 00025 Sterling Ventures LLC 01--02 -84.721077 00025 Sterling Ventures LLC 03--01 -84.721077 00025 Sterling Ventures LLC 05--01 -84.721077 00025 Sterling Ventures LLC 05--02 -84.721077 00025 Sterling Ventures LLC 05--03 -84.721077 00025 Sterling Ventures LLC 07--01 -84.721077 00025 Sterling Ventures LLC 17--01 -84.721077 00025 Sterling Ventures LLC 18--01 -84.721077 00025 Sterling Ventures LLC 25--01 -84.721077 00025 Sterling Ventures LLC 26--01 -84.721077 00025 Sterling Ventures LLC 27--01 -84.721077 00025 Sterling Ventures LLC 28--01 -84.721077 00025 Sterling Ventures LLC 28--02 -84.721077 00025 Sterling Ventures LLC 29--01 -84.721077 00025 Sterling Ventures LLC 29--02 -84.721077 00030 IMI South LLC EP0101 -84.821077 00030 IMI South LLC EP0103 -84.821077 00030 IMI South LLC EP0104 -84.821077 00030 IMI South LLC EP-02 -84.821077 00030 IMI South LLC EP0205 -84.821077 00030 IMI South LLC EP0206 -84.821077 00030 IMI South LLC EP0301 -84.821077 00030 IMI South LLC EP0302 -84.821077 00030 IMI South LLC EP0402 -84.821089 00044 Ashland Recovery Inc 001 -82.6
Development of Point Source Emission Inventory for 2007 Southeastern States A

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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) -86.21091 00026 L. R. Chapman (02) -86.21091 00026 L. R. Chapman (03) -86.21091 00026 L. R. Chapman (04) -86.21091 00026 L. R. Chapman (05) -86.21091 00026 L. R. Chapman (06) -86.21091 00026 L. R. Chapman (07) -86.21091 00026 L. R. Chapman (08) -86.21091 00026 L. R. Chapman (09) -86.21091 00026 L. R. Chapman (10) -86.21091 00026 L. R. Chapman (11) -86.21091 00026 L. R. Chapman (12) -86.21091 00026 L. R. Chapman (13) -86.21091 00026 L. R. Chapman (14) -86.21091 00026 L. R. Chapman (15) -86.21091 00026 L. R. Chapman (16) -86.21091 00026 L. R. Chapman (17) -86.21091 00026 L. R. Chapman (18) -86.21091 00026 L. R. Chapman (19) -86.21091 00026 L. R. Chapman (20) -86.21091 00026 L. R. Chapman (21) -86.21091 00026 L. R. Chapman (22) -86.21091 00026 L. R. Chapman (23) -86.21091 00026 L. R. Chapman (24) -86.
Development of Point Source Emission Inventory for 2007 Southeastern States A

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21091 00026 L. R. Chapman (25) -86.21091 00026 L. R. Chapman (26) -86.21091 00026 L. R. Chapman (27) -86.21091 00026 L. R. Chapman (28) -86.21091 00026 L. R. Chapman (29) -86.21091 00026 L. R. Chapman (30) -86.21091 00026 L. R. Chapman (31) -86.21091 00026 L. R. Chapman (32) -86.21091 00026 L. R. Chapman (33) -86.21091 00026 L. R. Chapman (34) -86.21091 00026 L. R. Chapman (35) -86.21091 00026 L. R. Chapman (36) -86.21091 00026 L. R. Chapman (37) -86.21091 00026 L. R. Chapman (38) -86.21091 00026 L. R. Chapman (39) -86.21091 00026 L. R. Chapman (40) -86.21091 00026 L. R. Chapman (41) -86.21091 00026 L. R. Chapman (42) -86.21091 00026 L. R. Chapman (43) -86.21091 00026 L. R. Chapman (44) -86.21091 00026 L. R. Chapman (45) -86.21091 00026 L. R. Chapman (46) -86.21091 00026 L. R. Chapman (47) -86.21091 00026 L. R. Chapman (48) -86.21091 00026 L. R. Chapman (49) -86.21091 00026 L. R. Chapman (50) -86.21091 00026 L. R. Chapman (51) -86.21091 00026 L. R. Chapman (52) -86.21101 00139 Kentucky 5 Star Energy LLC FS01 -87.52421101 00139 Kentucky 5 Star Energy LLC FS02 -87.524
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 -87.621107 00146 Hopkinsville Wood Products 002 -87.621107 00156 J-Lok Corp EP-AU- -87.4821107 00156 J-Lok Corp EP-V-1 -87.4821107 00156 J-Lok Corp EP-V-2 -87.4821107 00156 J-Lok Corp EP-V-3 -87.4821117 00165 Laser Graphic Systems 001 -84.62721117 00165 Laser Graphic Systems 002 -84.62721117 00165 Laser Graphic Systems 003 -84.627
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 -84.621117 00176 Alstom Power Inc EP1 -84.621117 00176 Alstom Power Inc EP2 -84.621119 00038 Chesapeake Appalachia LLC - Brinkley Transmission Station 001 -82.9421119 00040 Chesapeake Appalachia LLC - Lackey Transmission Station 001 -82.821119 00041 ICG Knott Co - Raven Coal Preperation Plant Group1 -82.82321119 00041 ICG Knott Co - Raven Coal Preperation Plant Group2 -82.82321119 00041 ICG Knott Co - Raven Coal Preperation Plant Group3 -82.82321121 00032 Gatliff Coal Co - ADA Tipple 5 001 -83.8221121 00032 Gatliff Coal Co - ADA Tipple 5 002 -83.8221121 00032 Gatliff Coal Co - ADA Tipple 5 003 -83.8221125 00084 Admiralty Boats Inc 001 -84.021125 00084 Admiralty Boats Inc 002 -84.021125 00084 Admiralty Boats Inc 003 -84.021125 00084 Admiralty Boats Inc 005 -84.021125 00084 Admiralty Boats Inc 006 -84.021125 00106 ABC Automotive Systems Inc EP1-21 -84.0321125 00106 ABC Automotive Systems Inc EP22 -84.0321125 00106 ABC Automotive Systems Inc EP23 -84.0321125 00106 ABC Automotive Systems Inc EP24 -84.0321133 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
Development of Point Source Emission Inventory for 2007 Southeastern States A

