# Development of the Point Source

Emission Inventory for 2007

in the SESARM Region

(Version 1.10a)

Prepared for:

John Hornback

Executive Director, Southeastern St ates 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 140 th 

# 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

i AMEC 

# 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.............................................................................................................1 1

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 Init ial 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 NH 3 

# Emissions by State

Exhibit 10 – 2007 Point Source NH 3 

# Emissions by Category

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

Exhibit 12 – 2007 Point Source NO

x 

# 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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iii AMEC 

# 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

NH 3 

# Ammonia

NIF3.0 National Emission Inventory Input Format Version 3.0

nonEGU Non Electric Generating Unit

NO

x 

# 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 PM 2.5 

# , Filterable portion only

PM25-PRI Primary PM 2.5 

# , 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 Ke rnel 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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AMEC Project No.: 6066-09-0326.02 January 18, 2012

1 AMEC 

# 1.0 ANNUAL 2007 INVENTO RY 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 par ticle, and regional haze assessm ent obligations through funding

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

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

preparing the 2007 criteria air pollutant (CAP) and ammonia ( 

# NH 3 

# ) emission inventory for point

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

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

sources in this inventory are sources classifi ed 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 sma ller sources in the point source inventory.

The inventory includes annual em issions for sulfur dioxide ( 

# SO

2 

# ), oxides of nitrogen ( 

# NO

x 

# ), volatile

organic compounds (VOC), carbon monoxide (CO), ammonia ( 

# NH 3 

# ), and five components of

particulate matter (PM).

The inventory also includes particulate matte r (PM) emissions, cat egorized 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 thr ough the filter. Condensable particulate matter is

material that is emitted in the vapor state which later c ondenses 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 diamet er less than or equal to a nominal 10 and 2.5

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

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

particles (PM-CON). Note that PM10-PRI equa ls 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 emi ssion inventories to be used with models and

other analyses for demonstrating a ttainment 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 bei ng modeled. This inventory is generally used for

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

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

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

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

the baseline inventory may need to replace the day spec ific 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 qu ality assurance (QA) reviews by State and local

(S/L) agencies, as well as a revi ew by stakeholders. Numerous co rrections and improvements were

made to the inventory. Updated ve rsions of the inventory were re leased throughout the inventory

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

different versions of the inventory:

 Version 1.1, released April 201 0. S/L agency submittals were compiled into this initial

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

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

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

Version 1.1.

 Version 1.2, not released. Th is 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 th e 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. Th is 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 co rrections 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 m odeling, such as emissions of hazardous air

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

SEMAP for use in preparing emi ssion density maps and bubble plot s that were provided to

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

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

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

 Version 1.7, released December 7, 2010. This version incl uded emission updates to two

facilities in Kentucky and replaced geographic c oordinates with latit ude and longitude for all

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

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

 Version 1.8, released Januar y 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 deliver ables are described in Section 1.11.

1.2 INITIAL DATA SOURCES AND QA REVIEW

Version 1.1 of the 2007 poi nt source inventory was developed using data submitt ed by State and

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

1.2.1 State Submittals and C onversion into a NIF Database

Each S/L agency collects point s ource data according to EPA approv ed procedures t hat are included

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

standard operating procedures. These plans and pr ocedures 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 Cons olidated 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 sour ces. In this case, in ventories 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 platfo rm (EPA 2009c). S/L

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

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

formats for the S/L agency point s ource submittals with additional ex planatory notes provided in the

following sections.

As noted in Exhibit 1, a few S/L agencies provi ded 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 c hanged very little between 2005 and

2007. Other S/L agencies indicat ed that 2005, 2006, or 2008 emissi ons data should be considered

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

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

(i.e., 97 percent of the point source 

# NO

x 

# emissions and 99 percent of the 

# SO

2 

# emissions are 2007

data). It was decided that spending limited resource s 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 s ubmitted fewer facilities. An ex planation of t he reason why the

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

sub-sections. SESARM’s area sour ce contractor has developed proc edures 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 s ource inventory and (2) that

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

the area source inventory.

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

Infrastructure, Inc. (AMEC) perf ormed 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 mi nor issues were identified and were resolved by

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

individual inventory files were c onsolidated into a single data set. A dditional QA acti vities identified

in the Quality Assurance Project Plan (SESAR M 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 contai ned two National Emission Invent ory (NEI) Input Format (NIF)

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

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

with the minor source found and iden tified 10 facilities that were in bot h 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 fo r these 10 facilities. Alabama ensured that the minor source

emissions that were included in the poi nt source file were not double c ounted 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 ensur e that double counti ng did not occur.

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

coordinates, or inconsist encies 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 an d 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 NI F ACCESS database files. The first contained 2007 emissions

data for 37 very large sources, while the se cond 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 emissi ons. AMEC did not project 2005

emission data to 2007, as the 2005 data was considered to be repr esentative 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 identif ied 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 nece ssary 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 Rel ease (ER) table were reported in cubic feet per

minute. The NIF specificat ions require that this field be report ed 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 ASC II 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 fl ow rate and velocity by t he EPA’s Basic Format and Content

Checker. These cases are discussed later in Se ction 1.5 of this docum ent. Otherwise the data

passed all of the QA checks.

1.2.1.4 Georgia

Georgia submitted three NIF ACCESS database file s. The first contai ned 2007 emissions data for

74 very large sources. The se cond file contained 20 08 emission data for 109 additional facilities.

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

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

a last resort. We used the data from the 2007 f ile and deleted the corres ponding facilities from the

2008/2005 files to ensure no double count ing of emissions. No signific ant issues were identified by

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

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

1.6.4 for a discussion of how 2007 emissions we re 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 in to 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., emi ssions were zero for all criteria air pollutants at the facility) and

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

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

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

# NO

x 

# emissions

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

The EPA’s Basic Format and Content Checker identifi ed several relational wi dow 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 t he 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-r ange values for stack parameters or location

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

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

1.2.1.6 Kentucky – Jefferson County

Jefferson County submitted two NI F ACCESS databases cont aining 2007 emissions data – one file

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

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7 AMEC 

# criteria air pollutant file was processed. Jefferson Co unty’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 fo rmat 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 wi th 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 t he data from Mississippi’s 2007 file and deleted the

corresponding facilities from the 2005 EPA file to ensure no double count ing 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 si gnificant issues were

identified by EPA’s Basic Fo rmat 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 contro l information in the ORL file,

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

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

coordinates, or inconsistencies bet ween 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. Nort h Carolina investigated

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

tables were provided in May 2010 to correct this problem.

The 2007 SEMAP inventory contains many more s ources 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 init ial submittal that were permanently closed

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

emissions. These facilities were remo ved 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 ev ery three years to once every five year

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

source emission inventory is much more in clusive 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 submitt ed two NIF ACCESS database files. The first contai ned 2007 emissions

data for 9 Title V facilities, while the second c ontained 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 count ing of emissions. We also deleted all records

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

AMEC Project No.: 6066-09-0326.02 January 18, 2012

8 AMEC 

# for Snider Tire (Facility ID 0861) which ceas ed 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-ra nge values for stack parameters or location

coordinates, or inconsistencies bet ween 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 EI S-formatted ACCESS database. The

data is actually a mix of 2008, 2007 and previous year data, but Fo rsyth County indi cated that the

submittal is representative of ca lendar 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 “Releas ePoint” ACCESS table we re mapped to NIF ER

table fields. The flow rate in the “Release Poin t” 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 provi ded by 60. There were no stack-level geographic

coordinates in the “ReleasePoint Geographic Coordinates” ACCESS tabl e. However, there

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

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

facility. Where a facility matc h could not be made, we substitu ted the county centroid for the

geographic coordinates (longitude -80.24, latitude 36.114).

 EU Table – relevant fields from the “Emiss ionUnit” ACCESS table we re mapped to NIF EU

table fields.

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

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

“ReleasePointApportion ment” ACCESS table.

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

PE table fields.

 CE Table – no information on c ontrol equipment was provided.

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

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

“ReleasePointApportion ment” ACCESS table.

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

coordinates, or inconsistencies bet ween 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 emi ssions data for 539 facilities in a spreadsheet t hat contained

a limited number of NIF fields. AMEC perfo rmed data reformatting and a number of data

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

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

AMEC Project No.: 6066-09-0326.02 January 18, 2012

9 AMEC 

#  SI Table – only the facility id# and facility name were provid ed; 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 contai n any stack parameters and the geographic

coordinates were in NC State Pl anar coordinates, not UTM coor dinates or latitude/longitude

as required by the NIF specification. To f ill in the geographic coor dinates, we obtained the

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

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

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

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

Stack parameters for all other sources will be f illed in according to t he gap-filling procedures

discussed later in Section 1.5 of this document.

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

elements were left blank.

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

 PE Table – we filled in the PE table with t he 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 c ontained annual emissions for all criteria air pollutants and

ammonia.

After reformatting the spreadsheet into NIF t ables, 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 count ies 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 f ile 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 identif ied that certain EM records associated with

facility ID 2320-0034 (NAN YA Plastics) were assi gned to FIPS 45041 (Florenc e 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 t he 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 fe wer facilities than were in the VISTAS 2002

inventory. South Carolina revi ewed data from EPA’s 2005-based mode ling 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.

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

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10 AMEC 

# 1.2.1.13 Tennessee

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

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

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

merged the two files and checked fo r duplicate facilities. One fac ility – JW Aluminum (Facility ID

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

avoid double counting of emissions.

Tennessee submitted emissi ons data for a large number of hazar dous air pollutants. Since these

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

EM and CE tables.

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

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

in the EU, EP, PE and EM tables.

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

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

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

NIF database, and merged with South Carolina’s s ubmittal. We used the data from Tennessee’s

2007 files and deleted the corresponding facilitie s 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 C ontent Checker. An additional 280

facilities were added during th is 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 inconsis tencies between the fl ow rate and velocity by the EPA’s Basic

Format and Content Checker. These cases are di scussed 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 re presentative of 2007 for 177 fac ilities in a spreadsheet that

contained the NIF fields needed fo r regional air quality mode ling. AMEC performed data

reformatting to create reasonably complete NIF t ables. The data passed a ll of the QA checks.

1.2.1.16 Tennessee – Knox County

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

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

coordinates, or inconsistencies bet ween 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 spreadsh eet with NIF tables for 29 fac ilities with 2008 emissions data.

The 2008 was consi dered 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 

# NO

x 

# emissions as reported in EPA’s

CAMD database.

Shelby County submitted emissions data for a la rge 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.

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

AMEC Project No.: 6066-09-0326.02 January 18, 2012

11 AMEC 

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

AMEC made the necessary corrections to the NIF t ables 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 de veloping 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 pr ocess, Virginia provided emissions data for a

number of additional distributed gene ration units. Virginia’s submitta l 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 t he SEMAP 2007 point source modeling inventory.

1.2.1.19 West Virginia

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

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

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

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

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

are discussed later in Sect ion 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 Cl ean Air Act. AMEC downloaded the 2007 CAMD annual inventory

containing 

# NO

x 

# and 

# SO

2 

# emissions, heat input dat a 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 in ventory. In the CAMD invent ory, the Office of Regulatory

Information Systems (ORIS) i dentification (ID) c ode 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 hour ly inventory containing hourly 

# NO

x 

# 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 repo rting units) by emission unit. The summed hourly

data was compared to the annual summary data, whic h 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 developi ng 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 uni ts. However, in many other cases either the

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

example, the facility IDs in West Virginia’s 2002 VISTAS database we re 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 consis ted of the five-digit FIPS code follow ed by a 5-digit facility ID, while the

facility IDs in the 2007 SEMAP inventor y 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 eac h S/L agency with linkages between the CAMD

identifiers and the S/L agency i dentifiers and a comparison betw een the CAMD annual summary

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

AMEC Project No.: 6066-09-0326.02 January 18, 2012

12 AMEC 

# emissions, the annual emissions summed from t he hourly CAMD database, and annual emissions

reported in the S/L inventory. This spreadshe et 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 f ile, (2) the sum of the CAMD hourly emission file,

and (3) the State submitted NIF tabl es. Note that the CAMD Emissi ons are reported at the unit level

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

AMEC added three fields to the NI F EP table to facilitate the link age 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 spreads heet 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) ther e are not any large discrepancies between the

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

There are three types of possible linkages:

 CAMD facility has no match in NIF SI facility table. The em issions from these facilities

reported to CAMD are small, and initia lly accounted for about 0.5% of the 

# NO

x 

# 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, accounti ng for about 0.9% of the 

# NO

x 

# and 0.007% of the 

# SO

2



# emissions in the CAMD database. Most of t he 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 wher e multiple CAMD units match to a single

NIF record (i.e., units are grouped in the NIF t ables 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 

# NO

x



# 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 ge nerally very close to the CAMD unit level

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

As another QA check, AMEC comp iled a list of sources with EG U 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 signifi cant efforts to improve the

crosswalk between the CAMD identif iers 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 a nnual 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 estimate s for those species were missing from the S/L agency submittal

.For example, if a S/L agency provided only PM 10-PRI emissions, the PM augmentation process

filled in estimates for PM-CON, PM 10-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 identic al to the EPA methodology used for the 2002 NEI

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

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

AMEC Project No.: 6066-09-0326.02 January 18, 2012

13 AMEC 

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

 Step 2: Updating of PM factor ratios previ ously 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 augm entation results to S/L agencies for review and comment;

and

 Step 5: Updates to augmented values in ca ses 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 em itted 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 ent er 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 PM 2.5 

# , Filterable portion only Particles with an aerodynamic diameter equal to or less

than 2.5 micrometers that ar e 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 PM 2.5 

# , includes filterables and

condensables

PM25-PRI=

PM25-FIL + PM-CON Particles with an aerodynamic diameter equal to or less

than 2.5 micrometers that ent er 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.)

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

AMEC Project No.: 6066-09-0326.02 January 18, 2012

14 AMEC 

# 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

MS 1 

# 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

SC 1 

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

TN 1 

# 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

VA 2 

# 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 perf ormed using an identical augmentation process

during the development of the 2007 regional em ission 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 inconsis tent, they were replaced. The consistency che cks and replacement

actions are as follows:

1. If PM10-PRI >0 and PM25-PRI > PM10-PR I (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.

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

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15 AMEC 

# 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 inc onsistencies, 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 corr ections 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 tabl e developed for the MANE-VU 2002

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

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

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

inventory that were not contai ned in the 2002 MANE-VU inventory.

1.4.3 PM Emission Calculations

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

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

augmentation method that was applied.

Exhibit 4 – PM Cases and Required St eps 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

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

AMEC Project No.: 6066-09-0326.02 January 18, 2012

16 AMEC 

# 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 t he 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 agen cy resulted in negative values when FIL was backcalculated. In this case the ne gative 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 what ever States provided in the way of PM and filled in gaps to add in PM-CON

where emissions were missing in order to calculate PM 10 

# -PRI and PM 2.5 

# -PRI for all processes to get

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

obtained from the PM augmentati on process by State and SCC.

Exhibit 5 Comparison of PM Emissions from the In itial 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

SC 1 

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

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

TN 1 

# 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

VA 2 

# 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 perf ormed using an identical augmentation process

during the development of the 2007 inventor y 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, re vise, 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 relev ant physical attributes

of the emission release point. Locat ion 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 eit her of two coordinate

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

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

Y coordinates reported as UTM Easting and UTM Nort hing, 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 T eam and converted to, and stored as Latitude

Measure and Longitude Measure in decimal degrees.

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

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

data to decimal degree format and was configured for WGS 84 DATU M. 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 coordi nates accurate to five decimal places. Four

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

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

checked for reasonableness.

Once all conversions were made to LATLON dec imal 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 coordi nates 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 (bas ed 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 fo r review by the data

provider.

For version 1.10a of the inventor y additional GIS checks were made by personnel from GADEP to

evaluate any remaining inconsistencies bet ween 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 pa rameters for the physical characteristics of each

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

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

modeling. Gaussian dispersion model s need stack parameters to charac terize 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 repl ace values if necessary, and to fill-in missing data

points. This methodology is vi rtually identical to the EPA met hodology used for the 2002 NEI (EPA

2006a).

We employed a routine that compared each emis sion 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 consis tency between:

 stack height and diameter, and

 stack diameter, exit gas velo city, and exit gas flow rate.

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

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

internally inconsistent stack parameters.

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

For fugitive emission release poi nts, we first compared the ex isting 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 repl aced all other stack parameters with the defaulted

values listed below. If the height was invalid, we replaced all stack param eters 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 firs t compared existing stack parameters against a set

of the following ranges thought to be representative of the minimu m 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 ft 3 

# /sec

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

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

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

to exist within the bounds of the emission re lease 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, t he stack height may not be less than stack diameter.

B. We determined the internal c onsistency between diameter, veloci ty 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 with in 10 % of one another, then internal consistency

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

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

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

the internal consistency tests, the parameter was replaced usin g 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 ther e 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 heigh t, then all five parameters were defaulted using

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

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

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

next. If velocity and flow rate were not internally c onsistent, 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 c onsistency. If t he internal consistency was not met

for velocity, flow rate, and diameter, Exhibit 6 pr ovides instructions on how we replaced missing, out-

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# of-range values, or internally inconsistent valu es for velocity and flow rate based on different

reported scenarios. Velocity and flow rate were augmented either by calcul ation 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, temperatur e was evaluated. If temperature was missing or

out-of-range, then the temperatur e 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 record s submitted and identifies which parameters were defaulted as a

result of our QA. S/L agencies were asked to revi ew 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 20 07 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. Ne w EM and CE tables were provided in May 2010 to correct this

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

described in previous sections.

Alabama reviewed the geographic c oordinates for the 34 stacks that were fl agged as being outside

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

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

In response to the QA checks of stack paramet ers, Alabama changed the em ission release type to

“01” (fugitive sources) for 98 and accepted the defaul t fugitive emission releas e characteristics. For

another 71 stacks, Alabama changed t he 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 re commended 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 c hecks 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 di fferent 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 mism atch 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 20 08 emissions and projecting of 2005

emissions was performed in the following manner:

 Facilities with 2007 emi ssions do not get changed;

 For facilities with 2005 and 2 008 emissions (but no 2007 em issions), 2007 emissions were

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

a pollutant-by-pollutant basis to calculate fac ility 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 perfo rmed, additional adjustments were made for

facilities where only 2005 data we re available and the facility di d not operate in 2007 or operated for

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

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

the 2005 emissions by a scaling fa ctor 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 operati on. 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 thei r associated emission units to the NIF tables. All of the units

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

 

# NO

x 

# – used the CAMD reported 2007 annual 

# NO

x 

# emissions

 

# SO

2 

# – used the CAMD reported 2007 annual 

# SO

2 

# emissions

 CO – calculated annual CO emissions usi ng 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 emissi ons 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 emissi ons 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 em issions using the CAMD repo rted 2007 annual heat input

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

These calculations were revi ewed and approved by Georgia.

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

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

1.6.5 Kentucky

Kentucky compared facility-level emissions in th eir 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 

# NO

x 

# in the draft 2007 SEMAP

inventory and (2) Chesapeake Applachia LLC (211 9500252), 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 dat a for 677 stacks that were identified as being

located outside of the count y 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 stac k height and exit gas temperature.

1.6.6 Kentucky – Jefferson County

Jefferson County updated the coordi nates of emission release point s for large and medium-sized

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

those with synthetic minor operatin g permits. Most of these emi ssion 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 coor dinates) were obtained by other m eans, 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 Mississ ippi’s 2007 submittal. Mississippi reviewed

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

very small sources, contained dated emissions data, had some double-c ounting 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, Mississi ppi 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 dat a for 15 stacks that were identified as being

located outside of the county boundaries.

Mississippi approved the stack parameter chan ges 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 fugi tive emission sources with a emission release point of “9999”.

These stacks were updated to c hange 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 (B TEC New Albany ORIS 13213, Natchez ORIS 2052, and

AP Holdings Southhaven ORIS 55219) are current ly 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 Mississi ppi’s original submittal. Missi ssippi 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 invest igated this problem and ident ified 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 descr ibed in previous sections.

