Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FAX 

MEMORANDUM 

To: VISTAS State Point Source Contacts and VISTAS EGU Special Interest Workgroup 

From: Gregory Stella, VISTAS Technical Advisor - Emission Inventories 

Date: June 13, 2005 

Re: EGU Emission Factors and Emission Factor Assignment 

Purpose

The purpose of this memorandum is to discuss the differences currently known to exist in the 

base year (2002) and future year (2009 and 2018) forecasts of EGU emission factors for PM and 

NH3. In particular, it has been identified that E.H. Pechan & Associates, Inc. (Pechan) in their 

development of post-processed IPM output into NIF structure uses a set of PM and NH3 

emission factors that are “the most recent EPA approved uncontrolled emission factors” and 

which are most likely not the same emission factors used by States and emission inventory 

preparation contractors for estimating these emissions in 2002 for EGUs in the VISTAS domain. 

Additionally, through review of the code used to post-process the IPM parsed files, it has also 

been determined that emission factors are assigned in future years based on Pechan assigned 

SCCs and not necessarily initial base year SCCs as coded in the original VISTAS NIF files. 

A second objective of this memorandum is to propose a resolution to the issues at hand and to 

recommend a set of modifications to be made to the base year PM and NH3 emission estimates 

for this source category. 

Background

VISTAS Base Year EGU Emissions Preparation 

A major component to the development of the VISTAS point source sector of the inventory was 

the incorporation of data submitted by the VISTAS States and local (S/L) agencies to the United 

States Environmental Protection Agency (EPA) as part of the Consolidated Emissions Reporting 

Rule (CERR). Work on incorporating the CERR data into the revised base year involved: 1) 

obtaining the data from EPA or the S/L agency, 2) evaluating the emissions and pollutants 

reported in the submittal, 3) augmenting CERR data with annual emission estimates for PM10-

PRI and PM25-PRI; 4) evaluating the emissions from electric generating units, and 5) 

completing quality assurance reviews for each component of the point source inventory. 

Data from several sources were used: 1) the inventories that the S/L submitted to EPA from May 

through July 2004; 2) supplemental data supplied by the S/L agencies that may have been 

revised or finalized after submittal to EPA, and 3) the original VISTAS 2002 inventory in cases 

where S/L CERR data were not available. 
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FAX 

Particulate matter emissions can be reported in many different forms, as follows: 

PM Category Description

PM-PRI Primary PM (includes filterable and condensable) 

PM-CON Primary PM, condensable portion only (all less than 1 micron) 

PM-FIL Primary PM, filterable portion only 

PM10-PRI Primary PM10 (includes filterable and condensable) 

PM10-FIL Primary PM10, filterable portion only 

PM25-PRI Primary PM25 (includes filterable and condensable) 

PM25-FIL Primary PM25, filterable portion only 

State/local agencies did not report PM emissions in a consistent manner. The State/local 

inventories submitted for VISTAS included emissions data for either PM-FIL, PM-PRI, PM10-

FIL, PM10-PRI, PM25-FIL, PM25-PRI, and/or PM-CON. From any one of these pollutants, 

EPA has developed augmentation procedures to estimate PM10-PRI, PM10-FIL, PM25-PRI, 

PM25-FIL, and PM-CON. If not included in a State/local inventory, PM10-PRI and PM25-PRI 

were calculated by adding PM10-FIL and PM-CON or PM25-FIL and PM-CON, respectively. 

The procedures for augmenting point source PM emissions are documented in detail in Appendix 

C of Documentation for the Final 1999 National Emissions Inventory (Version 3) for Criteria 

Air Pollutants and Ammonia – Point Sources, January 31, 20041. 

Briefly, the PM data augmentation procedure includes the following five steps: 

• Step 1: Prepare S/L/T PM and PM10 Emissions for Input to the PM Calculator 

• Step 2: Develop and Apply Source-Specific Conversion Factors 

• Step 3: Prepare Factors from PM Calculator 

• Step 4: Develop and Apply Algorithms to Estimate Emissions from S/L/T Inventory Data 

• Step 5: Review Results and Update the NEI with Emission Estimates and Control 

Information. 