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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 -85.5621183 00069 Western KY Energy Corp - Wilson Station EU-01 -87.07921183 00069 Western KY Energy Corp - Wilson Station EU-02 -87.07921183 00069 Western KY Energy Corp - Wilson Station EU-03 -87.07921183 00069 Western KY Energy Corp - Wilson Station EU-04 -87.07921183 00069 Western KY Energy Corp - Wilson Station EU-05 -87.07921183 00069 Western KY Energy Corp - Wilson Station IA -87.07921195 00267 EQT Gathering LLC - Rockhouse Compressor Station 01 -82.321195 00267 EQT Gathering LLC - Rockhouse Compressor Station 02 -82.321207 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 -86.621213 00029 South Union Elevator 002 -86.621213 00029 South Union Elevator 003 -86.621213 00029 South Union Elevator 004 -86.621213 00029 South Union Elevator 005 -86.621217 00033 TN Gas Pipeline - Station 96 001 -85.321217 00033 TN Gas Pipeline - Station 96 FUG01 -85.321217 00035 Ambrake Corp 001 -85.321217 00035 Ambrake Corp 002 -85.3
Development of Point Source Emission Inventory for 2007 Southeastern States A

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21217 00035 Ambrake Corp 003 -85.321219 00013 Koppers Industries,Inc 001 -87.121219 00013 Koppers Industries,Inc 002a -87.121219 00013 Koppers Industries,Inc 002b -87.121219 00013 Koppers Industries,Inc 003 -87.121219 00013 Koppers Industries,Inc 004 -87.121219 00013 Koppers Industries,Inc 005 -87.121219 00013 Koppers Industries,Inc 006 -87.121233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 001 -87.77421233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 002 -87.77421233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 003 -87.77421233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 004 -87.77421233 00008 Webster Co Coal LLC - Dotiki Mine Prep Plant 005 -87.77437021 0735 Western Animal Disease Diagnostic Laboratory ES-1 -82.37057 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 -80.945003 0080-0011 SCE&G URQUHART 3 -81.945015 0420-0015 ALUMAX OF SOUTH CAROLINA 1 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 10 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 100 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 101 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 11 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 12 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 122 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 123 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 124 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 13 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 14 -80.0
Development of Point Source Emission Inventory for 2007 Southeastern States A

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45015 0420-0015 ALUMAX OF SOUTH CAROLINA 15 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 16 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 17 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 18 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 19 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 2 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 20 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 21 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 22 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 24 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 26 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 27 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 28 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 29 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 3 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 30 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 31 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 32 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 33 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 34 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 35 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 36 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 37 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 38 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 39 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 4 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 40 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 41 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 42 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 43 -80.0
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45015 0420-0015 ALUMAX OF SOUTH CAROLINA 44 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 45 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 46 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 47 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 5 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 50 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 51 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 52 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 53 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 54 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 55 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 57 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 58 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 59 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 6 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 60 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 61 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 62 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 63 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 64 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 65 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 66 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 67 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 68 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 69 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 7 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 8 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 80 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 81 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 83 -80.0
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State Fac 

ID Facility Name Release Point ID Long 

45015 0420-0015 ALUMAX OF SOUTH CAROLINA 84 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 85 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 86 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 87 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 9 -80.045015 0420-0015 ALUMAX OF SOUTH CAROLINA 95 -80.045015 0420-0094 SEA FOX BOAT COMPANY 1 -80.045019 0560-0029 SCE&G HAGOOD 1 -79.945059 1520-0066 FAURECIA INTERIOR SYS USA FOUNTAIN INN 57 -82.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 1 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 10 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 11 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 12 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 13 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 14 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 15 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 16 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 17 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 18 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 19 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 2 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 20 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 21 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 22 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 227 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 3 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 4 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 6 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 7 -81.145063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 8 -81.1
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ID Facility Name Release Point ID Long 