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# North Carolina reviewed the geographic coordinate s for the stacks that were flagged as being

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

paragraph contained corrections to t he 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 corr ections for stack parameters for 2007. For the

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

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

Allen), new stacks will beco me operational after 2007.

1.6.9 North Carolina – Buncombe County

Buncombe County approved the sta ck parameter changes for the st acks 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 orig inal stack parameters for certain stacks and

requested that the updat ed stack data be used.

The geographic coordinates were inadve rtently truncated (not rounded) to 1/100 th 

# 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 SEM AP 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 hi ghest emitting sources. The emissi ons 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 correc ting inconsistencies in

the reported PM data during t he PM augmentation process. Fo r example, the Corn Products

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

greater than PM10-PRI, the PM10-PRI value was r eplaced during the PM augm entation process.

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

3706700003.

The geographic coordi nates were incorrect for many facilitie s. These have been replaced for all

facilities in Forsyth County.

1.6.11 North Carolina – Mecklenburg County

Mecklenburg County approved the sta ck parameter changes for the st acks that were recommended

for change based on the QA c hecks 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 S outh Carolina’s 2007 submittal. South Carolina

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

was for very small sources, contained dated emissi ons data, had some doubl e-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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27 AMEC 

# added from the 2005 NEI from the 2007 SEMAP invent ory 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 longit ude data for 14 stacks that were identified as

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

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

were flagged, the facility level lati tude and longitude were used to more accurately loca te the stack.

South Carolina approved the stack parameter ch anges for the stacks that were recommended for

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

several cases, South Carolina updated the orig inal stack parameters for certain stacks and

requested that the updat ed stack data be used.

South Carolina reviewed the PM augmentation of PM10-PRI and PM 2.5 

# -PRI and generally agreed

with the small increases in the PM10-PRI and PM 2.5 

# -PRI emissions resulti ng from the augmentation

process. South Carolina expressed a concern a bout the increases that we re 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 fe w facilities had reported PM10-FIL and PM25-FIL,

not PM10-PRI and PM25-PRI. Since the PM10-FIL and PM25-FIL were repor ted, 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 crosswal k and updated several linkages to correctly map

CAMD identifiers to NIF. South Carolina also compared the CAMD-reported 

# NO

x 

# and 

# SO

2 

# emissions to the NIF-reported emissions, and updated the NIF emissi ons for several coal-fired

plants with the CAMD emissions after cons ulting 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 T ennessee’s 2007 submittal. Tennessee reviewed

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

very small sources, contained dated emissions data, had some double-c ounting 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 remo ve 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 emissi ons 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 ENGINEERIN G DEVELOPMENT CENTER

47031 0067 BATESVILLE MANUFACTURING, INC.

47031 0113 M-TEK, INC.

47031 0123 CREATEC CORPORATION

47047 0080 STABILT AMERICA, INC

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

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28 AMEC 

# 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 bo undaries. Tennessee also pr ovided changes to the stack

parameters for 29 stacks. Stack par ameter changes were made for fugitive emission release points

that were recommended for c hange based on the QA c hecks and gap filling process described in

Section 1.5.2 of this report.

1.6.14 Tennessee – Davidson County

Davidson County reviewed the dra ft point source emission invent ory 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 Sect ion 1.5.2 of this report. In

several cases, Davidson County provided up dated 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 up dated stack latitude and longitude for th ree 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 updat ed 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 ch anges for 765 stacks that were recommended for

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

a few cases, Shelby County provided updat ed stack parameters for selected stacks.

Hamilton County provided updated stack latitude and longitude for fa cilities that were flagged as

being located outside of the county boundaries.

1.6.18 Virginia

Virginia provided updated latitude and longitude dat a for 115 stacks that we re identified as being

located outside of t he 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 filli ng process described in Section 1.5.2 of this report. The only

exception was for the Jewel Coke Company (ID 51027-00004, stacks 1 an d 3), where Virginia

requested that the original stack exhaust gas tem peratures of 1500 degrees Fahrenheit be retained.

As part of the development of a 2007 inventory for the Mid-Atlantic and Nort heast 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 ch anges 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, Gr atech International 5403300001,

Monongahela Power Harrison 5403300015, DuPont Belle 5403900001) where West Virginia

requested that the original stack par ameters for certain stacks be retained.

West Virginia reviewed the locations for the se ven facilities flagged as be ing outside of the county

boundaries and provided updated stack latit ude and longitude for t hese facilities.

West Virginia reviewed the draft emission inventory and confirmed that all poi nt source facilities are

represented in the inventor y, that the PM augmentat ion 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 crossw alk and identified the linkage between CAMD and

NIF identifiers for the Union Carb ide Corporation (5403900003) boile rs 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 re gulated community,

academia, environmental groups, and the general public. This section documents the changes

made to Version 1.3 based on S/L ag ency review of stakeholder comm ents as well as any additional

updates or corrections identif ied by the S/L agencies.

1.7.1 Alabama

The National Lime Association requ ested consideration of a modification to PM emissions data for

one of their facilities in Alabam a (Unimin Lime Corporation, Ca lera Plant). The request was

reviewed by State staff and the suggest ed correction was justified and made.

1.7.2 Florida

Lakeland Electric requested that the 

# SO

2 

# and 

# NO

x 

# emission values from the EPA CAMD submittal

be used instead of the values repo rted to the State. The CAMD represent the emissions more

accurately that the State submittal for two plant s (Plant IDs 1050004 and 1050003). Florida agreed

to make these changes.

Tampa Electric reviewed the dat abase and suggested several corrections . Most of the changes are

due to the installation and operation of the SCR control devices on Big B end units 1-4. Tampa

Electric also evaluated filterabl e and condensable PM emissions for a ll of its major generating units

and provided better, unit specific, emission rates fo r these units where ava ilable. Finally, Tampa

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

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30 AMEC 

# 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 Cris t plant reflects the current

scrubbed stack parameters, not the operating paramete rs in 2007. Appropriate stack parameters for

2007 were submitted and review ed/approved by Florida.

1.7.3 Georgia

Georgia reviewed the emissions va lues and stack parameters for the Georgia Power facilities in the

State. Georgia provided updated PM and 

# NH 3 

# 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 st ack parameters for selected Georgia Power stacks.

Georgia also identified a number of emission units where the PM 2.5 

# emissions were greater than the

PM10 emissions. The source of this error was in vestigated and ident ified, and revisions were made

to correct this error.

1.7.4 Kentucky

Kentucky identified that t he PM point source emissions originally submitted for all Kentucky counties,

excluding Jefferson County, should be c onsidered as filterable PM emissi ons. 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 pollu tant codes to represent filt erable 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 wi th these utilities in obtaining updated PM emissi ons data that

included both filterable and condens able 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 requ ested that the SCC be changed as that will impact how boilers are

grouped by category for various regulator y 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 ent ries in the emission

inventory. AMEC investigated this issue and identified the erro r. The duplicate entries were

removed.

Tennessee also provided updated 2007 emissions data for the CalsonicKans ei North America -

Lewisburg Operati ons 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. Emissi on projections for EGU point sources are being

developed by the Eastern Regional Technical Adviso ry Committee (ERTAC). The emissions from

point sources classified as nonEGUs will be projec ted using the methods and data developed by

SEMAP.

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31 AMEC 

# Most, but not all, of the units t hat are required to repor t 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 participat ing in an emissions cap and trade program under the

Acid Rain Control Program, the 

# NO

x 

# Budget Trading Program, or the Clean Air Interstate Rule. The

following guidance was provided to States to determi ne whether a unit that reports to CAMD should

be classified as an EGU or nonEGU:

For the ERTAC process, a unit should only be cons idered EGU if it meets the following criteria:

 An EGU sells most of the power g enerated to the electrical grid;

 An EGU burns mostly commercial fuel. Commercia l fuel in this case means natural gas, oil,

and coal. Wood would not be c onsidered as commercial fuel because some states have

them as renewable, therefore, to prevent double counting, unl ess 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 facilit y 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-xx x-xx or 2-01-xxx-xx). From t hese lists, S/L agencies identified

units that should be classified as EGUs and thos e 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 em ission 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 hour ly emissions to the CAMD database and

have been classified as EGUs by the S/L agency;

 EGU-nonCAMD are combustion units with SCC star ting with 101 or 201 that are not

contained in CAMD database;

 nonEGU-CAMD are combustion units that report hour ly 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 categoriz ed 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 agenc ies to verify the PM emissions

data for coal- and oil-fired units included PM co ndensable 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 pl ots prepared by another SEMAP contractor. This

section documents the changes m ade based on these final QA checks. In addition, the

documentation was revised to address comments provided by EPA Region 4.

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

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32 AMEC 

# 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 subm itted information to confirm that the PM 2.5 

# -PRI and

PM10-PRI emission estimates fo r its facilities do include both filterable and condensable values.

1.9.3 North Carolina – Forsyth County

In its original submittal, Forsyth County subm itted a mix of 2007 and 20 08 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., Pl ant 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 add ition of the coal boilers at R.J. Reynolds Tobacco Company

(Plant ID 00039) to the SEMAP 2007 inventory t hat 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 emi ssions are included in the PM10-PRI and

PM 2.5 

# -PRI data provided for coal- and oil-fired EGUs.

1.9.5 Virginia

Virginia confirmed that t he PM condensable emissions ar e included in the PM10-PRI and PM 2.5 

# -PRI

data provided for coal- and oil-fired EGUs.

1.9.6 West Virginia

After reviewing the emission density maps and em ission bubble plots, West Virginia submitted

revisions to the geographic coor dinates at three facilities ( 54-009-00012 Impress USA, 54-021-

00001 Columbia Gas Glenville, 54-0 57-00008 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 in ventory. 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 signi ficant 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 identif ied along with the CAMD and

SEMAP unit identifiers:

 CAMD_ID = Plant ORIS / Boiler ID

 SEMAP_ID = FIPS county code / Pl antID / PointID / ProcessID

Several States have indicated that they would like to the SEMAP inventory to be updated to reflect

the CAMD 

# NO

x 

# 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

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

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33 AMEC 

# substitution procedures spec ified by EPA. Once States review the proposed revisions to the CAMD

emissions to account for missing data substitution, St ates will be given the oppor tunity to specify the



# NO

x 

# 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 a ccount 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 

# NO

x 

# 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 

# NO

x 

# 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 

# NO

x 

# changed from 4,559 tons to 3,717 t ons to match CAMD emissions

PowerSouth Energy Coop (CAMD_ID = 56 / 3; SEMAP_ID = 01129/ 0001/ 003 / 01

SEMAP 

# NO

x 

# 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 

# NO

x 

# changed from 4,507 tons to 10,044 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1,610 tons to 2,999 t ons to match CAMD emissions

TECO Big Bend (CAMD_ID = 645 / BB02; SEMAP_ID = 12057 / 0570039 / 2 / 2)

SEMAP 

# NO

x 

# changed from 3,889 tons to 10,051 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1,389 tons to 2,717 t ons to match CAMD emissions

TECO Big Bend (CAMD_ID = 645 / BB03; SEMAP_ID = 12057 / 0570039 / 3 / 3)

SEMAP 

# NO

x 

# changed from 1,571 tons to 3,838 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 2,035 tons to 1,773 t ons to match CAMD emissions

TECO Big Bend (CAMD_ID = 645 / BB01; SEMAP_ID = 12057 / 0570039 / 1 / 1)

BoilerID in SEMAP EP Table changed from BB O 4 to BB 0 4 to match CAMD boiler ID

SEMAP 

# NO

x 

# changed from 1,183 tons to 1,192 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 2,305 tons to 2,414 t ons to match CAMD emissions

1.9.7.4 Georgia

No changes reques ted by State.

1.9.7.5 Kentucky

Kentucky provided revised SEMAP-to-CAMD mappi ng 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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34 AMEC 

# 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 reques ted by State.

1.9.7.8 North Carolina

No changes reques ted 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 ID s for the combustion turbines. The SEMAP

NIF EP table was changed to correctly matc h CTs 4, 5, 6 between the CAMD and SEMAP

inventories

CAMD unit URQ4 is now linked to EU11 (p reviously was linked to EU04 – CT 1)

CAMD unit URQ5 is now linked to EU12 (p reviously was linked to EU05 – CT 2)

CAMD unit URQ6 is now linked to EU13 (p reviously was linked to EU06 – CT 3)

Progress Energy Robinson (CAMD_ID = 3250 / 12; SEMAP_ID = 45031 / 0820-0002 / 017 / 3)

SEMAP 

# NO

x 

# changed from 3.9 tons to 0 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1.183 tons to 0 t ons to match CAMD emissions

Progress Energy Robinson (CAMD_ID = 3250 / 12; SEMAP_ID = 45031 / 0820-0002 / 017 / 4)

SEMAP 

# NO

x 

# changed from 45 tons to 33.6 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1.178 tons to 1.42 t ons to match CAMD emissions

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

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35 AMEC 

# Progress Energy Robinson (CAMD_ID = 3250 / 13; SEMAP_ID = 45031 / 0820-0002 / 018 / 3)

SEMAP 

# NO

x 

# changed from 18.3 tons to 0 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 0.847 tons to 0 t ons to match CAMD emissions

Progress Energy Robinson (CAMD_ID = 3250 / 13; SEMAP_ID = 45031 / 0820-0002 / 018 / 4)

SEMAP 

# NO

x 

# changed from 42.4 tons to 31.31 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 1.108 tons to 1.05 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT1A; SEMAP_ID = 45007 / 0200-0144 / 001 / 1)

SEMAP 

# NO

x 

# changed from 218.17 tons to 19.71 to ns to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT1B; SEMAP_ID = 45007 / 0200-0144 / 001 / 3)

SEMAP 

# NO

x 

# changed from 218.17 tons to 19.71 to ns to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT2A; SEMAP_ID = 45007 / 0200-0144 / 002 / 1)

SEMAP 

# NO

x 

# changed from 33.40 tons to 16.29 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT2B; SEMAP_ID = 45007 / 0200-0144 / 002 / 3)

SEMAP 

# NO

x 

# changed from 32.40 tons to 18.21 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT3; SEMAP_ID = 45007 / 0200-0144 / 003 / 1)

SEMAP 

# NO

x 

# changed from 0.072 tons to 4.4 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT4; SEMAP_ID = 45007 / 0200-0144 / 003 / 2)

SEMAP 

# NO

x 

# changed from 0.060 tons to 5.13 t ons to match CAMD emissions

Santee Cooper Rainey (CAMD_ID = 7834 / CT5; SEMAP_ID = 45007 / 0200-0144 / 003 / 3)

SEMAP 

# NO

x 

# changed from 0.078 tons to 4.79 t ons to match CAMD emissions

SCE&G Hagood (CAMD_ID = 3285 / HAG4; SEMAP_ID = 45019 / 0560-0029 / 001 / 2)

SEMAP 

# NO

x 

# changed from 21.1 tons to 31.28 t ons to match CAMD emissions

SEMAP 

# SO

2 

# changed from 34.5 tons to 1.22 t ons 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-refe rence 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 #1 2. In SEMAP, there is only one emission

point -015 – that is a coal fi red boiler. To improve the match between CAMD and SEMAP,

new records were created in the SEMAP databa se to disaggregate em issions from boilers

#11 and #12 into individual records using the 

# NO

x 

# 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 

# NO

x 

# for Auxiliary boiler A1 , which was based on

allowable emissions and is conserva tive. For 2007, based on a tested 

# NO

x 

# rate of

0.067lb/mmBtu and fuel usage of 132317 gallons of #2 oil, 

# NO

x 

# emissions for Auxiliary boiler

A1 changed to 0.6 ton.

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

AMEC Project No.: 6066-09-0326.02 January 18, 2012

36 AMEC 

# TVA Cumberland (CAMD_ID = 3399 / A2; SEMAP_ID = 47161 / 0011 / 004 / 01)

The SEMAP inventory reported 15.3 tons of 

# NO

x 

# for Auxiliary boiler A2, which was based on

allowable emissions and is conservative. Th is unit was not in service in 2007 and does not

show up in CAMD for 2007. It did not bec ome operational until 2008. Boiler A2 was

inadvertently included in the 2007 SEMAP emissi on 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 disaggregat e emissions from boilers #23 and #24 into

individual records using the 

# NO

x 

# 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 bet ween CAMD and SEMAP, new records were

created in the SEMAP database to disaggregate em issions for each boiler #25 to #29 into

individual records using the 

# NO

x 

# 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 boile rs #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 dis aggregate emissions for each boiler #30 to #31

into individual records using the 

# NO

x 

# 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 request ed to the SEMAP inventory.

1.9.7.19 West Virginia

No changes reques ted by State.

1.9.8 Changes for Version 1.10a of the Point Source Inventory

This section documents t he changes to Version 1.9 of the SEMAP point source emission inventory

to create Version 1.10a. The purpos e of these revisions were to re solve significant differences in

emissions as reported by States in Version 1.9 and the CEMs emissi ons as reported in the Clean Air

Market Division’s hourly emission database. Each change that was made is i dentified along with the

CAMD and SEMAP unit identifiers:

 CAMD_ID = Plant ORIS / Boiler ID

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

AMEC Project No.: 6066-09-0326.02 January 18, 2012

37 AMEC 

#  SEMAP_ID = FIPS county code / Pl antID / PointID / ProcessID

These changes were made because a number of States have indicat ed that they would like to have

the SEMAP inventory updated to reflect the CAMD 

# NO

x 

# and 

# SO

2 

# emissions from CEMS data.

These changes had not been made in version 1.9 because of potent ial adjustments to the CAMD

emissions to account for overly conservative missi ng data substitution proce dures specified by EPA.

Once States were allowed to review the proposed revisions to the CAMD emissions to account for

missing data substitution, they were gi ven the opportunity to specify the 

# NO

x 

# and 

# SO

2 

# emissions to

be used in the final SEMAP 2007 inventory. The c hoices were: 1) retain State-supplied emissions;

2) use CAMD emissions as prov ided in standard EPA data sets; or 3) use CAMD emissions as

modified by SEMAP to account for overly cons ervative 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 la titude/longitude values. T he final portion of this

section details the emission rel ease points that were modified and the new latitude/longitude values.