Ammonia (NH3) emissions from these sources were assigned using direct incorporation of S/L/T 

provided emission estimates or via the application of emission factors using ratios of NH3 

emission factors to other reported pollutants (e.g., VOC, CO, etc.). 

IPM Post Processing 

ICF via VISTAS contracts provided an initial spreadsheet file containing unit-level records of 

both (1) “existing” units and (2) committed or new generic aggregates. All records have unit and 

fuel type data; existing, retrofit (for SO2 and NOx), and separate NOx control information; annual 

SO2 and NOx emissions and heat input; summer season (May-September) NOx and heat input; 

July day NOx and heat input; coal heat input by coal type; nameplate capacity (MW), and State 

FIPS code. Existing units also have county FIPS code, a unique plant identifier (ORISPL) and 

unit ID (also called boiler ID) (BLRID); generic units do not have these data. 

 

1

 ftp://ftp.epa.gov/EmisInventory/finalnei99ver3/criteria/documentation/point/point_99nei_finalv3_0204.pdf 
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FAX 

The IPM data were further processed by Pechan using data files and methodology recently 

approved by EPA. The most current documentation related to this subject is the EPA report 

titled, Documentation for the 2002 Electric Generating Unit (EGU) National Emissions 

Inventory (NEI), September 20042

. The processing includes estimating various types of 

emissions and adding in control efficiencies, stack parameters, latitude-longitude coordinates, 

and State identifiers (plant ID, point ID, stack ID, process ID). Additionally, the generic units 

were sited in a county and given IDs. 

Pechan developed SCC assignments for all units; unit/fuel/firing/bottom type data were used for 

existing units’ assignments, while only unit and fuel type were used for generic units’ 

assignments. Additional review of the source code used in developing these post-processed files 

confirmed this fact. In actuality, not only does it exist that the post-processing code assigns 

different emission factors for the same SCC but that SCCs assigned in future year IPM output are 

potentially different than those assigned in the base year inventory, leading to additional, 

propagating differences in the base year and future year estimates. The full extent of these issues 

is currently under review by VISTAS and MRPO. 

Stack parameters were attached, first using matches to data in the VISTAS 2002 NIF files, 

secondly using the EPA-provided data files, thirdly using a March 9, 2004 Pechan in-house stack 

parameter file based on previous EIA-767 data, and lastly using an EPA June 2003 SCC-based 

default stack parameter file. 

Plant ID (within State and county), point ID, process ID, and stack ID were then attached, first 

using the VISTAS-provided data files, or secondly using EPA or Pechan-generated defaults. 

Default stack IDs within a plant were assigned for each unique stack height-diameter 

combination. The process ID and stack ID default data were only used when the data were not 

matched to the original VISTAS 2002 NIF files. 

Additional data were required for estimating VOC, CO, filterable primary PM10 and PM2.5, PM 

condensable, and NH3 emissions for all units. Thus, ash and sulfur contents were assigned by 

first using 2002 EIA-767 values for existing units or SCC-based defaults; filterable PM10 and 

PM2.5 efficiencies were obtained from the 2002 EGU NEI that were based on 2002 EIA-767 

control data and the PM Calculator program (a default of 99.2% was used for coal units if 

necessary); fuel use was back calculated from the given heat input and a default SCC-based heat 

content; and emission factors were obtained from an EPA-approved October 7, 2004 Pechan 

emission factor file based on AP-42 emission factors. Table 1 provides the emission factor 

differences between the “old” emission factor file (used in development of EPA’s 1999 NEI v.3) 

and the updated factors as used in VISTAS latest IPM conversion. Note that this updated file was 

not the one used for estimating emissions for previous EPA post-processed IPM files (including 

estimates for CAIR). It should also be noted that this component of emission estimation is only 

for the filterable component of PM and that the emission factors used for condensable PM did 

not change between the two versions. 