45063 1560-0016 SHAW INDUSTRIES GROUP INC PLANT 8S 9 -81.145081 1940-0007 SIMPSON LBR CO JOHNSTON LBR MILL 1 -81.845081 1940-0007 SIMPSON LBR CO JOHNSTON LBR MILL 2 -81.845081 1940-0007 SIMPSON LBR CO JOHNSTON LBR MILL 6 -81.845081 1940-0007 SIMPSON LBR CO JOHNSTON LBR MILL 7 -81.847009 0176 USI, INC. SPB-1 -83.93347009 0176 USI, INC. SPB-2 -83.93347009 0176 USI, INC. SPB-3 -83.93347009 0176 USI, INC. SPB-4 -83.93347009 0176 USI, INC. SPB-5 -83.93347009 0176 USI, INC. SPB-6 -83.93347011 0215 ARCH CHEMICALS, INC. H-12V -84.7847011 0215 ARCH CHEMICALS, INC. H-13E -84.7847011 0215 ARCH CHEMICALS, INC. H-1E -84.7847011 0215 ARCH CHEMICALS, INC. H-2E -84.7847011 0215 ARCH CHEMICALS, INC. H-3E -84.7847011 0215 ARCH CHEMICALS, INC. H-5E -84.7847011 0215 ARCH CHEMICALS, INC. H-7E -84.7847011 0215 ARCH CHEMICALS, INC. H-89BH -84.7847011 0215 ARCH CHEMICALS, INC. H-8BH -84.7847011 0215 ARCH CHEMICALS, INC. H-9BH -84.7847011 0215 ARCH CHEMICALS, INC. H-P10 -84.7847011 0215 ARCH CHEMICALS, INC. H-P11 -84.7847017 0012 NORANDAL USA, INC. 801HD -88.38147017 0012 NORANDAL USA, INC. 801MR -88.38147017 0012 NORANDAL USA, INC. 802HD -88.38147017 0012 NORANDAL USA, INC. 802M -88.38147017 0012 NORANDAL USA, INC. 803HD -88.38147017 0012 NORANDAL USA, INC. 803M -88.38147017 0012 NORANDAL USA, INC. 804HD -88.381
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47017 0012 NORANDAL USA, INC. 804M -88.38147017 0012 NORANDAL USA, INC. 901H -88.38147017 0012 NORANDAL USA, INC. 901M -88.38147017 0012 NORANDAL USA, INC. 902H -88.38147017 0012 NORANDAL USA, INC. 902M -88.38147017 0012 NORANDAL USA, INC. 903HD -88.38147017 0012 NORANDAL USA, INC. 903M -88.38147017 0012 NORANDAL USA, INC. 904HD -88.38147017 0012 NORANDAL USA, INC. 905MHD -88.38147017 0012 NORANDAL USA, INC. AHON -88.38147017 0012 NORANDAL USA, INC. AHOS -88.38147017 0012 NORANDAL USA, INC. FUG-01 -88.38147017 0012 NORANDAL USA, INC. RM1 -88.38147017 0012 NORANDAL USA, INC. S-05A -88.38147017 0012 NORANDAL USA, INC. S-05B -88.38147017 0012 NORANDAL USA, INC. S-05C -88.38147017 0012 NORANDAL USA, INC. S-05D -88.38147017 0012 NORANDAL USA, INC. S-05E -88.38147017 0012 NORANDAL USA, INC. S-05F -88.38147017 0012 NORANDAL USA, INC. S-05G -88.38147017 0012 NORANDAL USA, INC. S-05H -88.38147017 0012 NORANDAL USA, INC. S-05I -88.38147017 0012 NORANDAL USA, INC. S-05J -88.38147017 0012 NORANDAL USA, INC. S-05K -88.38147017 0012 NORANDAL USA, INC. S-05L -88.38147017 0012 NORANDAL USA, INC. S-08A -88.38147017 0012 NORANDAL USA, INC. S-08B -88.38147017 0012 NORANDAL USA, INC. S-14A -88.38147017 0012 NORANDAL USA, INC. S-14B -88.38147017 0012 NORANDAL USA, INC. S-14C -88.381
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ID Facility Name Release Point ID Long 

47017 0012 NORANDAL USA, INC. S-14D -88.38147017 0012 NORANDAL USA, INC. S-19A -88.38147017 0012 NORANDAL USA, INC. S-23A -88.38147017 0012 NORANDAL USA, INC. S-31A -88.38147025 0083 DTR TENNESSEE, INC 001 -83.547025 0083 DTR TENNESSEE, INC 002 -83.547025 0083 DTR TENNESSEE, INC 003 -83.547025 0083 DTR TENNESSEE, INC 004 -83.547025 0083 DTR TENNESSEE, INC 009 -83.547025 0083 DTR TENNESSEE, INC 010 -83.547025 0083 DTR TENNESSEE, INC 011 -83.547025 0083 DTR TENNESSEE, INC 012 -83.547041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. 001 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-001 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-002 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-003 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-004 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-006 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-007 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-008 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-009 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-010 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-011 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-012 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-021 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-022 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-024 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-029 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-030 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-031 -85.8032441139
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47041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-032 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-033 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-034 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-040 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-041 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-042 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-043 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-048 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-049 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-050 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-051 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-052 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-054 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-055 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-062 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-063 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-064 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-065 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-066 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-067 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-068 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-069 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-082 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-083 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-084 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-085 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-086 -85.803244113947041 0031 FEDERAL MOGUL CORPORATION FRICTION PRODUCTS, INC. S-087 -85.803244113947043 0079 MASONITE DOOR CORPORATION EP12 -87.3347043 0079 MASONITE DOOR CORPORATION EP6 -87.33
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ID Facility Name Release Point ID Long 