The information below identifies those facilities t hat had their emissions chang ed as a result of the

CEMS review.Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201238AMEC1.9.8.1 AlabamaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01001 Southern Power Company 0010 001 01 7897 1A NOX 42.631001001 Southern Power Company 0010 001 01 7897 1A SO2 2.058001001 Southern Power Company 0010 002 01 7897 1B NOX 42.855001001 Southern Power Company 0010 002 01 7897 1B SO2 2.084001001 Southern Power Company 0010 003 01 7897 2A NOX 37.757001001 Southern Power Company 0010 003 01 7897 2A SO2 1.530001001 Southern Power Company 0010 004 01 7897 2B NOX 33.353001001 Southern Power Company 0010 004 01 7897 2B SO2 1.472001001 Tenaska Alabama II Partners LP 0009 001 01 55440 CTGDB1 NOX 14.544001001 Tenaska Alabama II Partners LP 0009 001 01 55440 CTGDB1 SO2 0.546001001 Tenaska Alabama II Partners LP 0009 002 01 55440 CTGDB2 NOX 12.697001001 Tenaska Alabama II Partners LP 0009 002 01 55440 CTGDB2 SO2 0.490001001 Tenaska Alabama II Partners LP 0009 003 01 55440 CTGDB3 NOX 11.224001001 Tenaska Alabama II Partners LP 0009 003 01 55440 CTGDB3 SO2 0.467001001 Tenaska Alabama Partners LP 0008 001 01 55271 CT1 NOX 15.905001001 Tenaska Alabama Partners LP 0008 001 01 55271 CT1 SO2 0.731001001 Tenaska Alabama Partners LP 0008 002 01 55271 CT2 NOX 10.436001001 Tenaska Alabama Partners LP 0008 002 01 55271 CT2 SO2 0.686001001 Tenaska Alabama Partners LP 0008 003 01 55271 CT3 NOX 11.018001001 Tenaska Alabama Partners LP 0008 003 01 55271 CT3 SO2 0.567001015 Calhoun Power Company I LLC Generating Station 0073 001 01 55409 CT1 NOX 19.525001015 Calhoun Power Company I LLC Generating Station 0073 001 01 55409 CT1 SO2 0.546001015 Calhoun Power Company I LLC Generating Station 0073 002 01 55409 CT2 NOX 20.092001015 Calhoun Power Company I LLC Generating Station 0073 002 01 55409 CT2 SO2 0.527001015 Calhoun Power Company I LLC Generating Station 0073 003 01 55409 CT3 NOX 22.875001015 Calhoun Power Company I LLC Generating Station 0073 003 01 55409 CT3 SO2 0.600001015 Calhoun Power Company I LLC Generating Station 0073 004 01 55409 CT4 NOX 21.961001033 TVA 0010 009 01 47 1 NOX 3,103.485001033 TVA 0010 009 01 47 1 SO2 5,786.830001033 TVA 0010 009 01 47 2 NOX 2,880.063001033 TVA 0010 009 01 47 2 SO2 5,339.807001033 TVA 0010 009 01 47 3 NOX 3,104.7600Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201239AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01033 TVA 0010 009 01 47 3 SO2 5,799.600001033 TVA 0010 009 01 47 4 NOX 2,923.267001033 TVA 0010 009 01 47 4 SO2 5,496.512001039 PowerSouth Energy Cooperative Inc 0001 002 01 533 **4 NOX 18.536001039 PowerSouth Energy Cooperative Inc 0001 002 01 533 **4 SO2 0.203001039 PowerSouth Energy Cooperative Inc 0001 004 01 533 **V1 NOX 23.972001039 PowerSouth Energy Cooperative Inc 0001 004 01 533 **V1 SO2 1.196001039 PowerSouth Energy Cooperative Inc 0001 005 01 533 **V2 NOX 20.701001039 PowerSouth Energy Cooperative Inc 0001 005 01 533 **V2 SO2 0.933001055 Alabama Power Company 0002 001 01 7 1 NOX 1,212.747001055 Alabama Power Company 0002 001 01 7 1 SO2 5,556.217001063 Alabama Power Company 0001 001 01 10 1 NOX 2,965.247001063 Alabama Power Company 0001 001 01 10 1 SO2 16,379.736001063 Alabama Power Company 0001 001 01 10 2 NOX 3,148.497001063 Alabama Power Company 0001 001 01 10 2 SO2 14,267.787001063 Alabama Power Company 0001 002 01 10 CT2 NOX 28.133001063 Alabama Power Company 0001 002 01 10 CT2 SO2 0.556001063 Alabama Power Company 0001 003 01 10 CT3 NOX 21.375001063 Alabama Power Company 0001 004 01 10 CT4 NOX 21.493001063 Alabama Power Company 0001 005 01 10 CT5 NOX 20.356001063 Alabama Power Company 0001 006 01 10 CT6 NOX 24.899001063 Alabama Power Company 0001 007 01 10 CT7 NOX 22.287001063 Alabama Power Company 0001 007 01 10 CT7 SO2 0.479001063 Alabama Power Company 0001 008 01 10 CT8 NOX 14.797001063 Alabama Power Company 0001 009 01 10 CT9 NOX 14.095001063 Alabama Power Company 0001 010 01 10 CT10 NOX 16.947001071 TVA 0008 001 01 50 1 NOX 1,654.184001071 TVA 0008 001 01 50 1 SO2 3,549.110001071 TVA 0008 001 01 50 2 NOX 1,696.500001071 TVA 0008 001 01 50 2 SO2 3,670.096001071 TVA 0008 001 01 50 3 NOX 1,759.766001071 TVA 0008 001 01 50 3 SO2 3,757.587001071 TVA 0008 001 01 50 4 NOX 2,038.6580Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201240AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01071 TVA 0008 001 01 50 4 SO2 4,357.298001071 TVA 0008 001 01 50 5 SO2 2,834.696001071 TVA 0008 001 01 50 6 NOX 1,823.314001071 TVA 0008 001 01 50 6 SO2 3,934.988001071 TVA 0008 002 01 50 7 NOX 3,694.200001071 TVA 0008 002 01 50 7 SO2 6,518.666001071 TVA 0008 003 01 50 8 NOX 3,646.963001071 TVA 0008 003 01 50 8 SO2 4,100.945001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 101 1 6002 1 NOX 5,772.419001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 101 1 6002 1 SO2 16,967.289001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 102 1 6002 2 NOX 5,682.308001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 102 1 6002 2 SO2 15,760.193001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 103 1 6002 3 NOX 5,446.441001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 103 1 6002 3 SO2 13,515.093001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 104 1 6002 4 NOX 5,160.873001073 ALABAMA POWER COMPANY (MILLER POWER PLANT) 0107300011 104 1 6002 4 SO2 13,285.274001081 Southern Power Company 0036 001 01 7710 1A NOX 36.006001081 Southern Power Company 0036 001 01 7710 1A SO2 1.846001081 Southern Power Company 0036 002 01 7710 1B NOX 34.501001081 Southern Power Company 0036 002 01 7710 1B SO2 1.822001081 Southern Power Company 0036 003 01 7710 2A NOX 40.466001081 Southern Power Company 0036 003 01 7710 2A SO2 2.116001081 Southern Power Company 0036 004 01 7710 2B NOX 37.216001081 Southern Power Company 0036 004 01 7710 2B SO2 2.116001097 Alabama Power Company 1001 001 01 3 1 NOX 1,484.265001097 Alabama Power Company 1001 001 01 3 1 SO2 4,814.710001097 Alabama Power Company 1001 001 01 3 2 NOX 1,653.985001097 Alabama Power Company 1001 001 01 3 2 SO2 5,244.420001097 Alabama Power Company 1001 001 01 3 3 NOX 2,834.011001097 Alabama Power Company 1001 001 01 3 3 SO2 8,907.217001097 Alabama Power Company 1001 002 01 3 4 NOX 3,000.114001097 Alabama Power Company 1001 002 01 3 4 SO2 10,938.662001097 Alabama Power Company 1001 003 01 3 5 SO2 21,362.0720Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201241AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01097 Alabama Power Company 1001 005 01 3 6A NOX 37.865001097 Alabama Power Company 1001 005 01 3 6A SO2 2.309001097 Alabama Power Company 1001 006 01 3 6B NOX 39.424001097 Alabama Power Company 1001 006 01 3 6B SO2 2.311001097 Alabama Power Company 1001 007 01 3 7A NOX 33.936001097 Alabama Power Company 1001 007 01 3 7A SO2 2.346001097 Alabama Power Company 1001 008 01 3 7B NOX 33.409001097 Alabama Power Company 1001 008 01 3 7B SO2 2.258001097 Alabama Power Company 8073 001 01 7721 CC1 NOX 38.459001097 Alabama Power Company 8073 001 01 7721 CC1 SO2 3.356001097 Mobile Energy LLC 8066 001 01 55241 COG01 NOX 8.669001103 Decatur Energy Center LLC 0079 001 01 55292 CTG-1 NOX 38.234001103 Decatur Energy Center LLC 0079 001 01 55292 CTG-1 SO2 2.198001103 Decatur Energy Center LLC 0079 002 01 55292 CTG-2 NOX 28.891001103 Decatur Energy Center LLC 0079 002 01 55292 CTG-2 SO2 1.841001103 Decatur Energy Center LLC 0079 003 01 55292 CTG-3 NOX 33.962001103 Decatur Energy Center LLC 0079 003 01 55292 CTG-3 SO2 2.081001103 Morgan Energy Center LLC 0080 001 01 55293 CT-1 NOX 45.655001103 Morgan Energy Center LLC 0080 001 01 55293 CT-1 SO2 3.655001103 Morgan Energy Center LLC 0080 002 01 55293 CT-2 SO2 1.648001103 Morgan Energy Center LLC 0080 003 01 55293 CT-3 NOX 28.532001103 Morgan Energy Center LLC 0080 003 01 55293 CT-3 SO2 1.692001103 Solutia Inc 0010 001 01 880041 Z006 NOX 259.408001103 Solutia Inc 0010 002 01 880041 X053 NOX 0.021001103 Solutia Inc 0010 003 01 880041 X015 NOX 458.016001117 Alabama Power Company 0005 001 01 26 1 NOX 3,271.590001117 Alabama Power Company 0005 001 01 26 1 SO2 20,341.725001117 Alabama Power Company 0005 001 01 26 2 NOX 3,397.051001117 Alabama Power Company 0005 001 01 26 2 SO2 20,957.713001117 Alabama Power Company 0005 002 01 26 4 NOX 3,098.079001117 Alabama Power Company 0005 002 01 26 4 SO2 17,818.254001117 Alabama Power Company 0005 003 01 26 5 NOX 8,138.996001117 Alabama Power Company 0005 003 01 26 5 SO2 64,663.2850Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201242AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions01127 Alabama Power Company 0001 003 01 8 7 NOX 1,445.365001127 Alabama Power Company 0001 003 01 8 7 SO2 8,930.936001127 Alabama Power Company 0001 004 01 8 9 SO2 10,310.752001129 Alabama Power Company 0018 001 01 7697 CC1 NOX 247.086001129 Alabama Power Company 0018 001 01 7697 CC1 SO2 2.561001129 PowerSouth Energy Cooperative Inc 0001 001 02 56 1 NOX 715.381501129 PowerSouth Energy Cooperative Inc 0001 001 02 56 1 SO2 1,836.045501129 PowerSouth Energy Cooperative Inc 0001 002 01 56 1 NOX 715.381501129 PowerSouth Energy Cooperative Inc 0001 002 01 56 1 SO2 1,836.045501129 PowerSouth Energy Cooperative Inc 0001 002 01 56 2 NOX 3,703.715001129 PowerSouth Energy Cooperative Inc 0001 002 01 56 2 SO2 4,845.338001129 PowerSouth Energy Cooperative Inc 0001 003 01 56 3 NOX 4,995.522001129 PowerSouth Energy Cooperative Inc 0001 003 01 56 3 SO2 7,735.500001129 PowerSouth Energy Cooperative Inc 0012 002 01 7063 **2 NOX 2.985001129 PowerSouth Energy Cooperative Inc 0012 002 01 7063 **2 SO2 0.040001129 PowerSouth Energy Cooperative Inc 0012 003 01 7063 **3 SO2 0.02401.9.8.2 Alabama – Jefferson CountyNo issues identified.1.9.8.3 FloridaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12001 CITY OF GAINESVILLE, GRU 0010006 3 1 663 B1 NOX 201.596112001 CITY OF GAINESVILLE, GRU0010006 3 1 663 B1 SO2 0.608812001 CITY OF GAINESVILLE, GRU0010006 3 2 663 B1 NOX 40.077912001 CITY OF GAINESVILLE, GRU 0010006 3 2 663 B1 SO2 110.693212001 CITY OF GAINESVILLE, GRU 0010006 5 3 663 B2 NOX 3,624.850012001 CITY OF GAINESVILLE, GRU 0010006 5 3 663 B2 SO2 7,837.084012001 CITY OF GAINESVILLE, GRU0010006 6 1 663 CT3 NOX 9.199012001 CITY OF GAINESVILLE, GRU0010006 6 1 663 CT3 SO2 0.166012001 FLORIDA POWER CORPORATION D/B/APROGRESS 0010001 7 2 7345 1 NOX 109.743012001 FLORIDA POWER CORPORATION D/B/A PROGRESS 0010001 7 27345 1 SO2 1.020012001 GAINESVILLE REGIONAL UTILITIES 0010005 10 1 664CC1 NOX 30.159012001 GAINESVILLE REGIONAL UTILITIES 0010005 10 1 664CC1 SO2 0.6710Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201243AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 1 NOX 2.932512005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 1 SO2 6.758512005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 2 NOX 2.052912005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 1 643 2 SO2 6.093212005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 1 NOX 2,768.137012005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 1 SO2 6,379.594212005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 2 NOX 2,967.463212005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 2 643 2 SO2 8,807.783012005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 1 NOX 0.171612005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 1 SO2 0.395412005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 2 NOX 0.024912005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 1 3 643 2 SO2 0.073812005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 1 643 4 NOX 148.202612005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 1 643 4 SO2 0.811612005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 2 643 4 NOX 4.456412005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 4 2 643 4 SO2 0.024412005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 1 643 5 NOX 144.839612005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 1 643 5 SO2 0.750012005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 2 643 5 NOX 5.014412005 GULF POWER COMPANY LANSING SMITH PLANT 0050014 5 2 643 5 SO2 0.026012009 FLORIDA POWER & LIGHT (PCC) 0090006 1 1 609 PCC1 NOX 1,356.283612009 FLORIDA POWER & LIGHT (PCC) 0090006 1 1 609 PCC1 SO2 1.965812009 FLORIDA POWER & LIGHT (PCC) 0090006 1 2 609 PCC1 NOX 829.858012009 FLORIDA POWER & LIGHT (PCC) 0090006 1 2 609 PCC1 SO2 1,894.741912009 FLORIDA POWER & LIGHT (PCC) 0090006 1 6 609 PCC1 NOX 0.011412009 FLORIDA POWER & LIGHT (PCC) 0090006 1 6 609 PCC1 SO2 0.000212009 FLORIDA POWER & LIGHT (PCC) 0090006 2 1 609 PCC2 NOX 1,665.609512009 FLORIDA POWER & LIGHT (PCC) 0090006 2 1 609 PCC2 SO2 2.220912009 FLORIDA POWER & LIGHT (PCC) 0090006 2 2 609 PCC2 NOX 1,141.284012009 FLORIDA POWER & LIGHT (PCC) 0090006 2 2 609 PCC2 SO2 2,396.808812009 FLORIDA POWER & LIGHT (PCC) 0090006 2 6 609 PCC2 NOX 0.012412009 FLORIDA POWER & LIGHT (PCC) 0090006 2 6 609 PCC2 SO2 0.000312009 OLEANDER POWER PROJECT, LP 0090180 1 1 55286 O-1 NOX 0.0175Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201244AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12009 OLEANDER POWER PROJECT, LP 0090180 1 1 55286 O-1 SO2 0.033212009 OLEANDER POWER PROJECT, LP 0090180 1 2 55286 O-1 NOX 16.844512009 OLEANDER POWER PROJECT, LP 0090180 1 2 55286 O-1 SO2 0.126812009 OLEANDER POWER PROJECT, LP 0090180 2 1 55286 O-2 NOX 0.554012009 OLEANDER POWER PROJECT, LP 0090180 2 1 55286 O-2 SO2 0.569012009 OLEANDER POWER PROJECT, LP 0090180 2 2 55286 O-2 NOX 27.582012009 OLEANDER POWER PROJECT, LP 0090180 2 2 55286 O-2 SO2 0.561012009 OLEANDER POWER PROJECT, LP 0090180 3 1 55286 O-3 NOX 0.060312009 OLEANDER POWER PROJECT, LP 0090180 3 1 55286 O-3 SO2 0.100112009 OLEANDER POWER PROJECT, LP 0090180 3 2 55286 O-3 NOX 24.503712009 OLEANDER POWER PROJECT, LP 0090180 3 2 55286 O-3 SO2 0.241912009 OLEANDER POWER PROJECT, LP 0090180 4 1 55286 O-4 NOX 0.591612009 OLEANDER POWER PROJECT, LP 0090180 4 1 55286 O-4 SO2 0.488912009 OLEANDER POWER PROJECT, LP 0090180 4 2 55286 O-4 NOX 26.585412009 OLEANDER POWER PROJECT, LP 0090180 4 2 55286 O-4 SO2 0.435112009 ORLANDO UTLITIES COMMISSION0090008 5 2 683 **C NOX 4.536012009 ORLANDO UTLITIES COMMISSION0090008 5 2 683 **C SO2 0.037012009 ORLANDO UTLITIES COMMISSION0090008 6 2 683 **D NOX 6.634012009 ORLANDO UTLITIES COMMISSION0090008 6 2 683 **D SO2 0.069012009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 1 NOX 29.939912009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 1 SO2 0.105612009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 2 NOX 39.551612009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 1 55318 2 SO2 0.145912009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 1 NOX 19.861112009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 1 SO2 80.702812009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 2 NOX 68.226412009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 2 55318 2 SO2 342.253912009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 3 55318 1 SO2 0.075512009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 3 55318 2 SO2 0.073212009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 1 4 55318 2 SO2 0.081012009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 1 55318 3 NOX 77.052112009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 1 55318 3 SO2 0.281012009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 2 55318 3 NOX 98.3389Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201245AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12009 RELIANT ENERGY FLORIDA, L.L.C. 0090196 3 2 55318 3 SO2 489.397012011 FLORIDA POWER & LIGHT (PFL) 0110037 35 1 613 4GT1 NOX 0.094112011 FLORIDA POWER & LIGHT (PFL) 0110037 35 1 613 4GT1 SO2 0.139612011 FLORIDA POWER & LIGHT (PFL) 0110037 35 2 613 4GT1 NOX 448.493912011 FLORIDA POWER & LIGHT (PFL) 0110037 35 2 613 4GT1 SO2 2.482412011 FLORIDA POWER & LIGHT (PFL) 0110037 36 1 613 4GT2 NOX 500.238412011 FLORIDA POWER & LIGHT (PFL) 0110037 36 1 613 4GT2 SO2 2.454012011 FLORIDA POWER & LIGHT (PFL) 0110037 36 2 613 4GT2 NOX 0.105612011 FLORIDA POWER & LIGHT (PFL) 0110037 36 2 613 4GT2 SO2 0.138012011 FLORIDA POWER & LIGHT (PFL) 0110037 37 2 613 5GT1 NOX 678.057012011 FLORIDA POWER & LIGHT (PFL) 0110037 37 2 613 5GT1 SO2 3.396012011 FLORIDA POWER & LIGHT (PFL) 0110037 38 1 613 5GT2 NOX 686.054012011 FLORIDA POWER & LIGHT (PFL) 0110037 38 1 613 5GT2 SO2 3.418012011 FLORIDA POWER & LIGHT (PPE) 0110036 1 1 617 PPE1 NOX 43.613312011 FLORIDA POWER & LIGHT (PPE) 0110036 1 1 617 PPE1 SO2 0.192212011 FLORIDA POWER & LIGHT (PPE) 0110036 1 2 617 PPE1 NOX 387.032712011 FLORIDA POWER & LIGHT (PPE) 0110036 1 2 617 PPE1 SO2 1,484.126412011 FLORIDA POWER & LIGHT (PPE) 0110036 1 7 617 PPE1 NOX 0.012112011 FLORIDA POWER & LIGHT (PPE) 0110036 1 7 617 PPE1 SO2 0.000412011 FLORIDA POWER & LIGHT (PPE) 0110036 2 1 617 PPE2 NOX 30.215012011 FLORIDA POWER & LIGHT (PPE) 0110036 2 1 617 PPE2 SO2 0.136712011 FLORIDA POWER & LIGHT (PPE) 0110036 2 2 617 PPE2 NOX 303.411012011 FLORIDA POWER & LIGHT (PPE) 0110036 2 2 617 PPE2 SO2 1,194.452012011 FLORIDA POWER & LIGHT (PPE) 0110036 2 6 617 PPE2 NOX 0.010012011 FLORIDA POWER & LIGHT (PPE) 0110036 2 6 617 PPE2 SO2 0.000312011 FLORIDA POWER & LIGHT (PPE) 0110036 3 1 617 PPE3 NOX 604.125312011 FLORIDA POWER & LIGHT (PPE) 0110036 3 1 617 PPE3 SO2 1.492012011 FLORIDA POWER & LIGHT (PPE) 0110036 3 2 617 PPE3 NOX 1,478.764812011 FLORIDA POWER & LIGHT (PPE) 0110036 3 2 617 PPE3 SO2 3,177.451312011 FLORIDA POWER & LIGHT (PPE) 0110036 3 6 617 PPE3 NOX 0.040912011 FLORIDA POWER & LIGHT (PPE) 0110036 3 6 617 PPE3 SO2 0.000712011 FLORIDA POWER & LIGHT (PPE) 0110036 4 1 617 PPE4 NOX 540.360412011 FLORIDA POWER & LIGHT (PPE) 0110036 4 1 617 PPE4 SO2 1.3622Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201246AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12011 FLORIDA POWER & LIGHT (PPE) 0110036 4 2 617 PPE4 NOX 2,000.326612011 FLORIDA POWER & LIGHT (PPE) 0110036 4 2 617 PPE4 SO2 4,387.456812011 FLORIDA POWER & LIGHT (PPE) 0110036 4 6 617 PPE4 NOX 0.050012011 FLORIDA POWER & LIGHT (PPE) 0110036 4 6 617 PPE4 SO2 0.000912017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 1 3 628 1 NOX 4,054.805012017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 1 3 628 1 SO2 16,738.693012017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 2 4 628 2 NOX 4,910.118012017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 2 4 628 2 SO2 19,166.410012017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 