 

2

 ftp://ftp.epa.gov/EmisInventory/draftnei2002/point/documentation/egu2002doc.pdf 
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FAX 

Issue Identification

During a VISTAS TAWG meeting held at the Solution Center in Durham, NC on April 5 and 6, 

2005, emission summaries were presented as comparisons of 2002 to 2018 forecasts. Table 2 

presents the slide originally used in identifying the increase in PM and NH3 emissions. In this 

comparison, it was noted that PM and NH3 emissions (highlighted in Table 2) from EGUs were 

significantly higher in 2018 than in 2002 and based on known regulation and activity, no reason 

could be identified for this increase. After an initial review of the data, it was determined that the 

PM and NH3 emission factors used between the base year and future year were most likely the 

culprit. In fact, for some SCCs, the NH3 emission factor increased by over 5,000% (0.000565 to 

0.03 lbs/ton coal burned). Changes in PM emission factors were not as large and limited to only 

a few SCCs. However, this emissions increase was simply an artifact of the change in emission 

factor, not anything to do with changes in activity or control technology application. 

Additionally, after further review of the post-processing code by VISTAS, it was determined that 

not only were differing emission factors being used for similar SCCs between the base and future 

year estimates for those SCCs identified in Table 2, but that the same SCCs were not necessarily 

being used for emission factor assignment in the base and post-processed IPM scenarios. This 

issue has implications not only for the different PM and NH3 factors, but for other pollutants 

(CO, VOC) not initially estimated by IPM. 

Table 3 presents those unit-segment (SCC) combinations which have been identified in the 2018 

OTW run to have been assigned SCCs in the IPM post-processing step different than those in the 

2002 base case. In some instances, the SCCs are comparable enough that the emission factors 

assigned were the same. However, there are additional instances where significant enough 

difference exists that review and correction may be warranted. An analysis of the differences in 

assignment of these SCCs and associated factors has not yet been completed. 

Proposed Solution

There are two issues which need to be resolved in the estimation of relative differences in EGU 

emissions between VISTAS base year 2002 emissions inventory and any forecasts of this source 

sector using IPM and post-processing steps applied using existing programs provided by Pechan; 

(1) consistent use of emission factors between the base and future years, and (2) the consistent 

use of SCCs for determining emission factors between the base and future years. 

These issues can be resolved using a variety of ways but the proposal provided here positions 

VISTAS to regenerate some specific pollutant 2002 emissions for the EGU sector in a fashion 

consistent, and presumably, more up-to-date, than the estimates provided in the 2002 base year 

inventory. Additionally, this proposal allows for the existing process to be completed in the postprocessing steps but adjusts the resulting non-IPM generated emissions using correct SCCs and 

emission factors. 
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FAX 

Base Year Emissions Adjustment 

The first step is the adjustment of the 2002 base year emissions inventory. Using the latest 

“EPA-approved” uncontrolled emission factors by SCC, VISTAS contactors will utilize CERR 

or VISTAS reported annual heat input, fuel throughput, heat, ash and sulfur content to estimate 

annual uncontrolled emissions for units identified as output by IPM. This step will be conducted 

for non-CEM pollutants (CO, VOC, PM, and NH3) only. For PM emissions, the condensable 

component of emissions will also be calculated and added to the resulting PM primary 

estimations. When these fuel characteristic variables are found to be zero, out of range (as 

identified by AP-42 factors), or invalid, average fuel data collected from EPA’s AP-42 

documentation on heat, sulfur, and/or ash content will be used. The resulting emissions will then 

be adjusted by any control efficiency factors reported in the CERR or VISTAS data collection 

effort. 

Future Year Scenario Adjustment 

Because the assignment of the SCCs to IPM output is a post-processing step which involves the 

cross-reference file developed to match IPM units to VISTAS 2002 base year inventory, it 

should be relatively straightforward to modify the code to assign the same base year SCC to the 

future year. Then, through assignment of SCCs and associated emission factors (via another 

cross-reference), similar base year and future year emission factor assignments could be made; 

just using the projected controls and fuel throughput as predicted by IPM. If modifications can 

not be made directly to the code for this cross-reference step, VISTAS can modify the resulting 

post-processed NIF files for those sources identified with alternate SCCs assigned in the future 

year. Using the same methods as described for the 2002 revisions, those non-IPM generated 

pollutants would be estimated using IPM predicted fuel characteristics and base year 2002 SCC 

assignments.
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FAX 

Table 1. Comparison of “Old” vs. “New” Emission Factors for IPM Post-Processing 

SCCEMFACforMRPOoldvsnew.xls -- PM+NH3 EF, 12/17/04

This file lists the "Old" and "New" EPA-approved Uncontrolled PM10, PM2.5, and NH3 Emission 

Factors for the SCCs in the MRPO Scenarios. 