47043 0079 MASONITE DOOR CORPORATION FUG1 -87.3347059 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 -82.747073 0001 HOLLISTON MILLS, INC. C1W -82.747073 0001 HOLLISTON MILLS, INC. E19F -82.747073 0001 HOLLISTON MILLS, INC. E4F -82.747073 0001 HOLLISTON MILLS, INC. E53F -82.747073 0001 HOLLISTON MILLS, INC. E5F -82.747073 0001 HOLLISTON MILLS, INC. E61F -82.747073 0001 HOLLISTON MILLS, INC. E9F -82.747073 0001 HOLLISTON MILLS, INC. F1M -82.747073 0001 HOLLISTON MILLS, INC. F2M -82.747073 0001 HOLLISTON MILLS, INC. P10A -82.747073 0001 HOLLISTON MILLS, INC. P10F -82.747073 0001 HOLLISTON MILLS, INC. P11A -82.747073 0001 HOLLISTON MILLS, INC. P11AF -82.747073 0001 HOLLISTON MILLS, INC. P11F -82.747073 0001 HOLLISTON MILLS, INC. P12A -82.747073 0001 HOLLISTON MILLS, INC. P12F -82.747073 0001 HOLLISTON MILLS, INC. P13F -82.747073 0001 HOLLISTON MILLS, INC. P14F -82.747073 0001 HOLLISTON MILLS, INC. P15F -82.747073 0001 HOLLISTON MILLS, INC. P16F -82.747073 0001 HOLLISTON MILLS, INC. P17F -82.747073 0001 HOLLISTON MILLS, INC. P19F -82.747073 0001 HOLLISTON MILLS, INC. P1A -82.7
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ID Facility Name Release Point ID Long 

47073 0001 HOLLISTON MILLS, INC. P20A -82.747073 0001 HOLLISTON MILLS, INC. P20F -82.747073 0001 HOLLISTON MILLS, INC. P21A -82.747073 0001 HOLLISTON MILLS, INC. P21F -82.747073 0001 HOLLISTON MILLS, INC. P22F -82.747073 0001 HOLLISTON MILLS, INC. P23F -82.747073 0001 HOLLISTON MILLS, INC. P24F -82.747073 0001 HOLLISTON MILLS, INC. P25F -82.747073 0001 HOLLISTON MILLS, INC. P26F -82.747073 0001 HOLLISTON MILLS, INC. P2A -82.747073 0001 HOLLISTON MILLS, INC. P34F -82.747073 0001 HOLLISTON MILLS, INC. P35F -82.747073 0001 HOLLISTON MILLS, INC. P36F -82.747073 0001 HOLLISTON MILLS, INC. P37F -82.747073 0001 HOLLISTON MILLS, INC. P38F -82.747073 0001 HOLLISTON MILLS, INC. P3A -82.747073 0001 HOLLISTON MILLS, INC. P3F -82.747073 0001 HOLLISTON MILLS, INC. P43F -82.747073 0001 HOLLISTON MILLS, INC. P44F -82.747073 0001 HOLLISTON MILLS, INC. P45F -82.747073 0001 HOLLISTON MILLS, INC. P46F -82.747073 0001 HOLLISTON MILLS, INC. P48F -82.747073 0001 HOLLISTON MILLS, INC. P49F -82.747073 0001 HOLLISTON MILLS, INC. P4A -82.747073 0001 HOLLISTON MILLS, INC. P4F -82.747073 0001 HOLLISTON MILLS, INC. P51F -82.747073 0001 HOLLISTON MILLS, INC. P58F -82.747073 0001 HOLLISTON MILLS, INC. P5A -82.747073 0001 HOLLISTON MILLS, INC. P5AF -82.747073 0001 HOLLISTON MILLS, INC. P5F -82.7
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ID Facility Name Release Point ID Long 