3 2 628 5 NOX 12,553.819012017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 3 2 628 5 SO2 26,650.920012017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 4 2 628 4 NOX 14,430.849012017 FLORIDA POWER CORPORATION D/B/APROGRESS 0170004 4 2 628 4 SO2 29,763.633012027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 1 55422 CT1 NOX 0.100112027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 1 55422 CT1 SO2 0.015412027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 2 55422 CT1 NOX 2.137912027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 1 2 55422 CT1 SO2 0.037612027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 1 55422 CT2 NOX 1.256112027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 1 55422 CT2 SO2 0.314212027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 2 55422 CT2 NOX 2.586912027 DESOTO COUNTY GENERATING COMPANY, LLC 0270016 2 2 55422 CT2 SO2 0.189812031 JEA 0310045 16 1 207 1 NOX 27.226812031 JEA 0310045 16 1 207 1 SO2 0.889912031 JEA 0310045 16 2 207 1 NOX 32.253312031 JEA 0310045 16 2 207 1 SO2 128.514112031 JEA 0310045 16 3 207 1 NOX 10,257.372012031 JEA 0310045 16 3 207 1 SO2 6,506.193012031 JEA 0310045 17 1 207 2 NOX 29.475012031 JEA 0310045 17 1 207 2 SO2 0.499612031 JEA 0310045 17 2 207 2 NOX 1,824.894412031 JEA 0310045 17 2 207 2 SO2 3,770.114812031 JEA 0310045 17 3 207 2 NOX 9,860.013512031 JEA 0310045 17 3 207 2 SO2 3,245.016612031 JEA 0310045 26 1 667 2A NOX 103.3139Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201247AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12031 JEA 0310045 26 1 667 2A SO2 69.817112031 JEA 0310045 26 2 667 2A NOX 611.590312031 JEA 0310045 26 2 667 2A SO2 1,338.595912031 JEA 0310045 26 3 667 2A NOX 3.796812031 JEA 0310045 27 1 667 1A NOX 108.698812031 JEA 0310045 27 1 667 1A SO2 70.496012031 JEA 0310045 27 2 667 1A NOX 614.093212031 JEA 0310045 27 2 667 1A SO2 1,440.123012031 JEA 0310045 27 3 667 1A NOX 1.800012031 JEA 0310045 3 1 667 3 NOX 561.382512031 JEA 0310045 3 2 667 3 NOX 186.036812031 JEA 0310045 3 2 667 3 SO2 1,281.108012031 JEA 0310045 3 5 667 3 NOX 0.673712031 JEA 0310047 15 1 666 7 NOX 11.082812031 JEA 0310047 15 2 666 7 NOX 0.097212031 JEA 0310047 15 2 666 7 SO2 0.240012031 JEA 0310485 1 1 7846 1 NOX 9.493012031 JEA 0310485 1 1 7846 1 SO2 0.169012031 JEA 0310485 2 2 7846 2 NOX 36.911012031 JEA 0310485 2 2 7846 2 SO2 1.548012031 JEA 0310485 3 2 7846 3 NOX 41.803012031 JEA 0310485 3 2 7846 3 SO2 1.786012033 GULF POWER COMPANY CRISTPLANT 0330045 1 1 641 6 NOX 9.683812033 GULF POWER COMPANY CRISTPLANT 0330045 1 1 641 6 SO2 39.788112033 GULF POWER COMPANY CRISTPLANT 0330045 1 1 641 7 NOX 1.552012033 GULF POWER COMPANY CRISTPLANT 0330045 1 1 641 7 SO2 22.070812033 GULF POWER COMPANY CRISTPLANT 0330045 1 2 641 4 NOX 0.449712033 GULF POWER COMPANY CRISTPLANT 0330045 1 2 641 4 SO2 1.594612033 GULF POWER COMPANY CRISTPLANT 0330045 1 2 641 5 NOX 0.306912033 GULF POWER COMPANY CRISTPLANT 0330045 1 2 641 5 SO2 1.167312033 GULF POWER COMPANY CRISTPLANT 0330045 1 2 641 6 NOX 0.040212033 GULF POWER COMPANY CRISTPLANT 0330045 1 2 641 6 SO2 0.165112033 GULF POWER COMPANY CRISTPLANT 0330045 1 2 641 7 NOX 0.1938Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201248AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12033 GULF POWER COMPANY CRISTPLANT 0330045 1 2 641 7 SO2 2.756012033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 4 NOX 1,058.544512033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 4 SO2 3,753.204712033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 5 NOX 845.807712033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 5 SO2 3,216.858712033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 6 NOX 2,942.815012033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 6 SO2 12,951.347812033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 7 NOX 1,488.340212033 GULF POWER COMPANY CRIST PLANT 0330045 1 3 641 7 SO2 21,165.054212033 GULF POWER COMPANY CRISTPLANT 0330045 1 4 641 4 NOX 0.670612033 GULF POWER COMPANY CRISTPLANT 0330045 1 4 641 4 SO2 2.377912033 GULF POWER COMPANY CRISTPLANT 0330045 1 4 641 5 NOX 6.423412033 GULF POWER COMPANY CRISTPLANT 0330045 1 4 641 5 SO2 24.430012033 GULF POWER COMPANY CRISTPLANT 0330045 1 5 641 4 NOX 0.089112033 GULF POWER COMPANY CRISTPLANT 0330045 1 5 641 4 SO2 0.315812049 HARDEE POWER PARTNERS LIMITED0490015 5 1 50949 CT2B NOX 2.440212049 HARDEE POWER PARTNERS LIMITED0490015 5 2 50949 CT2B NOX 0.218812049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 1 1 7380 1 NOX 30.605012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 1 7380 1 SO2 0.558012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 1 2 7380 1 NOX 0.062012049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 1 2 7380 1 SO2 0.010012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 2 1 7380 2 NOX 33.606912049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 1 7380 2 SO2 0.653012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 2 2 7380 2 NOX 0.080112049 SEMINOLE ELECTRIC COOPERATIVE, INC. 0490340 2 2 7380 2 SO2 0.010012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 5 1 7380 4A NOX 11.612012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 5 1 7380 4A SO2 0.140012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 5 2 7380 4B NOX 11.828012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 5 2 7380 4B SO2 0.131012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 6 1 7380 5A NOX 10.297012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 6 1 7380 5A SO2 0.129012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 6 2 7380 5B NOX 9.838012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 6 2 7380 5B SO2 0.1350Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201249AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 7 1 7380 6A NOX 11.342012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 7 1 7380 6A SO2 0.150012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 7 2 7380 6B NOX 10.793012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 7 2 7380 6B SO2 0.146012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 8 1 7380 7A NOX 12.812012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 8 1 7380 7A SO2 0.172012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 8 2 7380 7B NOX 12.940012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 8 2 7380 7B SO2 0.171012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 9 1 7380 8A NOX 10.781012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 9 1 7380 8A SO2 0.123012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 9 2 7380 8B NOX 11.032012049 SEMINOLE ELECTRIC COOPERATIVE,INC. 0490340 9 2 7380 8B SO2 0.133012049 VANDOLAH POWER COMPANY, LLC0490043 1 1 55415 GT101 NOX 0.671812049 VANDOLAH POWER COMPANY, LLC0490043 1 1 55415 GT101 SO2 0.448012049 VANDOLAH POWER COMPANY, LLC0490043 1 2 55415 GT101 NOX 13.507212049 VANDOLAH POWER COMPANY, LLC0490043 2 1 55415 GT201 NOX 2.005412049 VANDOLAH POWER COMPANY, LLC0490043 2 1 55415 GT201 SO2 1.207012049 VANDOLAH POWER COMPANY, LLC0490043 2 2 55415 GT201 NOX 8.514612049 VANDOLAH POWER COMPANY, LLC0490043 3 1 55415 GT301 NOX 2.296312049 VANDOLAH POWER COMPANY, LLC0490043 3 1 55415 GT301 SO2 1.720012049 VANDOLAH POWER COMPANY, LLC0490043 3 2 55415 GT301 NOX 6.959712049 VANDOLAH POWER COMPANY, LLC0490043 4 1 55415 GT401 NOX 0.461912049 VANDOLAH POWER COMPANY, LLC0490043 4 1 55415 GT401 SO2 0.297012049 VANDOLAH POWER COMPANY, LLC0490043 4 2 55415 GT401 NOX 5.560112057 TAMPA ELECTRIC COMPANY 0570039 1 2 645 BB01 NOX 10,043.608012057 TAMPA ELECTRIC COMPANY 0570039 1 2 645 BB01 SO2 2,999.205012057 TAMPA ELECTRIC COMPANY 0570039 2 2 645 BB02 NOX 10,050.939012057 TAMPA ELECTRIC COMPANY 0570039 2 2 645 BB02 SO2 2,716.640012057 TAMPA ELECTRIC COMPANY 0570039 3 2 645 BB03 NOX 3,838.168012057 TAMPA ELECTRIC COMPANY 0570039 3 2 645 BB03 SO2 1,762.555012057 TAMPA ELECTRIC COMPANY 0570039 4 2 645 BB04 NOX 1,192.414012057 TAMPA ELECTRIC COMPANY 0570039 4 2 645 BB04 SO2 2,396.061012057 TAMPA ELECTRIC COMPANY 0570040 20 1 7873 CT1A NOX 52.8910Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201250AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12057 TAMPA ELECTRIC COMPANY 0570040 20 1 7873 CT1A SO2 2.203012057 TAMPA ELECTRIC COMPANY 0570040 21 1 7873 CT1B NOX 51.293012057 TAMPA ELECTRIC COMPANY 0570040 21 1 7873 CT1B SO2 2.248012057 TAMPA ELECTRIC COMPANY 0570040 22 1 7873 CT1C NOX 44.772012057 TAMPA ELECTRIC COMPANY 0570040 22 1 7873 CT1C SO2 1.862012057 TAMPA ELECTRIC COMPANY 0570040 23 1 7873 CT2A NOX 60.582012057 TAMPA ELECTRIC COMPANY 0570040 23 1 7873 CT2A SO2 2.673012057 TAMPA ELECTRIC COMPANY 0570040 24 1 7873 CT2B NOX 56.355012057 TAMPA ELECTRIC COMPANY 0570040 24 1 7873 CT2B SO2 2.653012057 TAMPA ELECTRIC COMPANY 0570040 25 1 7873 CT2C NOX 59.920012057 TAMPA ELECTRIC COMPANY 0570040 25 1 7873 CT2C SO2 2.673012057 TAMPA ELECTRIC COMPANY 0570040 26 1 7873 CT2D NOX 614.234012057 TAMPA ELECTRIC COMPANY 0570040 26 1 7873 CT2D SO2 2.570012061 CITY OF VERO BEACH 0610029 3 1 693 3 NOX 3.791012061 CITY OF VERO BEACH 0610029 3 1 693 3 SO2 0.024012061 CITY OF VERO BEACH 0610029 4 1 693 4 NOX 20.621012061 CITY OF VERO BEACH 0610029 4 1 693 4 SO2 0.089012061 CITY OF VERO BEACH 0610029 5 1 693 **5 NOX 7.658112061 CITY OF VERO BEACH 0610029 5 1 693 **5 SO2 0.143012061 CITY OF VERO BEACH 0610029 5 2 693 **5 NOX 0.001912061 CITY OF VERO BEACH 0610029 5 2 693 **5 SO2 0.058012063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 1 642 1 NOX 0.361012063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 1 642 1 SO2 1.077312063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 1 642 2 NOX 0.423812063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 1 642 2 SO2 1.259912063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 2 642 1 NOX 857.996712063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 2 642 1 SO2 2,560.767512063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 2 642 2 NOX 813.863212063 GULF POWER COMPANY SCHOLZ PLANT 0630014 1 2 642 2 SO2 2,419.796112063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 3 642 1 NOX 0.011412063 GULF POWER COMPANY SCHOLZPLANT 0630014 1 3 642 1 SO2 0.041212071 FLORIDA POWER & LIGHT (PFM) 0710002 18 1 612 FMCT2A NOX 151.483012071 FLORIDA POWER & LIGHT (PFM) 0710002 18 1 612 FMCT2A SO2 3.3410Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201251AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12071 FLORIDA POWER & LIGHT (PFM) 0710002 19 1 612 FMCT2B NOX 146.258012071 FLORIDA POWER & LIGHT (PFM) 0710002 19 1 612 FMCT2B SO2 3.183012071 FLORIDA POWER & LIGHT (PFM) 0710002 20 1 612 FMCT2C NOX 160.901012071 FLORIDA POWER & LIGHT (PFM) 0710002 20 1 612 FMCT2C SO2 3.453012071 FLORIDA POWER & LIGHT (PFM) 0710002 21 1 612 FMCT2D NOX 158.289012071 FLORIDA POWER & LIGHT (PFM) 0710002 21 1 612 FMCT2D SO2 3.301012071 FLORIDA POWER & LIGHT (PFM) 0710002 22 1 612 FMCT2E NOX 157.256012071 FLORIDA POWER & LIGHT (PFM) 0710002 22 1 612 FMCT2E SO2 3.400012071 FLORIDA POWER & LIGHT (PFM) 0710002 23 1 612 FMCT2F NOX 151.786012071 FLORIDA POWER & LIGHT (PFM) 0710002 23 1 612 FMCT2F SO2 3.237012071 FLORIDA POWER & LIGHT (PFM) 0710002 27 1 612 PFM3A NOX 31.692612071 FLORIDA POWER & LIGHT (PFM) 0710002 27 1 612 PFM3A SO2 0.535312071 FLORIDA POWER & LIGHT (PFM) 0710002 27 2 612 PFM3A NOX 3.043412071 FLORIDA POWER & LIGHT (PFM) 0710002 27 2 612 PFM3A SO2 0.660712071 FLORIDA POWER & LIGHT (PFM) 0710002 28 1 612 PFM3B NOX 2.361712071 FLORIDA POWER & LIGHT (PFM) 0710002 28 1 612 PFM3B SO2 0.366912071 FLORIDA POWER & LIGHT (PFM) 0710002 28 2 612 PFM3B NOX 33.670312071 FLORIDA POWER & LIGHT (PFM) 0710002 28 2 612 PFM3B SO2 0.495112073 CITY OF TALLAHASSEE 0730003 1 1 688 1 NOX 306.707012073 CITY OF TALLAHASSEE 0730003 1 1 688 1 SO2 0.830012073 CITY OF TALLAHASSEE 0730003 31 1 688 HC3 NOX 0.022412073 CITY OF TALLAHASSEE 0730003 31 1 688 HC3 SO2 1.346612073 CITY OF TALLAHASSEE 0730003 31 2 688 HC3 NOX 4.234612073 CITY OF TALLAHASSEE 0730003 31 2 688 HC3 SO2 0.192412073 CITY OF TALLAHASSEE 0730003 32 1 688 HC4 NOX 0.014512073 CITY OF TALLAHASSEE 0730003 32 1 688 HC4 SO2 0.855112073 CITY OF TALLAHASSEE 0730003 32 2 688 HC4 NOX 4.316512073 CITY OF TALLAHASSEE 0730003 32 2 688 HC4 SO2 0.106912073 CITY OF TALLAHASSEE 0730003 4 1 688 2 NOX 393.086812073 CITY OF TALLAHASSEE 0730003 4 1 688 2 SO2 1.399912073 CITY OF TALLAHASSEE 0730003 4 2 688 2 NOX 90.391212073 CITY OF TALLAHASSEE 0730003 4 2 688 2 SO2 492.879112081 FLORIDA POWER & LIGHT (PMT) 0810010 1 2 6042 PMT1 NOX 1,021.5074Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201252AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12081 FLORIDA POWER & LIGHT (PMT) 0810010 1 2 6042 PMT1 SO2 6,212.965512081 FLORIDA POWER & LIGHT (PMT) 0810010 1 4 6042 PMT1 NOX 0.020112081 FLORIDA POWER & LIGHT (PMT) 0810010 1 4 6042 PMT1 SO2 0.001012081 FLORIDA POWER & LIGHT (PMT) 0810010 1 7 6042 PMT1 NOX 269.404512081 FLORIDA POWER & LIGHT (PMT) 0810010 1 7 6042 PMT1 SO2 1.844512081 FLORIDA POWER & LIGHT (PMT) 0810010 2 2 6042 PMT2 NOX 1,147.361412081 FLORIDA POWER & LIGHT (PMT) 0810010 2 2 6042 PMT2 SO2 5,582.577112081 FLORIDA POWER & LIGHT (PMT) 0810010 2 3 6042 PMT2 NOX 0.023012081 FLORIDA POWER & LIGHT (PMT) 0810010 2 3 6042 PMT2 SO2 0.000912081 FLORIDA POWER & LIGHT (PMT) 0810010 2 6 6042 PMT2 NOX 303.983612081 FLORIDA POWER & LIGHT (PMT) 0810010 2 6 6042 PMT2 SO2 1.664912081 FLORIDA POWER & LIGHT (PMT) 0810010 5 1 6042 MTCT3A NOX 51.572012081 FLORIDA POWER & LIGHT (PMT) 0810010 5 1 6042 MTCT3A SO2 3.584012081 FLORIDA POWER & LIGHT (PMT) 0810010 6 1 6042 MTCT3B NOX 57.014012081 FLORIDA POWER & LIGHT (PMT) 0810010 6 1 6042 MTCT3B SO2 3.661012081 FLORIDA POWER & LIGHT (PMT) 0810010 7 1 6042 MTCT3C NOX 51.826012081 FLORIDA POWER & LIGHT (PMT) 0810010 7 1 6042 MTCT3C SO2 3.512012081 FLORIDA POWER & LIGHT (PMT) 0810010 8 1 6042 MTCT3D NOX 58.812012081 FLORIDA POWER & LIGHT (PMT) 0810010 8 1 6042 MTCT3D SO2 3.795012085 FLORIDA POWER & LIGHT (PMR) 0850001 1 1 6043 PMR1 NOX 1,028.914812085 FLORIDA POWER & LIGHT (PMR) 0850001 1 1 6043 PMR1 SO2 3.586112085 FLORIDA POWER & LIGHT (PMR) 0850001 1 3 6043 PMR1 NOX 875.301912085 FLORIDA POWER & LIGHT (PMR) 0850001 1 3 6043 PMR1 SO2 4,960.278312085 FLORIDA POWER & LIGHT (PMR) 0850001 1 6 6043 PMR1 NOX 0.019312085 FLORIDA POWER & LIGHT (PMR) 0850001 1 6 6043 PMR1 SO2 0.000512085 FLORIDA POWER & LIGHT (PMR) 0850001 11 1 6043 PMR8A NOX 49.890812085 FLORIDA POWER & LIGHT (PMR) 0850001 11 1 6043 PMR8A SO2 3.463312085 FLORIDA POWER & LIGHT (PMR) 0850001 11 2 6043 PMR8A NOX 0.037212085 FLORIDA POWER & LIGHT (PMR) 0850001 11 2 6043 PMR8A SO2 0.000712085 FLORIDA POWER & LIGHT (PMR) 0850001 12 1 6043 PMR8B NOX 53.962912085 FLORIDA POWER & LIGHT (PMR) 0850001 12 1 6043 PMR8B SO2 3.958712085 FLORIDA POWER & LIGHT (PMR) 0850001 12 2 6043 PMR8B NOX 0.108112085 FLORIDA POWER & LIGHT (PMR) 0850001 12 2 6043 PMR8B SO2 0.0023Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201253AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12085 FLORIDA POWER & LIGHT (PMR) 0850001 17 1 6043 PMR8C NOX 54.478412085 FLORIDA POWER & LIGHT (PMR) 0850001 17 1 6043 PMR8C SO2 3.914712085 FLORIDA POWER & LIGHT (PMR) 0850001 17 2 6043 PMR8C NOX 0.742612085 FLORIDA POWER & LIGHT (PMR) 0850001 17 2 6043 PMR8C SO2 0.013312085 FLORIDA POWER & LIGHT (PMR) 0850001 18 1 6043 PMR8D NOX 48.812912085 FLORIDA POWER & LIGHT (PMR) 0850001 18 1 6043 PMR8D SO2 3.901012085 FLORIDA POWER & LIGHT (PMR) 0850001 18 2 6043 PMR8D NOX 1.142112085 FLORIDA POWER & LIGHT (PMR) 0850001 18 2 6043 PMR8D SO2 0.019012085 FLORIDA POWER & LIGHT (PMR) 0850001 2 1 6043 PMR2 NOX 1,007.402312085 FLORIDA POWER & LIGHT (PMR) 0850001 2 1 6043 PMR2 SO2 3.238712085 FLORIDA POWER & LIGHT (PMR) 0850001 2 3 6043 PMR2 NOX 1,065.328112085 FLORIDA POWER & LIGHT (PMR) 0850001 2 3 6043 PMR2 SO2 5,568.798712085 FLORIDA POWER & LIGHT (PMR) 0850001 2 6 6043 PMR2 NOX 0.019612085 FLORIDA POWER & LIGHT (PMR) 0850001 2 6 6043 PMR2 SO2 0.000612085 FLORIDA POWER & LIGHT (PMR) 0850001 3 2 6043 HRSG3A NOX 191.378012085 FLORIDA POWER & LIGHT (PMR) 0850001 3 2 6043 HRSG3A SO2 3.428012085 FLORIDA POWER & LIGHT (PMR) 0850001 4 1 6043 HRSG3B NOX 231.617012085 FLORIDA POWER & LIGHT (PMR) 0850001 4 1 6043 HRSG3B SO2 3.429012085 FLORIDA POWER & LIGHT (PMR) 0850001 5 2 6043 HRSG4A NOX 246.151012085 FLORIDA POWER & LIGHT (PMR) 0850001 5 2 6043 HRSG4A SO2 3.443012085 FLORIDA POWER & LIGHT (PMR) 0850001 6 1 6043 HRSG4B NOX 183.877012085 FLORIDA POWER & LIGHT (PMR) 0850001 6 1 6043 HRSG4B SO2 3.269012086 FLORIDA POWER & LIGHT (PCU) 0250001 3 2 610 PCU5 NOX 12.297012086 FLORIDA POWER & LIGHT (PCU) 0250001 3 2 610 PCU5 SO2 0.072012086 FLORIDA POWER & LIGHT (PCU) 0250001 4 2 610 PCU6 NOX 63.730012086 FLORIDA POWER & LIGHT (PCU) 0250001 4 2 610 PCU6 SO2 0.381012086 FLORIDA POWER & LIGHT (PTF) 0250003 1 1 621 PTP1 NOX 141.521112086 FLORIDA POWER & LIGHT (PTF) 0250003 1 1 621 PTP1 SO2 0.505012086 FLORIDA POWER & LIGHT (PTF) 0250003 1 2 621 PTP1 NOX 1,330.613812086 FLORIDA POWER & LIGHT (PTF) 0250003 1 2 621 PTP1 SO2 4,218.407312086 FLORIDA POWER & LIGHT (PTF) 0250003 1 5 621 PTP1 NOX 0.022112086 FLORIDA POWER & LIGHT (PTF) 0250003 1 5 621 PTP1 SO2 0.000612086 FLORIDA POWER & LIGHT (PTF) 0250003 10 1 621 TPCT5B NOX 35.7690Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201254AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12086 FLORIDA POWER & LIGHT (PTF) 0250003 10 1 621 TPCT5B SO2 3.196912086 FLORIDA POWER & LIGHT (PTF) 0250003 10 2 621 TPCT5B NOX 2.018012086 FLORIDA POWER & LIGHT (PTF) 0250003 10 2 621 TPCT5B SO2 0.017112086 FLORIDA POWER & LIGHT (PTF) 0250003 11 1 621 TPCT5C NOX 33.777012086 FLORIDA POWER & LIGHT (PTF) 0250003 11 1 621 TPCT5C SO2 3.130812086 FLORIDA POWER & LIGHT (PTF) 0250003 11 2 621 TPCT5C NOX 1.591012086 FLORIDA POWER & LIGHT (PTF) 0250003 11 2 621 TPCT5C SO2 0.013212086 FLORIDA POWER & LIGHT (PTF) 0250003 12 1 621 TPCT5D NOX 36.602312086 FLORIDA POWER & LIGHT (PTF) 0250003 12 1 621 TPCT5D SO2 3.165212086 FLORIDA POWER & LIGHT (PTF) 0250003 12 2 621 TPCT5D NOX 2.322712086 FLORIDA POWER & LIGHT (PTF) 0250003 12 2 621 TPCT5D SO2 0.015812086 FLORIDA POWER & LIGHT (PTF) 0250003 2 1 621 PTP2 NOX 164.962712086 FLORIDA POWER & LIGHT (PTF) 0250003 2 1 621 PTP2 SO2 0.492312086 FLORIDA POWER & LIGHT (PTF) 0250003 2 2 621 PTP2 NOX 1,369.479012086 FLORIDA POWER & LIGHT (PTF) 0250003 2 2 621 PTP2 SO2 3,630.897212086 FLORIDA POWER & LIGHT (PTF) 0250003 2 5 621 PTP2 NOX 0.021212086 FLORIDA POWER & LIGHT (PTF) 0250003 2 5 621 PTP2 SO2 