 

SCC1

 FUEL 

"New" 

PM10EF4

"Old" 

PM10EF3

"New" 

PM25EF4

"Old" 

PM25EF3 PMFLAG2

"New" 

NH3EF4

"Old" 

NH3EF3

10100201 BIT 2.6000 2.6000 1.4800 1.4800 A 0.030000 0.000565

10100202 BIT 2.3000 2.3000 0.6000 0.6000 A 0.030000 0.000565

10100203 BIT 0.2600 0.2600 0.1100 0.1100 A 0.030000 0.000565

10100204 BIT 13.2000 13.2000 4.6000 4.6000 0.030000 0.000565

10100211 BIT 2.6000 2.6000 1.4800 1.4800 A 0.030000 0.000565

10100212 BIT 2.3000 2.3000 0.6000 0.6000 A 0.030000 0.000565

10100217 BIT 12.4000 12.4000 1.3640 3.2000 0.030000 0.000565

10100221 SUB 2.6000 2.6000 1.4800 1.4800 A 0.030000 0.000565

10100222 SUB 2.3000 2.3000 0.6000 0.6000 A 0.030000 0.000565

10100223 SUB 0.2600 0.2600 0.1100 0.1100 A 0.030000 0.000565

10100224 SUB 13.2000 13.2000 4.6000 4.6000 0.030000 0.000565

10100226 SUB 2.3000 2.3000 0.6000 0.6000 A 0.030000 0.000565

10100238 SUB 16.1000 16.1000 4.2000 4.2000 0.030000 0.000565

10100301 LIG 1.8170 1.8170 0.5214 0.5214 A 0.030000 0.000565

10100302 LIG 2.3000 2.3000 0.6600 0.6600 A 0.030000 0.000565

10100303 LIG 0.8710 0.8700 0.3690 0.1100 A 0.030000 0.000565

10100317 LIG 12.0000 12.0000 1.4000 1.4000 0.030000 0.000565

10100601 NG 1.9000 1.9000 1.9000 1.9000 3.200000 3.200000

10100801 PC 7.9000 7.9000 4.5000 4.5000 A 0.397000 --- 

10102018 WC 12.0000 12.0000 1.4000 1.4000 0.030000 0.000565

20100201 NG 1.9380 1.9380 1.9380 1.9380 6.560000 --- 

20100301 IGCC 11.5500 11.5500 11.5500 11.5500 6.560000 --- 

Notes: 

1. SCCs beginning with 101002 (coal), 101003 (coal), 101008 (coke), or 101020 (waste coal), emission 

factors in LB/TON; SCCs beginning with 101006 (natural gas), 201002 (natural gas), or 201003 (IGCC), 

emission factors are in LB/E6FT3. 

2. If PMFLAG = 'A', then apply ash content to PM emission factor. 

3. "Old" emission factors are used for latest EPA IPM post-processing. 

4. "New" emission factors are used for MRPO IPM post-processing. 
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FA

Table 2. Annual Emissions Comparison of 2002 Typical with 2018 OTW; VISTAS Tier 1 Category Totals. 

VISTAS Total -19% -52% -8% -50% 13% 9% 

Miscellaneous 2% 0% 0% 0% 14% 5% 

Off-highway -40% -30% 23% -61% -29% -29% 

Highway Vehicles -47% -70% -19% -89% -34% -53% 

Waste Disposal & Recycling 11% 13% 9% 37% 11% 10% 

Storage & Transport -19% 28% 46% 34% -4% 2% 

Solvent Utilization 22% 48% 36% 23% 34% 32% Other Industrial Processes 22% 15% 21% 19% 28% 25% 

Petroleum & Related Industries -19% 23% 15% 11% 35% 33% 

Metals Processing 43% 27% 29% 37% 20% 20% Chemical & Allied Product Mfg 50% 29% 32% 31% 36% 36% 