47073 0001 HOLLISTON MILLS, INC. P60F -82.747073 0001 HOLLISTON MILLS, INC. P62F -82.747073 0001 HOLLISTON MILLS, INC. P63F -82.747073 0001 HOLLISTON MILLS, INC. P67F -82.747073 0001 HOLLISTON MILLS, INC. P6A -82.747073 0001 HOLLISTON MILLS, INC. P6AF -82.747073 0001 HOLLISTON MILLS, INC. P6F -82.747073 0001 HOLLISTON MILLS, INC. P7A -82.747073 0001 HOLLISTON MILLS, INC. P7F -82.747073 0001 HOLLISTON MILLS, INC. P8A -82.747073 0001 HOLLISTON MILLS, INC. P8F -82.747073 0001 HOLLISTON MILLS, INC. P9A -82.747073 0001 HOLLISTON MILLS, INC. P9F -82.747075 0039 HAYWOOD COMPANY 9_A -89.240647075 0039 HAYWOOD COMPANY 9_B -89.240647075 0039 HAYWOOD COMPANY BIN_10 -89.240647075 0039 HAYWOOD COMPANY C114 -89.240647075 0039 HAYWOOD COMPANY C115 -89.240647075 0039 HAYWOOD COMPANY C116 -89.240647075 0039 HAYWOOD COMPANY C117 -89.240647075 0039 HAYWOOD COMPANY C118 -89.240647075 0039 HAYWOOD COMPANY C119 -89.240647075 0039 HAYWOOD COMPANY C120 -89.240647075 0039 HAYWOOD COMPANY C121 -89.240647075 0039 HAYWOOD COMPANY C122 -89.240647075 0039 HAYWOOD COMPANY C124 -89.240647075 0039 HAYWOOD COMPANY C125 -89.240647075 0039 HAYWOOD COMPANY C126 -89.240647075 0039 HAYWOOD COMPANY C127 -89.240647075 0039 HAYWOOD COMPANY C128 -89.2406
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47075 0039 HAYWOOD COMPANY C427 -89.240647075 0039 HAYWOOD COMPANY C63 -89.240647075 0039 HAYWOOD COMPANY C64 -89.240647075 0039 HAYWOOD COMPANY C65 -89.240647075 0039 HAYWOOD COMPANY C66 -89.240647075 0039 HAYWOOD COMPANY C67 -89.240647075 0039 HAYWOOD COMPANY C68 -89.240647075 0039 HAYWOOD COMPANY C69 -89.240647075 0039 HAYWOOD COMPANY C70 -89.240647075 0039 HAYWOOD COMPANY C71 -89.240647075 0039 HAYWOOD COMPANY C72 -89.240647075 0039 HAYWOOD COMPANY C73 -89.240647075 0039 HAYWOOD COMPANY C74 -89.240647075 0039 HAYWOOD COMPANY C75 -89.240647075 0039 HAYWOOD COMPANY C76 -89.240647075 0039 HAYWOOD COMPANY C77 -89.240647075 0039 HAYWOOD COMPANY C78 -89.240647075 0039 HAYWOOD COMPANY C79 -89.240647075 0039 HAYWOOD COMPANY C80 -89.240647075 0039 HAYWOOD COMPANY C81 -89.240647075 0039 HAYWOOD COMPANY C82 -89.240647075 0039 HAYWOOD COMPANY C83 -89.240647075 0039 HAYWOOD COMPANY C84 -89.240647075 0039 HAYWOOD COMPANY C85 -89.240647075 0039 HAYWOOD COMPANY C86 -89.240647075 0039 HAYWOOD COMPANY C87 -89.240647075 0039 HAYWOOD COMPANY C88 -89.240647075 0039 HAYWOOD COMPANY C89 -89.240647075 0039 HAYWOOD COMPANY C90 -89.240647075 0039 HAYWOOD COMPANY C91 -89.2406
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47075 0039 HAYWOOD COMPANY CEMENT -89.240647075 0039 HAYWOOD COMPANY FCM_7 -89.240647075 0039 HAYWOOD COMPANY FP3_MI -89.240647075 0039 HAYWOOD COMPANY H196 -89.240647075 0039 HAYWOOD COMPANY HOSE -89.240647075 0039 HAYWOOD COMPANY Line10 -89.240647075 0039 HAYWOOD COMPANY MB1_MI -89.240647075 0039 HAYWOOD COMPANY MILL_1 -89.240647075 0039 HAYWOOD COMPANY MILL_2 -89.240647075 0039 HAYWOOD COMPANY MILL_5 -89.240647075 0039 HAYWOOD COMPANY MILL_6 -89.240647075 0039 HAYWOOD COMPANY MILL34 -89.240647075 0039 HAYWOOD COMPANY N 112 -89.240647075 0039 HAYWOOD COMPANY N1 -89.240647075 0039 HAYWOOD COMPANY PRESS1 -89.240647075 0039 HAYWOOD COMPANY PRESS2 -89.240647075 0039 HAYWOOD COMPANY PRESS3 -89.240647075 0039 HAYWOOD COMPANY PRESS4 -89.240647075 0039 HAYWOOD COMPANY PRESS5 -89.240647075 0039 HAYWOOD COMPANY PVC_WE -89.240647075 0039 HAYWOOD COMPANY RE46 -89.240647075 0039 HAYWOOD COMPANY RE47 -89.240647075 0039 HAYWOOD COMPANY REXT -89.240647075 0039 HAYWOOD COMPANY RU_101 -89.240647075 0039 HAYWOOD COMPANY RU_112 -89.240647075 0039 HAYWOOD COMPANY RU_23 -89.240647075 0039 HAYWOOD COMPANY RU_32 -89.240647075 0039 HAYWOOD COMPANY RU_69 -89.240647075 0039 HAYWOOD COMPANY RU_70 -89.240647075 0039 HAYWOOD COMPANY RU_93 -89.2406
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47075 0039 HAYWOOD COMPANY SILO-1 -89.240647075 0039 HAYWOOD COMPANY SILO-2 -89.240647075 0039 HAYWOOD COMPANY SILO-3 -89.240647075 0039 HAYWOOD COMPANY SILO-4 -89.240647075 0039 HAYWOOD COMPANY SILO-5 -89.240647075 0039 HAYWOOD COMPANY SILO-6 -89.240647075 0039 HAYWOOD COMPANY SILO-7 -89.240647075 0039 HAYWOOD COMPANY SILO-8 -89.240647075 0039 HAYWOOD COMPANY UNIT_8 -89.240647075 0039 HAYWOOD COMPANY UNIT_9 -89.240647089 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 -83.4747219085