0.000512086 FLORIDA POWER & LIGHT (PTF) 0250003 9 1 621 TPCT5A NOX 33.022012086 FLORIDA POWER & LIGHT (PTF) 0250003 9 1 621 TPCT5A SO2 3.190112086 FLORIDA POWER & LIGHT (PTF) 0250003 9 2 621 TPCT5A NOX 1.779012086 FLORIDA POWER & LIGHT (PTF) 0250003 9 2 621 TPCT5A SO2 0.014912087 KEYS ENERGY SERVICES 0870003 11 1 6584 CT4 NOX 1.431012087 KEYS ENERGY SERVICES 0870003 11 1 6584 CT4 SO2 1.465012095 ORLANDO COGEN LIMITED, L.P.0950203 1 1 54466 1 NOX 216.196012095 ORLANDO COGEN LIMITED, L.P. 0950203 1 1 54466 1 SO2 2.311012095 ORLANDO UTILITIES COMMISSION 0950137 1 2 564 1 NOX 10.383912095 ORLANDO UTILITIES COMMISSION 0950137 1 2 564 1 SO2 6.027212095 ORLANDO UTILITIES COMMISSION0950137 1 3 564 1 NOX 6,043.701012095 ORLANDO UTILITIES COMMISSION0950137 1 3 564 1 SO2 4,603.364412095 ORLANDO UTILITIES COMMISSION 0950137 1 4 564 1 NOX 114.321512095 ORLANDO UTILITIES COMMISSION 0950137 1 5 564 1 NOX 0.443612095 ORLANDO UTILITIES COMMISSION 0950137 1 5 564 1 SO2 1.239512095 ORLANDO UTILITIES COMMISSION 0950137 2 2 564 2 NOX 2.1343Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201255AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12095 ORLANDO UTILITIES COMMISSION 0950137 2 2 564 2 SO2 1.528412095 ORLANDO UTILITIES COMMISSION0950137 2 3 564 2 NOX 2,571.211512095 ORLANDO UTILITIES COMMISSION0950137 2 3 564 2 SO2 1,854.051512095 ORLANDO UTILITIES COMMISSION 0950137 2 4 564 2 NOX 0.186912095 ORLANDO UTILITIES COMMISSION 0950137 2 4 564 2 SO2 1.235112095 ORLANDO UTILITIES COMMISSION 0950137 2 5 564 2 NOX 18.991412095 ORLANDO UTILITIES COMMISSION 0950137 26 1 55821 25 NOX 64.460012095 ORLANDO UTILITIES COMMISSION 0950137 26 1 55821 25 SO2 1.517612095 ORLANDO UTILITIES COMMISSION 0950137 26 2 55821 25 NOX 0.022012095 ORLANDO UTILITIES COMMISSION 0950137 26 2 55821 25 SO2 0.052412095 ORLANDO UTILITIES COMMISSION 0950137 27 1 55821 26 NOX 63.585912095 ORLANDO UTILITIES COMMISSION 0950137 27 1 55821 26 SO2 1.425312095 ORLANDO UTILITIES COMMISSION 0950137 27 2 55821 26 NOX 0.030112095 ORLANDO UTILITIES COMMISSION 0950137 27 2 55821 26 SO2 0.040712095 WALT DISNEY WORLD COMPANY 0950111 88 1 7254 32432 NOX 46.654012095 WALT DISNEY WORLD COMPANY 0950111 88 1 7254 32432 SO2 0.169012095 WALT DISNEY WORLD COMPANY 0950111 88 2 7254 32432 NOX 0.816012095 WALT DISNEY WORLD COMPANY 0950111 88 2 7254 32432 SO2 0.169012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 10 1 8049 **10 NOX 36.604012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 10 1 8049 **10 SO2 0.822012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 11 1 8049 **11 NOX 14.856012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 11 1 8049 **11 SO2 16.049012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 18 2 8049 **12 NOX 22.847012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 18 2 8049 **12 SO2 0.662012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 19 2 8049 **13 NOX 22.842012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 19 2 8049 **13 SO2 0.652012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 21 2 8049 **14 NOX 27.089012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 21 2 8049 **14 SO2 0.860012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 7 1 8049 **7 NOX 39.619012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 7 1 8049 **7 SO2 0.805012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 8 1 8049 **8 NOX 42.024012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 8 1 8049 **8 SO2 0.771012097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 9 1 8049 **9 NOX 46.3020Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201256AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12097 FLORIDA POWER CORPORATION D/B/APROGRESS 0970014 9 1 8049 **9 SO2 0.822012097 KISSIMMEE UTILITY AUTHORITY 0970043 1 1 7238 **1 NOX 2.551012097 KISSIMMEE UTILITY AUTHORITY 0970043 1 1 7238 **1 SO2 0.018012097 KISSIMMEE UTILITY AUTHORITY 0970043 2 1 7238 2 NOX 35.842012097 KISSIMMEE UTILITY AUTHORITY 0970043 2 1 7238 2 SO2 0.637012097 KISSIMMEE UTILITY AUTHORITY 0970043 3 1 7238 3 NOX 48.746012097 KISSIMMEE UTILITY AUTHORITY 0970043 3 1 7238 3 SO2 2.666012097 RELIANT ENERGY FLORIDA, LLC0970071 1 1 55192 OSC1 NOX 23.577012097 RELIANT ENERGY FLORIDA, LLC 0970071 1 1 55192 OSC1 SO2 0.508012097 RELIANT ENERGY FLORIDA, LLC0970071 2 1 55192 OSC2 NOX 20.982012097 RELIANT ENERGY FLORIDA, LLC 0970071 2 1 55192 OSC2 SO2 0.443012097 RELIANT ENERGY FLORIDA, LLC0970071 3 1 55192 OSC3 NOX 1.959412097 RELIANT ENERGY FLORIDA, LLC 0970071 3 1 55192 OSC3 SO2 0.013712097 RELIANT ENERGY FLORIDA, LLC0970071 3 2 55192 OSC3 NOX 1.439612097 RELIANT ENERGY FLORIDA, LLC 0970071 3 2 55192 OSC3 SO2 0.402312099 CITY OF LAKE WORTH UTILITIES 0990045 9 1 673 S-3 NOX 9.185012099 CITY OF LAKE WORTH UTILITIES 0990045 9 1 673 S-3 SO2 0.021012099 FLORIDA POWER & LIGHT (PRV) 0990042 3 1 619 PRV3 NOX 205.235412099 FLORIDA POWER & LIGHT (PRV) 0990042 3 1 619 PRV3 SO2 0.584812099 FLORIDA POWER & LIGHT (PRV) 0990042 3 3 619 PRV3 NOX 1,134.597412099 FLORIDA POWER & LIGHT (PRV) 0990042 3 3 619 PRV3 SO2 2,783.245112099 FLORIDA POWER & LIGHT (PRV) 0990042 3 7 619 PRV3 NOX 0.052212099 FLORIDA POWER & LIGHT (PRV) 0990042 3 7 619 PRV3 SO2 0.001112099 FLORIDA POWER & LIGHT (PRV) 0990042 4 1 619 PRV4 NOX 811.024212099 FLORIDA POWER & LIGHT (PRV) 0990042 4 1 619 PRV4 SO2 1.892812099 FLORIDA POWER & LIGHT (PRV) 0990042 4 3 619 PRV4 NOX 1,442.817312099 FLORIDA POWER & LIGHT (PRV) 0990042 4 3 619 PRV4 SO2 2,898.827912099 FLORIDA POWER & LIGHT (PRV) 0990042 4 7 619 PRV4 NOX 0.078512099 FLORIDA POWER & LIGHT (PRV) 0990042 4 7 619 PRV4 SO2 0.001312101 FLORIDA POWER CORPDBAPROGRESS ENERGY FL 1010017 1 3 8048 1 NOX 3,501.590012101 FLORIDA POWER CORPDBAPROGRESS ENERGYFL 1010017 1 3 8048 1 SO2 13,162.815012101 FLORIDA POWER CORPDBAPROGRESS ENERGY FL 1010017 2 2 8048 2 NOX 3,075.462012101 FLORIDA POWER CORPDBAPROGRESS ENERGYFL 1010017 2 2 8048 2 SO2 13,875.6460Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201257AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 1 1 55414 GT101 NOX 8.786412101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 1 1 55414 GT101 SO2 2.306212101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 1 2 55414 GT101 NOX 54.757612101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 1 2 55414 GT101 SO2 1.162812101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 2 1 55414 GT201 NOX 8.169212101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 2 1 55414 GT201 SO2 2.239612101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 2 2 55414 GT201 NOX 51.803812101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 2 2 55414 GT201 SO2 1.034412101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 3 1 55414 GT301 NOX 10.911612101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 3 1 55414 GT301 SO2 3.004512101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 3 2 55414 GT301 NOX 54.237412101 SHADY HILLS POWER COMPANY, L.L.C. 1010373 3 2 55414 GT301 SO2 1.176512103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 1 634 1 NOX 0.578312103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 1 634 1 SO2 4.443312103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 2 634 1 NOX 610.866712103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 2 634 1 SO2 3,345.872812103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 1 3 634 1 SO2 0.055912103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 2 634 2 NOX 459.239512103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 2 634 2 SO2 2,413.285612103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 5 634 2 NOX 0.004912103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 5 634 2 SO2 0.058112103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 6 634 2 NOX 0.020612103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 2 6 634 2 SO2 0.141212103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 1 634 3 SO2 43.956012103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 2 634 3 NOX 1,556.693012103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 2 634 3 SO2 6,619.406112103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 4 634 3 SO2 2.550512103 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1030011 3 5 634 3 SO2 0.147412105 APP, LP; APEC, LLC; CCFC 1050221 1 1 54658 1 NOX 136.818012105 APP, LP; APEC, LLC; CCFC1050221 1 1 546581 SO2 1.909012105 APP, LP; APEC, LLC; CCFC1050221 6 1 558336 NOX 27.074012105 APP, LP; APEC, LLC; CCFC1050221 6 1 558336 SO2 0.183012105 APP, LP; APEC, LLC; CCFC 1050221 8 1 55412 CT1 NOX 147.8600Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201258AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12105 APP, LP; APEC, LLC; CCFC 1050221 8 1 55412 CT1 SO2 2.442012105 APP, LP; APEC, LLC; CCFC 1050221 9 1 55412 CT2 NOX 143.753012105 APP, LP; APEC, LLC; CCFC 1050221 9 1 55412 CT2 SO2 2.625012105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050223 1 27699 1 NOX 95.018012105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050223 1 27699 1 SO2 1.945012105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 1 1 7302 1A NOX 105.966012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 1 1 7302 1A SO2 2.179012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 14 1 7302 2A NOX 62.226012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 14 1 7302 2A SO2 3.358712105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 14 2 7302 2A SO2 0.003312105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 15 1 7302 2B NOX 64.592012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 15 1 7302 2B SO2 3.067612105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 15 2 7302 2B SO2 0.004412105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 16 1 7302 3A NOX 52.257012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 16 1 7302 3A SO2 3.340612105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 16 2 7302 3A SO2 0.000412105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 17 1 7302 3B NOX 46.516012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 17 1 7302 3B SO2 1.562112105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 17 2 7302 3B SO2 1.743912105 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1050234 2 1 7302 1B NOX 109.539012105 FLORIDA POWER CORPDBAPROGRESS ENERGYFLA 1050234 2 1 7302 1B SO2 1.904012105 LAKELAND ELECTRIC 1050003 8 1 675 **8 NOX 0.033012105 LAKELAND ELECTRIC 1050003 8 1 675 **8 SO2 0.445012105 LAKELAND ELECTRIC 1050003 8 2 675 **8 NOX 41.090012105 LAKELAND ELECTRIC 1050004 1 1 676 1 NOX 50.064412105 LAKELAND ELECTRIC 1050004 1 1 676 1 SO2 0.101212105 LAKELAND ELECTRIC 1050004 1 2 676 1 NOX 32.260612105 LAKELAND ELECTRIC 1050004 1 2 676 1 SO2 233.214012105 LAKELAND ELECTRIC 1050004 1 3 676 1 NOX 0.103012105 LAKELAND ELECTRIC 1050004 1 3 676 1 SO2 0.829812105 LAKELAND ELECTRIC 1050004 28 2 676 5 NOX 97.427012105 LAKELAND ELECTRIC 1050004 28 2 676 5 SO2 2.510012105 LAKELAND ELECTRIC 1050004 5 1 676 2 NOX 66.8170Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201259AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12105 LAKELAND ELECTRIC 1050004 5 1 676 2 SO2 0.388012105 LAKELAND ELECTRIC 1050004 5 2 676 2 NOX 3.726012105 LAKELAND ELECTRIC 1050004 5 2 676 2 SO2 10.339012105 LAKELAND ELECTRIC 1050004 6 3 676 3 NOX 5,229.709112105 LAKELAND ELECTRIC 1050004 6 3 676 3 SO2 7,205.791012105 LAKELAND ELECTRIC 1050004 6 4 676 3 NOX 1.946012105 LAKELAND ELECTRIC 1050004 6 4 676 3 SO2 0.014012105 LAKELAND ELECTRIC 1050004 6 9 676 3 NOX 12.617912105 LAKELAND ELECTRIC 1050004 6 9 676 3 SO2 17.391012105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 1 1 54365 1 NOX 41.176012105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 1 1 54365 1 SO2 0.503012105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 2 1 54365 2 NOX 37.909012105 ORANGE COGENERATION LIMITED PARTNERSHIP 1050231 2 1 54365 2 SO2 0.462012105 POLK POWER PARTNERS, L.P.1050217 1 1 54426 1 NOX 66.706012105 POLK POWER PARTNERS, L.P.1050217 1 1 54426 1 SO2 1.084012105 TAMPA ELECTRIC COMPANY 1050233 1 2 7242 **1 NOX 396.447012105 TAMPA ELECTRIC COMPANY 1050233 1 2 7242 **1 SO2 1,069.837012105 TAMPA ELECTRIC COMPANY 1050233 10 2 7242 **3 NOX 16.673012105 TAMPA ELECTRIC COMPANY 1050233 10 2 7242 **3 SO2 0.521012105 TAMPA ELECTRIC COMPANY 1050233 13 1 7242 **4 NOX 13.307012105 TAMPA ELECTRIC COMPANY 1050233 13 1 7242 **4 SO2 0.256012105 TAMPA ELECTRIC COMPANY 1050233 14 1 7242 **5 NOX 11.923012105 TAMPA ELECTRIC COMPANY 1050233 14 1 7242 **5 SO2 0.220012105 TAMPA ELECTRIC COMPANY 1050233 9 1 7242 **2 NOX 12.659012105 TAMPA ELECTRIC COMPANY 1050233 9 1 7242 **2 SO2 0.309012107 FLORIDA POWER & LIGHT (PPN) 1070014 3 1 6246 HRSG11 NOX 421.684112107 FLORIDA POWER & LIGHT (PPN) 1070014 3 1 6246 HRSG11 SO2 0.641312107 FLORIDA POWER & LIGHT (PPN) 1070014 3 2 6246 HRSG11 NOX 0.128912107 FLORIDA POWER & LIGHT (PPN) 1070014 3 2 6246 HRSG11 SO2 0.116712107 FLORIDA POWER & LIGHT (PPN) 1070014 4 1 6246 HRSG12 NOX 468.859112107 FLORIDA POWER & LIGHT (PPN) 1070014 4 1 6246 HRSG12 SO2 0.661812107 FLORIDA POWER & LIGHT (PPN) 1070014 4 2 6246 HRSG12 NOX 0.141912107 FLORIDA POWER & LIGHT (PPN) 1070014 4 2 6246 HRSG12 SO2 0.1192Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201260AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12107 FLORIDA POWER & LIGHT (PPN) 1070014 5 1 6246 HRSG21 NOX 348.248412107 FLORIDA POWER & LIGHT (PPN) 1070014 5 1 6246 HRSG21 SO2 0.540912107 FLORIDA POWER & LIGHT (PPN) 1070014 5 2 6246 HRSG21 NOX 0.072612107 FLORIDA POWER & LIGHT (PPN) 1070014 5 2 6246 HRSG21 SO2 0.067112107 FLORIDA POWER & LIGHT (PPN) 1070014 6 1 6246 HRSG22 NOX 354.333312107 FLORIDA POWER & LIGHT (PPN) 1070014 6 1 6246 HRSG22 SO2 0.555812107 FLORIDA POWER & LIGHT (PPN) 1070014 6 2 6246 HRSG22 NOX 0.082712107 FLORIDA POWER & LIGHT (PPN) 1070014 6 2 6246 HRSG22 SO2 0.077212107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 1 1 136 1 NOX 21.226512107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 1 136 1 SO2 25.507112107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 1 2 136 1 NOX 8,013.601612107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 1 2 136 1 SO2 9,629.657912107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 1 3 136 1 NOX 392.904912107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 1 3 136 1 SO2 472.140012107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 2 1 136 2 NOX 24.185112107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 1 136 2 SO2 25.529512107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 2 2 136 2 NOX 9,001.978312107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 2 2 136 2 SO2 9,502.365212107 SEMINOLE ELECTRIC COOPERATIVE,INC. 1070025 2 3 136 2 NOX 644.192712107 SEMINOLE ELECTRIC COOPERATIVE, INC. 1070025 2 3 136 2 SO2 680.001212111 FT PIERCE UTILITIES AUTHORITY 1110003 7 1 658 7 NOX 3.072012111 FT PIERCE UTILITIES AUTHORITY 1110003 7 1 658 7 SO2 0.015012111 FT PIERCE UTILITIES AUTHORITY 1110003 8 1 658 8 NOX 3.948012111 FT PIERCE UTILITIES AUTHORITY 1110003 8 1 658 8 SO2 0.027012113 SANTA ROSA ENERGY CENTER, LLC 1130168 1 1 55242 CT-1 NOX 2.574012113 SANTA ROSA ENERGY CENTER, LLC 1130168 1 1 55242 CT-1 SO2 0.013012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 1 3 638 1 NOX 94.405012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 1 3 638 1 SO2 161.700012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 2 3 638 2 NOX 138.813012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 2 3 638 2 SO2 497.796012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 3 3 638 3 NOX 206.116012121 FLORIDA POWER CORPDBAPROGRESS ENERGY FLA 1210003 3 3 638 3 SO2 219.874012127 FLORIDA POWER & LIGHT (PSN) 1270009 1 2 620 PSN3 NOX 26.2474Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201261AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12127 FLORIDA POWER & LIGHT (PSN) 1270009 1 2 620 PSN3 SO2 0.045012127 FLORIDA POWER & LIGHT (PSN) 1270009 1 3 620 PSN3 NOX 102.441212127 FLORIDA POWER & LIGHT (PSN) 1270009 1 3 620 PSN3 SO2 301.320912127 FLORIDA POWER & LIGHT (PSN) 1270009 1 5 620 PSN3 NOX 0.004412127 FLORIDA POWER & LIGHT (PSN) 1270009 1 5 620 PSN3 SO2 0.000112127 FLORIDA POWER & LIGHT (PSN) 1270009 10 1 620 SNCT4A NOX 162.960012127 FLORIDA POWER & LIGHT (PSN) 1270009 10 1 620 SNCT4A SO2 3.287012127 FLORIDA POWER & LIGHT (PSN) 1270009 11 1 620 SNCT4B NOX 164.969012127 FLORIDA POWER & LIGHT (PSN) 1270009 11 1 620 SNCT4B SO2 3.272012127 FLORIDA POWER & LIGHT (PSN) 1270009 12 1 620 SNCT4C NOX 165.927012127 FLORIDA POWER & LIGHT (PSN) 1270009 12 1 620 SNCT4C SO2 3.312012127 FLORIDA POWER & LIGHT (PSN) 1270009 13 1 620 SNCT4D NOX 164.230012127 FLORIDA POWER & LIGHT (PSN) 1270009 13 1 620 SNCT4D SO2 3.214012127 FLORIDA POWER & LIGHT (PSN) 1270009 14 1 620 SNCT5A NOX 159.921012127 FLORIDA POWER & LIGHT (PSN) 1270009 14 1 620 SNCT5A SO2 3.294012127 FLORIDA POWER & LIGHT (PSN) 1270009 15 1 620 SNCT5B NOX 169.291012127 FLORIDA POWER & LIGHT (PSN) 1270009 15 1 620 SNCT5B SO2 3.352012127 FLORIDA POWER & LIGHT (PSN) 1270009 16 1 620 SNCT5C NOX 176.756012127 FLORIDA POWER & LIGHT (PSN) 1270009 16 1 620 SNCT5C SO2 3.515012127 FLORIDA POWER & LIGHT (PSN) 1270009 17 1 620 SNCT5D NOX 147.268012127 FLORIDA POWER & LIGHT (PSN) 1270009 17 1 620 SNCT5D SO2 2.987012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 15 1 6046 **7 NOX 25.011012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 15 1 6046 **7 SO2 7.871012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 16 1 6046 **8 NOX 24.743012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 16 1 6046 **8 SO2 7.889012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 17 1 6046 **9 NOX 21.178012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 17 1 6046 **9 SO2 7.258012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 18 1 6046 **10 NOX 12.892012127 FLORIDA POWER CORPORATION D/B/APROGRESS 1270028 18 1 6046 **10 SO2 27.775012129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 14 2 689 8 NOX 0.009512129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 14 2 689 8 SO2 0.697612129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 14 3 689 8 NOX 155.989512129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 14 3 689 8 SO2 3.3884Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201262AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions12129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 7 1 689 7 NOX 65.700012129 TALLAHASSEE CITY PURDOM GENERATINGSTA. 1290001 7 1 689 7 SO2 0.16501.9.8.4 GeorgiaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions13015 Ga Power Company - Plant Bowen 01500011 S1 1 703 1BLR NOX 3,551.565013015 Ga Power Company - Plant Bowen 01500011 S2 1 703 2BLR NOX 4,843.621013015 Ga Power Company - Plant Bowen 01500011 S3 1 703 3BLR NOX 5,702.325013015 Ga Power Company - Plant Bowen 01500011 S4 1 703 4BLR NOX 4,357.206013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 1 NOX 1,149.006013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 2 NOX 1,033.948013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 2 SO2 1,878.778013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 3 NOX 2,049.303013051 Ga Power Company - Plant Kraft 05100006 CS1 1 733 3 SO2 3,622.665013051 Ga Power Company - Plant Kraft 05100006 CS1 2 733 4 NOX 80.570013051 Ga Power Company - Plant Kraft 05100006 CS1 2 733 4 SO2 124.171013067 Ga Power Company - Plant McDonough/Atkinson 06700003 ST1M 1 710 MB1 NOX 2,257.208013067 Ga Power Company - Plant McDonough/Atkinson 06700003 ST1M 1 710 MB1 SO2 13,983.341013067 Ga Power Company - Plant McDonough/Atkinson 06700003 ST1M 1 710 MB2 SO2 14,554.921013077 Ga Power Company - Plant Yates 07700001 ST1 1 728 Y2BR NOX 1,528.460013077 Ga Power Company - Plant Yates 07700001 ST1A 1 728 Y1BR NOX 1,426.715013077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y4BR NOX 1,612.004013077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y4BR SO2 9,213.658013077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y5BR NOX 1,432.379013077 Ga Power Company - Plant Yates 07700001 ST2 1 728 Y5BR SO2 8,636.783013095 Ga Power Company - Plant Mitchell 09500002 ST3 1 727 3 NOX 1,985.073013103 Effingham County Power, LLC 10300012 S2 CTG2 55406 2 NOX 42.484013103 Ga Power Co Plt Mcintosh 10300003 S1 1 6124 1 NOX 2,092.398013115 Ga Power Company - Plant Hammond 11500003 ST2 1 708 4 NOX 4,176.184013127 Ga Power Company - Plant McManus 12700004 ST01 2 715 1 NOX 18.480013127 Ga Power Company - Plant McManus 12700004 ST01 2 715 2 NOX 27.513013149 Ga Power Company - Plant Wansley 14900001 ST01 1 6052 1 NOX 5,831.988013149 Ga Power Company - Plant Wansley 14900001 ST02 1 6052 2 NOX 8,026.3610Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201263AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions13149 Ga Power Company - Plant Wansley 14900001 ST04 1 6052 6A NOX 37.954013149 Ga Power Company - Plant Wansley 14900001 ST05 1 6052 6B NOX 34.908013149 Ga Power Company - Plant Wansley 14900001 ST06 1 6052 7A NOX 39.084013149 Ga Power Company - Plant Wansley 14900001 ST07 1 6052 7B NOX 40.719013207 Ga Power Company - Plant Scherer20700008 ST2 1 6257 2 NOX 4,670.316013207 Ga Power Company - Plant Scherer20700008 ST4 1 6257 4 NOX 4,672.102013237 Ga Power Company - Plant Branch 23700008 ST1 1 709 1 NOX 4,161.140013237 Ga Power Company - Plant Branch 23700008 ST1 1 709 1 SO2 17,707.594013237 Ga Power Company - Plant Branch 23700008 ST1 1 709 2 NOX 4,561.670013237 Ga Power Company - Plant Branch 23700008 ST1 1 709 2 SO2 19,404.389013237 Ga Power Company - Plant Branch 23700008 ST2 1 709 3 SO2 28,422.559013237 Ga Power Company - Plant Branch 23700008 ST2 1 709 4 NOX 6,559.262013237 Ga Power Company - Plant Branch 23700008 ST2 1 709 4 SO2 32,828.195013297 DOYLE GENERATING FACILITY29700041 41 1 55244 CTG-5 NOX 6.43701.9.8.5 KentuckyCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions21049 East Ky Power Coop 00003 001 1 1385 1 NOX 473.785021049 East Ky Power Coop 00003 001 1 1385 1 SO2 1,097.579021049 East Ky Power Coop 00003 002 1 1385 2 NOX 482.674021049 East Ky Power Coop 00003 002 1 1385 2 SO2 1,094.589021049 East Ky Power Coop 00003 003 1 1385 3 SO2 2,563.177021127 Kentucky Power Co-Big SandyPlant 00003 01 1 1353 BSU1 NOX 3,393.826021127 Kentucky Power Co-Big SandyPlant 00003 01 1 1353 BSU1 SO2 10,636.324221127 Kentucky Power Co-Big SandyPlant 00003 01 2 1353 BSU1 NOX 0.908021127 Kentucky Power Co-Big Sandy Plant 00003 01 2 1353 BSU1 SO2 0.500821127 Kentucky Power Co-Big SandyPlant 00003 02 1 1353 BSU2 NOX 11,585.034121127 Kentucky Power Co-Big SandyPlant 00003 02 1 1353 BSU2 SO2 36,112.387421127 Kentucky Power Co-Big SandyPlant 00003 02 2 1353 BSU2 NOX 3.136921127 Kentucky Power Co-Big Sandy Plant 00003 02 2 1353 BSU2 SO2 1.725621167 KY Utilities Co - Brown Station 00001 023-29 10 1355 9 NOX 3.787021167 KY Utilities Co - Brown Station 00001 023-29 11 1355 9 NOX 6.196021167 KY Utilities Co - Brown Station 00001 023-29 12 1355 10 NOX 6.2687Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201264AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions21167 KY Utilities Co - Brown Station 00001 023-29 13 1355 10 NOX 0.783321167 KY Utilities Co - Brown Station 00001 023-29 14 1355 11 NOX 4.064021167 KY Utilities Co - Brown Station 00001 023-29 2 1355 5 NOX 10.923121167 KY Utilities Co - Brown Station 00001 023-29 3 1355 5 NOX 0.011921167 KY Utilities Co - Brown Station 00001 023-29 4 1355 6 NOX 19.894021167 KY Utilities Co - Brown Station 00001 023-29 5 1355 6 NOX 0.061021167 KY Utilities Co - Brown Station 00001 023-29 6 1355 7 NOX 71.180721167 KY Utilities Co - Brown Station 00001 023-29 7 1355 7 NOX 0.939321167 KY Utilities Co - Brown Station 00001 023-29 8 1355 8 NOX 19.346221167 KY Utilities Co - Brown Station 00001 023-29 9 1355 8 NOX 0.208821177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 1 1378 1 SO2 11,733.637721177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 2 1378 1 SO2 2.961321177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 3 1378 1 SO2 460.585621177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 4 1378 1 SO2 0.062021177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU01 5 1378 1 SO2 0.077421177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 1 1378 2 SO2 17,824.133121177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 2 1378 2 SO2 4.498121177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 3 1378 2 SO2 699.658921177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU02 4 1378 2 SO2 0.107821177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 1 1378 3 SO2 3,761.212121177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 2 1378 3 SO2 0.949221177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 3 1378 3 SO2 147.640521177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 4 1378 3 SO2 0.051921177 Tennessee Valley Authority - Paradise Fossil Plant 00006 EU03 5 1378 3 SO2 0.024321183 Western KY Energy Corp - Wilson Station 00069 EU-01 1 6823 W1 NOX 6,598.158021199 East Ky Power Coop 00005 001 1 1384 1 NOX 765.925921199 East Ky Power Coop 00005 001 1 1384 1 SO2 3,495.665921199 East Ky Power Coop 00005 001 2 1384 1 NOX 777.203121199 East Ky Power Coop 00005 001 2 1384 1 SO2 3,242.441121199 East Ky Power Coop 00005 002 1 1384 2 NOX 1,973.138721199 East Ky Power Coop 00005 002 1 1384 2 SO2 8,877.374721199 East Ky Power Coop 00005 002 2 1384 2 NOX 1,022.560321199 East Ky Power Coop 00005 002 2 1384 2 SO2 4,205.4283Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201265AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions21233 Western KY Energy Corp - Green Station 00052 EU01G1 1 6639 G1 NOX 2,650.902021233 Western KY Energy Corp - Green Station 00052 EU02G2 1 6639 G2 NOX 2,906.247021233 Western KY Energy Corp - Reid HMP&LStation 2 00001 EU01 1 1383 R1 SO2 6,735.594021233 Western KY Energy Corp - Reid HMP&LStation 2 00001 EU02 1 1382 H1 SO2 1,786.966021233 Western KY Energy Corp - Reid HMP&LStation 2 00001 EU03 1 1382 H2 SO2 1,901.45701.9.8.6 Kentucky – Jefferson CountyNo issues identified.1.9.8.7 MississippiNo changes requested by State.1.9.8.8 North CarolinaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions37035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 1 S-1 2727 1 NOX 2,289.439037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 1 S-1 2727 1 SO2 7,552.402037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 2 S-2 2727 2 NOX 2,677.070037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 2 S-2 2727 2 SO2 7,099.639037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 3 S-3 2727 3 NOX 4,963.180037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 3 S-3 2727 3 SO2 7,617.807037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 4 S-4 2727 4 NOX 4,731.177037035 Duke Energy Carolinas, LLC - Marshall Steam Station 3703500073 4 S-4 2727 4 SO2 1,872.107037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 10S-8 2732 10 NOX 665.658037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 10 S-8 2732 10 SO2 4,858.990037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 7S-5 2732 7 NOX 489.186037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 7 S-5 2732 7 SO2 3,329.180037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 8S-6 2732 8 NOX 472.693037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 8 S-6 2732 8 SO2 2,908.216037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 9S-7 2732 9 NOX 602.427037071 Duke Energy Carolinas, LLC - Riverbend Steam Station 3707100040 9 S-7 2732 9 SO2 4,810.388037071 Duke Power Company, LLC - Allen SteamStation 3707100039 ES1 S-1 2718 1 NOX 853.155037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES1 S-1 2718 1 SO2 7,260.767037071 Duke Power Company, LLC - Allen SteamStation 3707100039 ES2 S-2 2718 2 NOX 821.529037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES2 S-2 2718 2 SO2 7,082.632037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES3 S-32718 3 NOX 1,426.5220Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201266AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions37071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES3 S-3 2718 3 SO2 12,391.614037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES4 S-42718 4 NOX 1,499.587037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES4 S-4 2718 4 SO2 11,576.642037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES5 S-52718 5 NOX 1,836.973037071 Duke Power Company, LLC - Allen Steam Station 3707100039 ES5 S-5 2718 5 SO2 12,238.267037071 Duke Power Company, LLC - Allen SteamStation 3707100039 ES6 S-7 2718 1 NOX 0.020037071 Duke Power Company, LLC - Allen SteamStation 3707100039 ES6 S-7 2718 1 SO2 0.050037129 Carolina Power_Light Company d/b/a ProgressEnergy Caro 3712900036 UNIT1 S-1 2713 1 NOX 980.312037129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT 1S-1 2713 1 SO2 3,458.972037129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT 1S-1 2713 2 NOX 1,212.738037129 Carolina Power_Light Company d/b/a Progress Energy Caro 3712900036 UNIT 1S-1 2713 2 SO2 4,241.526037145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1A NOX 723.611037145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1A SO2 12,168.034037145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1B NOX 639.711037145 Progress Energy - Mayo Facility 3714500045 ES1 S-1 6250 1B SO2 10,642.445037145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3A NOX 1,208.967037145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3A SO2 13,704.153037145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3B NOX 1,162.753037145 Progress Energy - Roxboro Plant 3714500029 EP3 S-3 2712 3B SO2 13,152.244037145 Progress Energy - Roxboro Plant3714500029 EP4 S-4 2712 4B NOX 0.692437145 Progress Energy - Roxboro Plant3714500029 EP4 S-4 2712 4B SO2 6.753337145 Progress Energy - Roxboro Plant3714500029 EP4 S-999 2712 4B NOX 720.844637145 Progress Energy - Roxboro Plant 3714500029 EP4 S-999 2712 4B SO2 7,050.866737145 Progress Energy - Roxboro Plant3714500029 EP4a S-14 2712 4A NOX 804.974037145 Progress Energy - Roxboro Plant 3714500029 EP4a S-14 2712 4A SO2 7,905.259037157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP2 S-2 2723 2 SO2 2,040.133237157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3A S-3 2723 3 NOX 445.532237157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3A S-3 2723 3 SO2 1,925.926637157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3B S-4 2723 3 NOX 237.848837157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP3B S-4 2723 3 SO2 2,017.656437157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP5 S-6 2723 1 NOX 2.224037157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP6 S-7 2723 1 NOX 0.992837157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP6 S-7 2723 1 SO2 0.2799Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201267AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions37157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP9 S-10 2723 1 NOX 0.089437157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 EP9 S-10 2723 1 SO2 0.289937157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 F-1 S-14 2723 2 NOX 2.202337157 Duke Energy Carolinas, LLC - Dan River Steam Station 3715700015 F-1 S-14 2723 2 SO2 0.245837157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-11 55116 CT5 NOX 3.071637157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-11 55116 CT5 SO2 0.209037157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-999 55116 CT5 NOX 3.071637157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP1 S-999 55116 CT5 SO2 0.209037157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-12 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-12 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-999a 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP2 S-999a 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-13 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-13 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-999b 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP3 S-999b 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-14 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-14 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-999c 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP4 S-999c 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-15 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-15 55116 CT5 SO2 0.052337157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-999d 55116 CT5 NOX 1.661437157 Duke Energy Carolinas, LLC - Rockingham Co. Comb. Turbine 3715700156 EP5 S-999d 55116 CT5 SO2 0.052337159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES5 S-2 2720 5 NOX 152.109037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES5 S-2 2720 5 SO2 652.741037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES6 S-3 2720 6 NOX 148.381037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES6 S-3 2720 6 SO2 625.414037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 7 NOX 221.838037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 7 SO2 794.919037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 8 NOX 581.569037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 8 SO2 4,265.884037159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 9 NOX 541.7360Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201268AMECCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions37159 Duke Power Company, LLC - Buck Steam Station 3715900004 ES9 S-6 2720 9 SO2 3,921.568037159 Duke Power Company, LLC - Buck SteamStation 3715900004 ES9CS-9 2720 5 NOX 0.518037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 1S-1 2721 1 NOX 229.690237161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 1 S-1 2721 1 SO2 715.472937161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 2S-2 2721 2 NOX 279.299037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 2 S-2 2721 2 SO2 996.333037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 3S-3 2721 3 NOX 478.600037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 3 S-3 2721 3 SO2 1,586.277037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 4S-4 2721 4 NOX 512.311037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 4 S-4 2721 4 SO2 1,632.625037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5S-5 2721 1 NOX 3.593237161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 1 SO2 11.803237161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5S-5 2721 5 NOX 995.811037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 5 S-5 2721 5 SO2 22,623.225037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 Misc.S-10 2721 2 NOX 0.060037161 Duke Energy Carolinas, LLC - Cliffside Steam Station 3716100028 Misc.S-10 2721 2 SO2 0.010037169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP1S-1 8042 1 NOX 1,300.686037169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP1S-1 8042 1 SO2 38,355.698037169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP2S-2 8042 2 NOX 2,119.973237169 Duke Energy Carolinas, LLC - Belews Creek Steam Station 3716900004 EP2S-2 8042 2 SO2 48,031.770037169 Duke Energy Carolinas, LLC - Belews CreekSteam Station 3716900004 F-1 S-12 8042 2 NOX 0.159837169 Duke Energy Carolinas, LLC - Belews CreekSteam Station 3716900004 F-1 S-12 8042 2 SO2 0.03001.9.8.9 North Carolina – Buncombe CountyNo affected facilities in the county.1.9.8.10 North Carolina – Forsyth CountyNo affected facilities in the county.1.9.8.11 North Carolina – Mecklenburg CountyNo affected facilities in the county.Development of Point Source Emission Inventory for2007 Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 18, 201269AMEC1.9.8.12 South CarolinaCountyFIPSFacilityNameFacilityIDPointIDProcessIDorisidblrid6PollutantCodeEmissions45021 BROAD RIVER ENERGY LLC 0600-0076 1 1 55166 CT-1 NOX 37.407045021 BROAD RIVER ENERGY LLC 0600-0076 1 1 55166 CT-1 SO2 0.613045021 BROAD RIVER ENERGY LLC 0600-0076 2 3 55166 CT-2 NOX 27.937045021 BROAD RIVER ENERGY LLC 0600-0076 2 3 55166 CT-2 SO2 0.421045021 BROAD RIVER ENERGY LLC 0600-0076 3 5 55166 CT-3 NOX 43.522045021 BROAD RIVER ENERGY LLC 0600-0076 3 5 55166 CT-3 SO2 0.659045021 CHEROKEE COGENERATION 0600-0060 1 1 55043 CCCP1 NOX 26.817045021 CHEROKEE COGENERATION 0600-0060 1 1 55043 CCCP1 SO2 0.554045053 SCE&G JASPER 1360-00261 1 55927 CT01 NOX 30.464045053 SCE&G JASPER 1360-00261 1 55927 CT01 SO2 1.571045053 SCE&G JASPER 1360-00262 1 55927 CT02 NOX 37.633045053 SCE&G JASPER 1360-00262 1 55927 CT02 SO2 2.238045053 SCE&G JASPER 1360-00263 1 55927 CT03 NOX 33.186045053 SCE&G JASPER 1360-00263 1 55927 CT03 SO2 1.60401.9.8.13 TennesseeNo 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 VirginiaNo issues identified.1.9.8.19 West VirginiaNo changes requested by State as a result of the CEMS review. West Virginiadid submit revised records for 70 emission releasepoints forPM10-PRI and PM25-PRI. Those records were inserted into the database at the time that the otherCEM related changes were made.