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-007 -83.4747219085

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-008 -83.4747219085

47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-009 -83.4747219085
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47089 0006 FIVE RIVERS ELECTRONIC INNOVATIONS, LLC. - CABINET 

DIVISION

S-010 -83.4747219085

47105 0098 MALIBU BOATS WEST, INC. S-G2 -84.32947105 0098 MALIBU BOATS WEST, INC. S-G3 -84.32947109 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
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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
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47117 0013 ROGERS GROUP, INC S-001A -86.774606108647117 0013 ROGERS GROUP, INC S-001B -86.774606108647119 0132 SATURN CORPORATION FUG110 -86.96347119 0132 SATURN CORPORATION FUG126 -86.96347119 0132 SATURN CORPORATION FUG130 -86.96347119 0132 SATURN CORPORATION FUG133 -86.96347119 0132 SATURN CORPORATION FUG136 -86.96347119 0132 SATURN CORPORATION FUG145 -86.96347119 0132 SATURN CORPORATION S-1022 -86.96347119 0132 SATURN CORPORATION S-1042 -86.96347119 0132 SATURN CORPORATION S-1044 -86.96347119 0132 SATURN CORPORATION S-1122 -86.96347119 0132 SATURN CORPORATION S-1142 -86.96347119 0132 SATURN CORPORATION S-1144 -86.96347119 0132 SATURN CORPORATION S-120 -86.96347119 0132 SATURN CORPORATION S-121 -86.96347119 0132 SATURN CORPORATION S-123 -86.96347119 0132 SATURN CORPORATION S-124 -86.96347119 0132 SATURN CORPORATION S-1242 -86.96347119 0132 SATURN CORPORATION S-1244 -86.96347119 0132 SATURN CORPORATION S-125 -86.96347119 0132 SATURN CORPORATION S-127 -86.96347119 0132 SATURN CORPORATION S-128 -86.96347119 0132 SATURN CORPORATION S-131 -86.96347119 0132 SATURN CORPORATION S-132 -86.96347119 0132 SATURN CORPORATION S-1322 -86.96347119 0132 SATURN CORPORATION S-1342 -86.96347119 0132 SATURN CORPORATION S-1344 -86.96347119 0132 SATURN CORPORATION S-1422 -86.96347119 0132 SATURN CORPORATION S-144 -86.963
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47119 0132 SATURN CORPORATION S-1442 -86.96347119 0132 SATURN CORPORATION S-1444 -86.96347119 0132 SATURN CORPORATION S-1542 -86.96347119 0132 SATURN CORPORATION S-1544 -86.96347119 0132 SATURN CORPORATION S-1644 -86.96347119 0132 SATURN CORPORATION S-1722 -86.96347119 0132 SATURN CORPORATION S-1822 -86.96347119 0132 SATURN CORPORATION S-1922 -86.96347119 0132 SATURN CORPORATION S-2022 -86.96347119 0132 SATURN CORPORATION S-2122 -86.96347119 0132 SATURN CORPORATION S-224 -86.96347119 0132 SATURN CORPORATION S-225 -86.96347119 0132 SATURN CORPORATION S-227 -86.96347119 0132 SATURN CORPORATION S-228 -86.96347119 0132 SATURN CORPORATION S-231 -86.96347119 0132 SATURN CORPORATION S-232 -86.96347119 0132 SATURN CORPORATION S-2422 -86.96347119 0132 SATURN CORPORATION S-244 -86.96347119 0132 SATURN CORPORATION S-2522 -86.96347119 0132 SATURN CORPORATION S-324 -86.96347119 0132 SATURN CORPORATION S-325 -86.96347119 0132 SATURN CORPORATION S-328 -86.96347119 0132 SATURN CORPORATION S-331 -86.96347119 0132 SATURN CORPORATION S-332 -86.96347119 0132 SATURN CORPORATION S-344 -86.96347119 0132 SATURN CORPORATION S-425 -86.96347119 0132 SATURN CORPORATION S-428 -86.96347119 0132 SATURN CORPORATION S-431 -86.96347119 0132 SATURN CORPORATION S-432 -86.96347119 0132 SATURN CORPORATION S-444 -86.963
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47119 0132 SATURN CORPORATION S-523 -86.96347119 0132 SATURN CORPORATION S-531 -86.96347119 0132 SATURN CORPORATION S-532 -86.96347119 0132 SATURN CORPORATION S-542 -86.96347119 0132 SATURN CORPORATION S-544 -86.96347119 0132 SATURN CORPORATION S-621 -86.96347119 0132 SATURN CORPORATION S-623 -86.96347119 0132 SATURN CORPORATION S-624 -86.96347119 0132 SATURN CORPORATION S-625 -86.96347119 0132 SATURN CORPORATION S-631 -86.96347119 0132 SATURN CORPORATION S-632 -86.96347119 0132 SATURN CORPORATION S-644 -86.96347119 0132 SATURN CORPORATION S-721 -86.96347119 0132 SATURN CORPORATION S-723 -86.96347119 0132 SATURN CORPORATION S-724 -86.96347119 0132 SATURN CORPORATION S-731 -86.96347119 0132 SATURN CORPORATION S-744 -86.96347119 0132 SATURN CORPORATION S-821 -86.96347119 0132 SATURN CORPORATION S-823 -86.96347119 0132 SATURN CORPORATION S-824 -86.96347119 0132 SATURN CORPORATION S-831 -86.96347119 0132 SATURN CORPORATION S-844 -86.96347119 0132 SATURN CORPORATION S-922 -86.96347119 0132 SATURN CORPORATION S-924 -86.96347119 0132 SATURN CORPORATION S-942 -86.96347119 0132 SATURN CORPORATION S-944 -86.96347123 0089 SEA RAY BOATS, INC. TEL01 -84.26547123 0089 SEA RAY BOATS, INC. TEL02 -84.26547123 0089 SEA RAY BOATS, INC. TEL03 -84.26547123 0089 SEA RAY BOATS, INC. TEL05 -84.265