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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 thos e records that were replaced

based on the quality assurance of latitude and l ongitude 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 t he 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 mo st of the point source CO emissions (about

81 percent) come from nonEGUs that are not re quired to report emissions to CAMD.

Exhibit 9 shows that 

# NH 3 

# emissions in the SEMAP region ha ve remained about the same in 2002

and 2007, although 

# NH 3 

# emissions increased substantially in some States while decreasing in

others. Exhibit 10 shows that most of the point source 

# NH 3 

# emissions (about 90 percent) come from

nonEGUs that are not required to report emissions to CAMD.

Exhibit 11 shows that NOx emi ssions have decreased by about 26 per cent between 2002 and 2007.

All States showed a decreas e in NOx emissions from point source s. 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 t he NOx emissions result from nonE GUs 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, al though PM10-PRI emissions incr eased substantially in some

States while decreasing in others. Exhibit 14 shows that about 46 per cent 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, al though PM25-PRI emissions incr eased substantially in some

States while decreasing in others. Exhibit 16 shows that about 45 per cent 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 ha ve decreased by about 15 percent

between 2002 and 2007. All States ex cept 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 in ventory; 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 spec ific economic growth or

contraction between 2002 and 2007 ; 8) facility or emission unit cl osures; 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 

# NH 3 

# 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 

# NH 3 

# 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 wi th the 8 NIF tables:

SEMAP 2007 Point NIF V_1_10a.zip

Annual point source files in SMOKE ORL form at are being prepared under SEMAP’s emission

modeling contract.

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

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79 AMEC 

# 1.12 REFERENCES

Dutch 2005. Steven Dutch, Natural and Applied Sciences, University of Wisconsin - Green Bay.

Converting UTM to Latitude and Longitude (Or Vice Versa) . Downloaded March 2009, last

updated 19 April 2005. http://www.uwgb.edu/dutchs/Us efulData/UTMFormulas.HTM

EPA 2004. U.S. Environment al Protection Agency. Basic Format and Content Checker. Version

Date 052604. 

# Software no longer available on EPA web site.

EPA 2005. U.S. Environment al Protection Agency. Emissions Inventory Guidance for

Implementation of Ozone and Pa rticulate 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/eiguidf inal_nov2005.pdf

EPA 2006a. U.S. Environment al 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. Environment al Protection Agency. 2002 NEI Stack Parameter Default

. ftp://ftp.epa.gov/EmisInventory/ 2002finalnei/document ation/augmentati on_point_sector/

.

EPA 2007. U.S. Environment al Protection Agency. Guidance on the Use of Models and Other

Analyses for Demonstrating Attainment of Air Quality Goals for Ozone, PM 2.5 

# , 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. Environment al 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. Environment al 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. Environment al Protection Agency. 2005 National Emissions Inventory Data &

Documentation . file name: 2005v4CAPHAP_orl_point.zip. June 2009.

ftp://ftp.epa.gov/EmisI nventory/2005v4/2005emis

MARAMA 2006. Mid-Atlantic Regi onal Air Management Association. Technical Support

Documentation for 2002 MANE-VU SIP M odeling 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 Impr ovement State and Tribal Asso ciation of the Southeast. Documentation

of the Base G 2002 Base Year, 2009, and 2018 Emission Inventories for the Visibility

Improvement State and Tribal A ssociation of the Southeast. February 2007.