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47123 0089 SEA RAY BOATS, INC. TEL06 -84.26547123 0089 SEA RAY BOATS, INC. TEL07 -84.26547123 0089 SEA RAY BOATS, INC. TEL08 -84.26547123 0089 SEA RAY BOATS, INC. TEL09 -84.26547123 0089 SEA RAY BOATS, INC. TEL10 -84.26547123 0089 SEA RAY BOATS, INC. TEL11 -84.26547123 0089 SEA RAY BOATS, INC. TEL12 -84.26547123 0089 SEA RAY BOATS, INC. TEL13 -84.26547123 0089 SEA RAY BOATS, INC. TEL14 -84.26547123 0089 SEA RAY BOATS, INC. TEL15 -84.26547123 0089 SEA RAY BOATS, INC. TEL16 -84.26547123 0089 SEA RAY BOATS, INC. TEL17 -84.26547123 0089 SEA RAY BOATS, INC. TEL18 -84.26547123 0089 SEA RAY BOATS, INC. TEL19 -84.26547123 0089 SEA RAY BOATS, INC. TEL20 -84.26547123 0089 SEA RAY BOATS, INC. TEL21 -84.26547123 0089 SEA RAY BOATS, INC. TEL22 -84.26547123 0089 SEA RAY BOATS, INC. TEL23 -84.26547123 0089 SEA RAY BOATS, INC. TEL24 -84.26547123 0089 SEA RAY BOATS, INC. TEL25 -84.26547123 0089 SEA RAY BOATS, INC. TEL26 -84.26547123 0089 SEA RAY BOATS, INC. TEL27 -84.26547123 0089 SEA RAY BOATS, INC. TEL28 -84.26547123 0089 SEA RAY BOATS, INC. TEL29 -84.26547123 0089 SEA RAY BOATS, INC. TEL30 -84.26547123 0089 SEA RAY BOATS, INC. TEL31 -84.26547123 0089 SEA RAY BOATS, INC. TEL32 -84.26547123 0089 SEA RAY BOATS, INC. TEL33 -84.26547123 0089 SEA RAY BOATS, INC. TEL34 -84.26547123 0089 SEA RAY BOATS, INC. TEL35 -84.265
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47123 0089 SEA RAY BOATS, INC. TEL36 -84.26547123 0089 SEA RAY BOATS, INC. TEL37 -84.26547123 0089 SEA RAY BOATS, INC. TEL38 -84.26547123 0089 SEA RAY BOATS, INC. TEL39 -84.26547123 0089 SEA RAY BOATS, INC. TEL40 -84.26547123 0089 SEA RAY BOATS, INC. TEL41 -84.26547123 0089 SEA RAY BOATS, INC. TEL42 -84.26547123 0089 SEA RAY BOATS, INC. TEL44 -84.26547123 0089 SEA RAY BOATS, INC. TEL46 -84.26547123 0089 SEA RAY BOATS, INC. TEL48 -84.26547123 0089 SEA RAY BOATS, INC. TEL49 -84.26547123 0089 SEA RAY BOATS, INC. TEL50 -84.26547123 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
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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 -86.8747147 0055 ELECTROLUX MAJOR APPLICANCES NORTH AMERICA S-028 -86.8747147 0055 ELECTROLUX MAJOR APPLICANCES NORTH AMERICA S-041 -86.8747149 0155 NISSAN NORTH AMERICA, INC. FUG-22 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. FUG-93 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. FUG-97 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. NG65 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S1P107 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S1P109 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S1P19 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S1P26 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S1P4 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S1P41 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S1P6 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S1P61 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P1 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P10 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P16 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P23 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P27 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P37 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P4 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P54 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P55 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S2P6 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S3P10 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. S3P12 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. SO05 -86.492314338
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47149 0155 NISSAN NORTH AMERICA, INC. SOB3 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. SOS3 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. SPP3 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. SPP4 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. TC1 -86.49231433847149 0155 NISSAN NORTH AMERICA, INC. TC23 -86.49231433847149 0172 STRATOS (JAVELIN_2 BOATS) 65978 -86.38247149 0172 STRATOS (JAVELIN_2 BOATS) 65979 -86.38247149 0172 STRATOS (JAVELIN_2 BOATS) 65980 -86.38247149 0172 STRATOS (JAVELIN_2 BOATS) S-014 -86.38247153 0034 TECUMSEH PRODUCTS CO. S-001 -85.37847153 0034 TECUMSEH PRODUCTS CO. S-002 -85.37847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A01 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A02 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A03 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A04 -86.55847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A05 -86.55847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A06 -86.55847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A07 -86.55847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A08 -86.55847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87A09 -86.55847165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C01 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C02 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C03 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C04 -86.547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C05 -86.547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C06 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C07 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87C08 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87D01 -86.557
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47165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87D02 -86.55747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87D03 -86.55747165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87E01 -86.5547165 0008 TENNESSEE GAS PIPELINE COMPANY, STATION 87 87E02 -86.5547167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION PT-3 -89.647167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION PT-4 -89.647167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION PT-5 -89.647167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION REECO1 -89.647167 0079 QW MEMPHIS CORPORATION - COVINGTON DIVISION REECO2 -89.651001 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 -78.47351019 00001 Rubatex International LLC 1 -79.551027 11159 Equitable Production Co-Hurricane 2 -8251031 00006 Babcock & Wilcox Nuclear Operations Group Inc 21 -79.051065 00001 Dominion - Bremo Power Station 1 -78.251075 00030 INGENCO - Rockville Plant 1 -77.66451081 00001 Emporia Foundry Incorporated 1 -77.53351081 00011 Belding Hausman Inc - Weldon Mill 1 -77.55751081 00020 Georgia Pacific Wood Products - Emporia - Plywood 1 -77.52451085 00042 Bear Island Paper Company LLC 17 -77.43851095 00023 HRSD - Williamsburg Sewage Treatment Plant 1 -76.62951101 00001 Stone Container Enterprises dba Smurfit-Stone Cont 1 -76.851101 00004 West Point Veneer LLC 1 -76.80751101 00021 Old Dominion Grain 1 -76.81551101 00023 Augusta Wood Products LC - Sawmill 1 -76.83351101 00027 West Point Chips Incorporated 1 -76.851121 00006 Alliant Techsystems Inc 2 -80.54151121 00091 Thermasteel Corporation 1 -80.566
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51133 00013 Waller, R P Oil BP 1 -76.51153 00002 Dominion - Possum Point Power Station 10 -77.28051153 00011 Prince William Hospital Corporation 5 -77.48551153 00021 LOCKHEED MARTIN MANASSAS 11 -77.51153 00814 BAE Systems 1 -77.49751153 00889 Architect of the Capitol 2 -77.51351161 00011 Adams Construction Co - Rockydale 1 -79.9451161 00015 Double Envelope Company 1 -79.951165 00069 Adams Construction Company 1 -78.74151165 00106 Transprint USA Inc 1 -78.90051179 00020 FBI Academy 1 -77.29051191 00044 Universal Fibers Inc. 1 -82.151195 00089 P M Terminals Inc -Buck Oil Co 1 -82.351515 00038 Wheelabrator Abrasives Incorporated 21 -79.5551520 00018 Strongwell Corporation/Bristol Division 6 -82.151620 00011 Franklin City - Electric Dept - Mechanic Street 1 -76.91951640 00002 Turman Hardwood Flooring Inc. 5 -80.951650 00007 US Air Force Base Langley 15 -76.351650 00011 US Department of Veterans Affairs Medical Ctr 1 -76.351650 00093 Bethel Landfill (USA Waste of Virginia) 1 -76.42651683 00003 Glen-Gery Corporation - Capitol Plant 1 -77.551683 00090 City of Manassas/VMEA 1 -77.50851690 00050 Southern Finishing 1 -79.85451700 00013 Northrop Grumman Shipbuilding Incorporated 28 -76.43551700 00071 Kinder Morgan Bulk Terminals - Pier IX 1 -76.43251710 00009 Ford Motor Company Norfolk Plant 6 -76.25251710 00068 U S Gypsum Co 1 -76.28551710 00113 J H Miles & Company Incorporated 1 -76.30551710 00249 Lyon Shipyard, Incorporated - Brown Ave 1 -76.27251710 00251 Lyon Shipyard Incorporated - Sealift Drydock 1 -76.265
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51740 00037 Fleet & Industrial Supply Center 1 -76.37551760 00098 Kinder Morgan Southeast Terminals-Rchmd Terminal 10 -77.42651760 00399 Spruance Genco LLC 1 -77.42651760 00489 Motiva Enterprises LLC-Richmond Terminal 1 -77.44551810 00013 US Navy - Joint Expeditionary Base - Little Creek 1 -76.1451810 00034 HRSD Chesapeake-Elizabeth Sewage Treatment Plant 1 -76.16454029 5402900001 ARCELORMITTAL WEIRTON INC. 107 -80.654029 5402900001 ARCELORMITTAL WEIRTON INC. 108 -80.654029 5402900001 ARCELORMITTAL WEIRTON INC. 109 -80.654029 5402900001 ARCELORMITTAL WEIRTON INC. 111 -80.654029 5402900001 ARCELORMITTAL WEIRTON INC. 112 -80.6