http://www.vistas-sesarm.org/doc uments/VISTABF2003-20-2008.pdf

# Appendix ADevelopment of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20111-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat010070001Alabama Pigments Co001-87.12705933.226081010070001Alabama Pigments Co002-87.12705933.226081010070001Alabama Pigments Co888-87.12705933.226081010150088SOUTHERN HERITAGE CASKET COMPANY, INC.001-85.93089233.593406010430010American Proteins Inc002-86.80956733.956023010430010American Proteins Inc005-86.80956733.956023010430010American Proteins Inc006-86.80956733.956023010430010American Proteins Inc007-86.80956733.956023010430010American Proteins Inc010-86.80956733.956023010430010American Proteins Inc011-86.80956733.956023010430010American Proteins Inc888-86.80956733.95602301073010730078CLUTCH & BRAKE SPECIALTY CO., INC.002-86.78642533.51421301073010730167ERGON TERMINALLING, INC.004-87.10799333.56035901073010730339SHELBY CONCRETE, INC.001-86.81318133.36740401073010730503LAFARGE BUILDING MATERIALS, BIRMINGHAM PLANT001-86.81324733.571241010930014Glen Allen Rail Inc002-87.74853733.915734010930014Glen Allen Rail Inc888-87.74853733.915734010930023King Kutter Inc001-87.82036433.921496010950046Jackson Paving & Construction Company888-86.23292934.460514010970010ExxonMobil Production Company001-88.05220330.25394010970010ExxonMobil Production Company002-88.05220330.25394010970010ExxonMobil Production Company003-88.05220330.25394010970010ExxonMobil Production Company004-88.05220330.25394010970010ExxonMobil Production Company005-88.05220330.25394010970010ExxonMobil Production Company006-88.05220330.25394010970010ExxonMobil Production Company007-88.05220330.25394010970010ExxonMobil Production Company008-88.05220330.25394010970010ExxonMobil Production Company010-88.05220330.25394010970010ExxonMobil Production Company011-88.05220330.25394010970010ExxonMobil Production Company012-88.05220330.25394Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20112-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat010970010ExxonMobil Production Company013-88.05220330.25394010970010ExxonMobil Production Company015-88.05220330.25394010970010ExxonMobil Production Company016-88.05220330.25394010970010ExxonMobil Production Company017-88.05220330.25394010970010ExxonMobil Production Company018-88.05220330.25394010970010ExxonMobil Production Company019-88.05220330.25394010970010ExxonMobil Production Company020-88.05220330.25394010970010ExxonMobil Production Company021-88.05220330.25394010970010ExxonMobil Production Company022-88.05220330.25394010970010ExxonMobil Production Company023-88.05220330.25394010970010ExxonMobil Production Company888-88.05220330.25394010970012ExxonMobil Production Company001-88.04476430.295978010970012ExxonMobil Production Company002-88.04476430.295978010970012ExxonMobil Production Company003-88.04476430.295978010970012ExxonMobil Production Company004-88.04476430.295978010970012ExxonMobil Production Company005-88.04476430.295978010970012ExxonMobil Production Company006-88.04476430.295978010970012ExxonMobil Production Company007-88.04476430.295978010970012ExxonMobil Production Company008-88.04476430.295978010970012ExxonMobil Production Company009-88.04476430.295978010970013ExxonMobil Production Company001-88.12485330.19192010970013ExxonMobil Production Company002-88.12485330.19192010970013ExxonMobil Production Company003-88.12485330.19192010970013ExxonMobil Production Company004-88.12485330.19192010970013ExxonMobil Production Company005-88.12485330.19192010970013ExxonMobil Production Company006-88.12485330.19192010970013ExxonMobil Production Company007-88.12485330.19192010970013ExxonMobil Production Company009-88.12485330.19192010970013ExxonMobil Production Company888-88.12485330.19192010970016Shell Exploration & Production Company001-88.07732330.178614Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20113-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat010970016Shell Exploration & Production Company002-88.07732330.178614010970016Shell Exploration & Production Company004-88.07732330.178614010970016Shell Exploration & Production Company005-88.07732330.178614010970016Shell Exploration & Production Company006-88.07732330.178614010970016Shell Exploration & Production Company007-88.07732330.178614010970025ExxonMobil Production Company001-87.95254430.18879010970025ExxonMobil Production Company002-87.95254430.18879010970025ExxonMobil Production Company003-87.95254430.18879010970025ExxonMobil Production Company004-87.95254430.18879010970025ExxonMobil Production Company005-87.95254430.18879010970025ExxonMobil Production Company006-87.95254430.18879010970025ExxonMobil Production Company007-87.95254430.18879010970025ExxonMobil Production Company888-87.95254430.18879010970038Mobile Abrasives003-88.03173630.688664010970038Mobile Abrasives888-88.03173630.688664010972002Armstrong World Industries Inc001-88.0582630.66557010972002Armstrong World Industries Inc002-88.0582630.66557010972002Armstrong World Industries Inc003-88.0582630.66557010972002Armstrong World Industries Inc004-88.0582630.66557010972002Armstrong World Industries Inc005-88.0582630.66557010972002Armstrong World Industries Inc006-88.0582630.66557010972002Armstrong World Industries Inc007-88.0582630.66557010972002Armstrong World Industries Inc008-88.0582630.66557010972002Armstrong World Industries Inc009-88.0582630.66557010972002Armstrong World Industries Inc010-88.0582630.66557010972002Armstrong World Industries Inc011-88.0582630.66557010972002Armstrong World Industries Inc013-88.0582630.66557010972002Armstrong World Industries Inc014-88.0582630.66557010974019MoBay Storage Hub, Inc001-88.22553530.253211010974019MoBay Storage Hub, Inc002-88.22553530.253211Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20114-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat010974019MoBay Storage Hub, Inc003-88.22553530.253211010976002Bender Shipbuilding & Repair Co Inc888-88.043630.684538010976007Alabama Shipyards Inc001-88.03259430.67713501099S011Owens Lumber Company001-86.98158631.795439011130018Boral Bricks001-84.99828732.458431011130018Boral Bricks002-84.99828732.458431011130018Boral Bricks003-84.99828732.458431011130018Boral Bricks005-84.99828732.458431011130018Boral Bricks006-84.99828732.458431011130018Boral Bricks007-84.99828732.458431011130018Boral Bricks888-84.99828732.458431011170005Alabama Power Company001-86.45989733.242746011170005Alabama Power Company002-86.4575833.244561011170005Alabama Power Company004-86.4575833.244561011170005Alabama Power Company888-86.45989733.242746011230015Stone's Throw Landfill888-85.83157932.511095011270015S&M Paving Co.001-87.60950433.958754120090090051NASA69-80.6518928.529149120310310010BAPTIST MEDICAL CENTER14-81.66374630.31471120310310213U S NAVAL STATION MAYPORT33-81.40639630.390052120310310213U S NAVAL STATION MAYPORT34-81.41753930.389417120310310213U S NAVAL STATION MAYPORT37-81.41753930.389417120310310325TRANSFLO TERMINAL SERVICES, INC.1-81.72005530.326385120450450002ARIZONA CHEMICALCOMPANY, LLC13-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC15-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC16-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC17-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC5-85.30833329.818056120450450002ARIZONA CHEMICALCOMPANY, LLC6-85.30833329.818056120570570094MOSAIC FERTILIZER, LLC100-82.4072927.80519Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20115-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat120570570252CEMEX2-82.43257427.901451120570570252CEMEX4-82.43257427.901451120690694822MIDDLESEX ASPHALT, L.L.C.2-81.90384828.832607120990990350SOUTH FLORIDA WATER MANAGEMENT DISTRICT1-80.44577826.472064121031030011FLORIDA POWER CORPDBAPROGRESS ENERGY FLA5-82.60166727.861389121031030011FLORIDA POWER CORPDBAPROGRESS ENERGY FLA6-82.60166727.861389121031030011FLORIDA POWER CORPDBAPROGRESS ENERGY FLA7-82.60166727.861389121031030011FLORIDA POWER CORPDBAPROGRESS ENERGY FLA8-82.60166727.861389121091090022LUHRS CORPORATION1-81.32194429.879167121131130040ODOM FIBERGLASS, INCORPORATED1-87.08720430.5442811301501500011Ga Power Company - Plant BowenS1-84.919234.12561301501500011Ga Power Company - Plant BowenS2-84.919234.12561301501500011Ga Power Company - Plant BowenS3-84.919234.12561301501500011Ga Power Company - Plant BowenS4-84.919234.12561301501500011Ga Power Company - Plant BowenSCT1-84.919234.12561301501500011Ga Power Company - Plant BowenSCT2-84.919234.12561303903900003Naval Submarine BasePT01-81.5530630.80011303903900003Naval Submarine BasePT02-81.5530630.80011303903900003Naval Submarine BasePT03-81.5530630.80011303903900003Naval Submarine BasePT04-81.5530630.80011303903900003Naval Submarine BasePT05-81.5530630.80011303903900003Naval Submarine BasePT06-81.5530630.80011303903900003Naval Submarine BasePT07-81.5530630.80011303903900003Naval Submarine BasePT08-81.5530630.80011303903900003Naval Submarine BasePT09-81.5530630.80011303903900003Naval Submarine BasePT10-81.5530630.80011303903900003Naval Submarine BasePT11-81.5530630.80011303903900003Naval Submarine BasePT12-81.5530630.80011303903900003Naval Submarine BasePT13-81.5530630.80011303903900003Naval Submarine BasePT14-81.5530630.8001Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20116-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1303903900003Naval Submarine BasePT15-81.5530630.80011303903900003Naval Submarine BasePT16-81.5530630.80011304504500052Southwire Company Carrollton Utility Products PlantF722-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN11-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN12-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN13-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN15-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN16-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN17-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN18-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN2-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN3-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN4-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN5-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN6-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantFAN7-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS205-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS280-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS281-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS296-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS297-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS501-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS504-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS507-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS510-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS513-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS516-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS721-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS745-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantS760-85.06226833.566447Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20117-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1304504500052Southwire Company Carrollton Utility Products PlantS761-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS12-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS13-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS14-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS5-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS6-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS7-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS8-85.06226833.5664471304504500052Southwire Company Carrollton Utility Products PlantSCS9-85.06226833.5664471304904900004West Fraser - Folkston Lumber MillFOB1-82.011830.849371304904900004West Fraser - Folkston Lumber MillFOB2-82.011830.849371305105100076Colonial Terminals, Inc.SB01-81.11210932.0941171305105100076Colonial Terminals, Inc.SB02-81.11210932.0941171305105100076Colonial Terminals, Inc.SB03-81.11210932.0941171305105100076Colonial Terminals, Inc.SD01-81.11210932.0941171305105100076Colonial Terminals, Inc.SD02-81.11210932.0941171305105100076Colonial Terminals, Inc.SD03-81.11210932.0941171305105100076Colonial Terminals, Inc.SD04-81.11210932.0941171305105100076Colonial Terminals, Inc.SD22-81.11210932.0941171305105100076Colonial Terminals, Inc.SD91-81.11210932.0941171305105100076Colonial Terminals, Inc.SM01-81.11210932.0941171305105100076Colonial Terminals, Inc.SR21-81.11210932.0941171305105100076Colonial Terminals, Inc.SR22-81.11210932.0941171305105100076Colonial Terminals, Inc.ST01-81.11210932.0941171305105100076Colonial Terminals, Inc.ST02-81.11210932.0941171305105100076Colonial Terminals, Inc.ST03-81.11210932.0941171305105100076Colonial Terminals, Inc.ST04-81.11210932.0941171305105100076Colonial Terminals, Inc.ST05-81.11210932.0941171305105100076Colonial Terminals, Inc.ST06-81.11210932.0941171305105100076Colonial Terminals, Inc.ST12-81.11210932.094117Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20118-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1305105100076Colonial Terminals, Inc.ST13-81.11210932.0941171305105100076Colonial Terminals, Inc.SVR4-81.11210932.0941171305105100076Colonial Terminals, Inc.SVR9-81.11210932.0941171305105100148ARIZONA CHEMICAL CORP.S1-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S10-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S11-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S12-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S13-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S14-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S2-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S3-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S4-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S5-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S6-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S7-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S8-81.1226232.0908031305105100148ARIZONA CHEMICAL CORP.S9-81.1226232.0908031305105100152Savannah Resource Recovery (Montaney)ST01-81.0279132.079161305105100152Savannah Resource Recovery (Montaney)ST02-81.0279132.079161306306300059Delta Air Lines Inc - Atlanta StationFUG-84.413933.64331306306300059Delta Air Lines Inc - Atlanta StationS1-84.413933.64331306306300059Delta Air Lines Inc - Atlanta StationS2-84.413933.64331306306300059Delta Air Lines Inc - Atlanta StationS3-84.413933.64331306506500005Bway Manufacturing IncS0-82.7738131.029071306506500005Bway Manufacturing IncS1-82.7738131.029071306506500005Bway Manufacturing IncS13-82.7738131.029071306506500005Bway Manufacturing IncS15-82.7738131.029071306506500005Bway Manufacturing IncS16-82.7738131.029071306506500005Bway Manufacturing IncS2-82.7738131.029071306506500005Bway Manufacturing IncS20-82.7738131.02907Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 20119-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1306506500005Bway Manufacturing IncS3-82.7738131.029071306506500005Bway Manufacturing IncS9-82.7738131.029071306706700032Marathon Petroleum Company LLC - Powder Springs TerminalFUG-84.6304833.863021306706700032Marathon Petroleum Company LLC - Powder Springs TerminalVCS-84.6304833.863021307307300003Quebecor World Kri Inc.FUG-82.1179133.543361307307300003Quebecor World Kri Inc.S1-82.1179133.543361307307300003Quebecor World Kri Inc.S10-82.1179133.543361307307300003Quebecor World Kri Inc.S11-82.1179133.543361307307300003Quebecor World Kri Inc.S12-82.1179133.543361308108100054Norbord Georgia IncS001-83.8022231.966061308108100054Norbord Georgia IncS003-83.8022231.966061308108100054Norbord Georgia IncS004-83.8022231.966061308108100054Norbord Georgia IncS010-83.8022231.966061308108100054Norbord Georgia IncS011-83.8022231.966061308108100054Norbord Georgia IncS012-83.8022231.966061308108100054Norbord Georgia IncS013-83.8022231.966061308108100054Norbord Georgia IncS063-83.8022231.966061308908900085Magellan Terminal Holdings, L.P. - Doraville I TerminalFUG-84.26993433.915191308908900085Magellan Terminal Holdings, L.P. - Doraville I TerminalS1-84.26993433.915191308908900128Transmontaigne Terminaling IncCGLK-84.27396133.9168411308908900128Transmontaigne Terminaling IncFUG-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8501-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8502-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8504-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8505-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8506-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8507-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8509-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8510-84.27396133.9168411308908900128Transmontaigne Terminaling IncST8515-84.27396133.916841Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201110-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1308908900128Transmontaigne Terminaling IncST8516-84.27396133.9168411308908900128Transmontaigne Terminaling IncSTLOAD-84.27396133.9168411308908900128Transmontaigne Terminaling IncSTVCU-84.27396133.9168411308908900128Transmontaigne Terminaling IncSTVRU-84.27396133.9168411309509500010MillerCoors LLCF036-84.0880531.59331309509500010MillerCoors LLCS001-84.0880531.59331309509500010MillerCoors LLCS003-84.0880531.59331309509500010MillerCoors LLCS034-84.0880531.59331309909900001Georgia-Pacific Corp Cedar Springs OperationFUG-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationINSIG-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS1-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS10-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS11-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS12-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS13-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS14-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS15-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS16-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS17-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS18-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS19-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS2-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS20-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS21-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS22-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS23-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS24-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS25-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS26-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS27-85.09547431.167343Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201111-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat1309909900001Georgia-Pacific Corp Cedar Springs OperationS28-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS29-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS3-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS5-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS6-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS7-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS8-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationS9-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationVSTACK-85.09547431.1673431309909900001Georgia-Pacific Corp Cedar Springs OperationWTS-85.09547431.1673431310310300007Georgia-Pacific Consumer Products Lp (Savannah River Mill)FUG-81.2017832.331131310310300007Georgia-Pacific Consumer Products Lp (Savannah River Mill)S1-81.2017832.331131310310300007Georgia-Pacific Consumer Products Lp (Savannah River Mill)S10-81.2017832.331131310310300007Georgia-Pacific Consumer Products Lp (Savannah River Mill)S11-81.2017832.331131310310300007Georgia-Pacific Consumer Products Lp (Savannah River Mill)S12-81.2017832.331131310310300007Georgia-Pacific 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R. Chapman(01)-86.85737.90052109100026L. R. Chapman(02)-86.85737.90052109100026L. R. Chapman(03)-86.85737.90052109100026L. R. Chapman(04)-86.85737.90052109100026L. R. Chapman(05)-86.85737.90052109100026L. R. Chapman(06)-86.85737.90052109100026L. R. Chapman(07)-86.85737.90052109100026L. R. Chapman(08)-86.85737.90052109100026L. R. Chapman(09)-86.85737.90052109100026L. R. Chapman(10)-86.85737.90052109100026L. R. Chapman(11)-86.85737.90052109100026L. R. Chapman(12)-86.85737.90052109100026L. R. Chapman(13)-86.85737.90052109100026L. R. Chapman(14)-86.85737.90052109100026L. R. Chapman(15)-86.85737.90052109100026L. R. Chapman(16)-86.85737.90052109100026L. R. Chapman(17)-86.85737.90052109100026L. R. Chapman(18)-86.85737.90052109100026L. R. Chapman(19)-86.85737.90052109100026L. R. Chapman(20)-86.85737.90052109100026L. R. Chapman(21)-86.85737.90052109100026L. R. Chapman(22)-86.85737.90052109100026L. R. Chapman(23)-86.85737.90052109100026L. R. Chapman(24)-86.85737.9005Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201121-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2109100026L. R. Chapman(25)-86.85737.90052109100026L. R. Chapman(26)-86.85737.90052109100026L. R. Chapman(27)-86.85737.90052109100026L. R. Chapman(28)-86.85737.90052109100026L. R. Chapman(29)-86.85737.90052109100026L. R. Chapman(30)-86.85737.90052109100026L. R. Chapman(31)-86.85737.90052109100026L. R. Chapman(32)-86.85737.90052109100026L. R. Chapman(33)-86.85737.90052109100026L. R. Chapman(34)-86.85737.90052109100026L. R. Chapman(35)-86.85737.90052109100026L. R. Chapman(36)-86.85737.90052109100026L. R. Chapman(37)-86.85737.90052109100026L. R. Chapman(38)-86.85737.90052109100026L. R. Chapman(39)-86.85737.90052109100026L. R. Chapman(40)-86.85737.90052109100026L. R. Chapman(41)-86.85737.90052109100026L. R. Chapman(42)-86.85737.90052109100026L. R. Chapman(43)-86.85737.90052109100026L. R. Chapman(44)-86.85737.90052109100026L. R. Chapman(45)-86.85737.90052109100026L. R. Chapman(46)-86.85737.90052109100026L. R. Chapman(47)-86.85737.90052109100026L. R. Chapman(48)-86.85737.90052109100026L. R. Chapman(49)-86.85737.90052109100026L. R. Chapman(50)-86.85737.90052109100026L. R. Chapman(51)-86.85737.90052109100026L. R. Chapman(52)-86.85737.90052110100139Kentucky 5 Star Energy LLCFS01-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS02-87.5241537.6462Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201122-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2110100139Kentucky 5 Star Energy LLCFS03-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS04-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS05-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS06-87.5241537.64622110100139Kentucky 5 Star Energy LLCFS07-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV01-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV02-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV03-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV04-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV05-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV06-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV07-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV08-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV09-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV10-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV11-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV12-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV13-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV1415-87.5241537.64622110100139Kentucky 5 Star Energy LLCSV16-87.5241537.64622110100139Kentucky 5 Star Energy LLCTK1-5-87.5241537.64622110700146Hopkinsville Wood Products001-87.689437.16522110700146Hopkinsville Wood Products002-87.689437.16522110700156J-Lok CorpEP-AU--87.4873937.277492110700156J-Lok CorpEP-V-1-87.4873937.277492110700156J-Lok CorpEP-V-2-87.4873937.277492110700156J-Lok CorpEP-V-3-87.4873937.277492111700165Laser Graphic Systems001-84.62769939.0376142111700165Laser Graphic Systems002-84.62769939.0376142111700165Laser Graphic Systems003-84.62769939.037614Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201123-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2111700174BBS Tech IncEP1-84.623339.05392111700176Alstom Power IncEP1-84.630539.04522111700176Alstom Power IncEP2-84.630539.04522111900038Chesapeake Appalachia LLC - Brinkley Transmission Station001-82.944537.29452111900040Chesapeake Appalachia LLC - Lackey Transmission Station001-82.833137.46652111900041ICG Knott Co - Raven Coal Preperation PlantGroup1-82.82367337.4018752111900041ICG Knott Co - Raven Coal Preperation PlantGroup2-82.82367337.4018752111900041ICG Knott Co - Raven Coal Preperation PlantGroup3-82.82367337.4018752112100032Gatliff Coal Co - ADA Tipple 5001-83.8205636.840282112100032Gatliff Coal Co - ADA Tipple 5002-83.8205636.840282112100032Gatliff Coal Co - ADA Tipple 5003-83.8205636.840282112500084Admiralty Boats Inc001-84.073936.97252112500084Admiralty Boats Inc002-84.073936.97252112500084Admiralty Boats Inc003-84.073936.97252112500084Admiralty Boats Inc005-84.073936.97252112500084Admiralty Boats Inc006-84.073936.97252112500106ABC Automotive Systems IncEP1-21-84.0335237.21252112500106ABC Automotive Systems IncEP22-84.0335237.21252112500106ABC Automotive Systems IncEP23-84.0335237.21252112500106ABC Automotive Systems IncEP24-84.0335237.21252113300079Mountain Enterprises Inc - Cumberland Plant 200101-83.0211136.97862113300079Mountain Enterprises Inc - Cumberland Plant 200201-83.0211136.97862113300079Mountain Enterprises Inc - Cumberland Plant 200202-83.0211136.97862113300079Mountain Enterprises Inc - Cumberland Plant 200301-83.0211136.97862113500013Mountain Enterprises Inc -Vanceburg Plant 30001-83.347538.59232113500013Mountain Enterprises Inc -Vanceburg Plant 30002-83.347538.59232113500013Mountain Enterprises Inc -Vanceburg Plant 30003-83.347538.59232114100020Hanson Aggregates Midwest LLC - Rockfield Quarry001-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry002-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry003-86.614536.882Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201124-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2114100020Hanson Aggregates Midwest LLC - Rockfield Quarry004-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry005-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry006-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry007-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry008-86.614536.8822114100020Hanson Aggregates Midwest LLC - Rockfield Quarry009-86.614536.8822114100060Bowling Green Concrete - Rockfield Ready-Mix Plant001-86.614536.8822117900034Heaven Hill Distilleries Inc001-85.5607937.8981412118300069Western KY Energy Corp - Wilson StationEU-01-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationEU-02-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationEU-03-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationEU-04-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationEU-05-87.07909637.4521042118300069Western KY Energy Corp - Wilson StationIA-87.07909637.4521042119500267EQT Gathering LLC - Rockhouse Compressor Station01-82.328137.53772119500267EQT Gathering LLC - Rockhouse Compressor Station02-82.328137.53772120700022Pyles Concrete Inc001-85.05916737.1061112120700022Pyles Concrete Inc002-85.05916737.1061112120700022Pyles Concrete Inc003-85.05916737.1061112121100050LG&E\KU System Control & Data Center1-85.349838.21172121100050LG&E\KU System Control & Data Center2-85.349838.21172121300029South Union Elevator001-86.655436.87512121300029South Union Elevator002-86.655436.87512121300029South Union Elevator003-86.655436.87512121300029South Union Elevator004-86.655436.87512121300029South Union Elevator005-86.655436.87512121700033TN Gas Pipeline - Station 96001-85.394437.41372121700033TN Gas Pipeline - Station 96FUG01-85.394437.41372121700035Ambrake Corp001-85.329437.34122121700035Ambrake Corp002-85.329437.3412Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201125-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat2121700035Ambrake Corp003-85.329437.34122121900013Koppers Industries,Inc001-87.156436.64332121900013Koppers Industries,Inc002a-87.156436.64332121900013Koppers Industries,Inc002b-87.156436.64332121900013Koppers Industries,Inc003-87.156436.64332121900013Koppers Industries,Inc004-87.156436.64332121900013Koppers Industries,Inc005-87.156436.64332121900013Koppers Industries,Inc006-87.156436.64332123300008Webster Co Coal LLC - Dotiki Mine Prep Plant001-87.77468937.454022123300008Webster Co Coal LLC - Dotiki Mine Prep Plant002-87.77468937.454022123300008Webster Co Coal LLC - Dotiki Mine Prep Plant003-87.77468937.454022123300008Webster Co Coal LLC - Dotiki Mine Prep Plant004-87.77468937.454022123300008Webster Co Coal LLC - Dotiki Mine Prep Plant005-87.77468937.45402370210735Western Animal Disease Diagnostic LaboratoryES-1-82.53435.4294370573705700265CEMEX Construction Materials, Atlantic, LLCES2-80.047635.9019370573705700265CEMEX Construction Materials, Atlantic, LLCES3-80.047635.9019370573705700265CEMEX Construction Materials, Atlantic, LLCES4-80.047635.901937119134Rea Contracting, LLC. (069 Arrowood)1-80.920335.0928450030080-0011SCE&G URQUHART3-81.911433.4342450150420-0015ALUMAX OF SOUTH CAROLINA1-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA10-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA100-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA101-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA11-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA12-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA122-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA123-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA124-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA13-80.054233.0517450150420-0015ALUMAX OF SOUTH CAROLINA14-80.054233.0517Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201126-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat450150420-0015ALUMAX OF SOUTH CAROLINA15-80.054233.0517450150420-0015ALUMAX OF SOUTH 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Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201147-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat471490155NISSAN NORTH AMERICA, INC.SOB3-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.SOS3-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.SPP3-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.SPP4-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.TC1-86.49231433868435.9616818991803471490155NISSAN NORTH AMERICA, INC.TC23-86.49231433868435.9616818991803471490172STRATOS (JAVELIN_2 BOATS)65978-86.38252635.794599471490172STRATOS (JAVELIN_2 BOATS)65979-86.38252635.794599471490172STRATOS (JAVELIN_2 BOATS)65980-86.38252635.794599471490172STRATOS (JAVELIN_2 BOATS)S-014-86.38252635.794599471530034TECUMSEH PRODUCTS CO.S-001-85.37884435.389409471530034TECUMSEH PRODUCTS CO.S-002-85.37884435.389409471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A01-86.5588136.617026471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A02-86.5588136.617026471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A03-86.5588136.617026471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A04-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A05-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A06-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A07-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A08-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787A09-86.55872536.616827471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C01-86.5577936.61541471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C02-86.5577936.61541471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C03-86.5577936.61541471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C04-86.557936.61539471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C05-86.557936.61539471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C06-86.5578536.6153471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C07-86.5578536.6153471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787C08-86.5578536.6153471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787D01-86.55774436.615342Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201148-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787D02-86.55774436.615342471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787D03-86.55774436.615342471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787E01-86.5577536.615269471650008TENNESSEE GAS PIPELINE COMPANY, STATION 8787E02-86.5577536.615269471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONPT-3-89.620235.619894471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONPT-4-89.620235.619894471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONPT-5-89.620235.619894471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONREECO1-89.620235.619894471670079QW MEMPHIS CORPORATION - COVINGTON DIVISIONREECO2-89.620235.6198945100100012A and N Electric Cooperative - Tangier Island1-75.9937.825100161414Old Dominion Electric Cooperative - UNIT 91-7637.845100161415Old Dominion Electric Cooperative - UNIT 101-7637.845100300099Virginia Industries for the Blind1-78.47303338.0216355101900001Rubatex International LLC1-79.510237.3355102711159Equitable Production Co-Hurricane2-82.1537.13385103100006Babcock & Wilcox Nuclear Operations Group Inc21-79.055337.40915106500001Dominion - Bremo Power Station1-78.287837.70895107500030INGENCO - Rockville Plant1-77.66400937.7018395108100001Emporia Foundry Incorporated1-77.53359636.6953455108100011Belding Hausman Inc - Weldon Mill1-77.55790636.6878855108100020Georgia Pacific Wood Products - Emporia - Plywood1-77.52469336.6964945108500042Bear Island Paper Company LLC17-77.43884737.8130925109500023HRSD - Williamsburg Sewage Treatment Plant1-76.62911637.2145785110100001Stone Container Enterprises dba Smurfit-Stone Cont1-76.805337.53925110100004West Point Veneer LLC1-76.80705237.5452465110100021Old Dominion Grain1-76.81518137.5508935110100023Augusta Wood Products LC - Sawmill1-76.83381937.5691655110100027West Point Chips Incorporated1-76.802837.53475112100006Alliant Techsystems Inc2-80.54111137.1805565112100091Thermasteel Corporation1-80.56611137.116667Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201149-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat5113300013Waller, R P Oil BP1-76.27937.83895115300002Dominion - Possum Point Power Station10-77.28083338.5383335115300011Prince William Hospital Corporation5-77.48501138.7675155115300021LOCKHEED MARTIN MANASSAS11-77.51838.7466155115300814BAE Systems1-77.49703338.7549955115300889Architect of the Capitol2-77.51321138.7466155116100011Adams Construction Co - Rockydale1-79.946837.21495116100015Double Envelope Company1-79.955737.3536115116500069Adams Construction Company1-78.74154638.7012345116500106Transprint USA Inc1-78.90004738.39155117900020FBI Academy1-77.29021538.5214165119100044Universal Fibers Inc.1-82.105536.66285119500089P M Terminals Inc -Buck Oil Co1-82.313336.90445151500038Wheelabrator Abrasives Incorporated21-79.5536437.343985152000018Strongwell Corporation/Bristol Division6-82.177236.59615162000011Franklin City - Electric Dept - Mechanic Street1-76.91976236.6764955164000002Turman Hardwood Flooring Inc.5-80.939736.64975165000007US Air Force Base Langley15-76.351737.08255165000011US Department of Veterans Affairs Medical Ctr1-76.331937.01445165000093Bethel Landfill (USA Waste of Virginia)1-76.42636237.0728565168300003Glen-Gery Corporation - Capitol Plant1-77.504938.74045168300090City of Manassas/VMEA1-77.50805638.7397225169000050Southern Finishing1-79.85464636.6902115170000013Northrop Grumman Shipbuilding Incorporated28-76.43553636.9862045170000071Kinder Morgan Bulk Terminals - Pier IX1-76.43272736.9745565171000009Ford Motor Company Norfolk Plant6-76.25286136.8314475171000068U S Gypsum Co1-76.28560736.8278335171000113J H Miles & Company Incorporated1-76.30551736.8586165171000249Lyon Shipyard, Incorporated - Brown Ave1-76.27216236.8431475171000251Lyon Shipyard Incorporated - Sealift Drydock1-76.26506936.840516Development of Point Source Emission Inventory for 2007Southeastern States Air Resource Managers, Inc.AMEC Project No.: 6066-09-0326.02January 26, 201150-AAMECFIPSCodeState FacIDFacility NameReleasePoint IDLongLat5174000037Fleet & Industrial Supply Center1-76.37501836.8835335176000098Kinder Morgan Southeast Terminals-Rchmd Terminal10-77.42680537.4566475176000399Spruance Genco LLC1-77.42680537.4566475176000489Motiva Enterprises LLC-Richmond Terminal1-77.44530537.4919475181000013US Navy - Joint Expeditionary Base - Little Creek1-76.146936.90585181000034HRSD Chesapeake-Elizabeth Sewage Treatment Plant1-76.16472136.90675540295402900001ARCELORMITTAL WEIRTON INC.107-80.602840.4219540295402900001ARCELORMITTAL WEIRTON INC.108-80.602840.4219540295402900001ARCELORMITTAL WEIRTON INC.109-80.602840.4219540295402900001ARCELORMITTAL WEIRTON INC.111-80.602840.4219540295402900001ARCELORMITTAL WEIRTON INC.112-80.602840.4219