Fuel Comb. Other -55% 19% -28% 15% -16% -8% 

Fuel Comb. Industrial 12% 0% 15% 7% 5% 7% 

Fuel Comb. Elec. Util. 13% -68% 53% -63% 69% 82% 

Source Category VOC NOx CO SO2 PM-10 PM-2.5 

Annual 2018 OTW - 2002 Typical Emissions (Percent)
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FA

Table 3. Differences in VISTAS Base Year 2002 and IPM Post-Processed SCC Emission Factor AssignmenFIPS Plant ID Plant Name Point ID Stack ID 01039 0001 ALABAMA ELECTRIC COOPERATIVE - MCWILLIAMS 005 002 01055 0002 ALABAMA POWER COMPANY - GADSDEN 002 001 01055 0002 ALABAMA POWER COMPANY - GADSDEN 003 001 01063 0001 ALABAMA POWER COMPANY - GREENE COUNTY 002 001 01063 0001 ALABAMA POWER COMPANY - GREENE COUNTY 003 001 01071 0008 TVA - WIDOWS CREEK 008 002 01071 0008 TVA - WIDOWS CREEK 009 003 01085 0008 GENERAL ELECTRIC CO 001 001 01097 1001 ALABAMA POWER COMPANY - BARRY 002 001 01097 1001 ALABAMA POWER COMPANY - BARRY 003 001 01097 1001 ALABAMA POWER COMPANY - BARRY 004 001 01097 1001 ALABAMA POWER COMPANY - BARRY 005 002 01097 1001 ALABAMA POWER COMPANY - BARRY 006 003 01097 1001 ALABAMA POWER COMPANY - BARRY 007 005 01097 1001 ALABAMA POWER COMPANY - BARRY 008 006 01097 1001 ALABAMA POWER COMPANY - BARRY 009 007 01097 1001 ALABAMA POWER COMPANY - BARRY 010 008 01127 0001 ALABAMA POWER COMPANY - GORGAS 004 003 01127 0001 ALABAMA POWER COMPANY - GORGAS 005 003 01127 0001 ALABAMA POWER COMPANY - GORGAS 006 004 01127 0001 ALABAMA POWER COMPANY - GORGAS 007 004 01127 0001 ALABAMA POWER COMPANY - GORGAS 008 004 12001 0010001 PROGRESS ENERGY FLORIDA, INC. U OF FL COGEN 1 1 12009 0090006 FLORIDA POWER & LIGHT (PCC) CAPE CANAVERAL 1 1 12009 0090006 FLORIDA POWER & LIGHT (PCC) CAPE CANAVERAL 2 2 12027 0270016 DESOTO COUNTY GENERATING COMPANY, LLC 2 2 12031 0310047 JEA KENNEDY 3 3 12031 0310047 JEA KENNEDY 4 4 12031 0310047 JEA KENNEDY 5 5 12031 0310485 JEA BRANDY BRANCH FACILITY 2 2 12033 0330045 GULF POWER COMPANY CRIST ELECTRIC GENERATING PLANT 2 1 12033 0330045 GULF POWER COMPANY CRIST ELECTRIC GENERATING PLANT 3 1 
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FA

FIPS Plant ID Plant Name Point ID Stack ID 

12049 0490043 VANDOLAH POWER COMPANY, LLC 1 1 12095 0950203 ORLANDO COGEN LIMITED, L.P. 1 1 12097 0970014 PROGRESS ENERGY FLORIDA, INC. INTERCESSION CITY PLANT 11 11 12097 0970014 PROGRESS ENERGY FLORIDA, INC. INTERCESSION CITY PLANT 18 18 12099 0990042 FLORIDA POWER & LIGHT (PRV) RIVIERA POWER PLANT 3 3 12099 0990042 FLORIDA POWER & LIGHT (PRV) RIVIERA POWER PLANT 4 4 12099 0990045 CITY OF LAKE WORTH UTILITIES TOM G. SMITH POWER PLANT 9 9 12103 1030011 PROGRESS ENERGY FLORIDA, INC. BARTOW PLANT 1 1 12103 1030011 PROGRESS ENERGY FLORIDA, INC. BARTOW PLANT 2 2 12103 1030011 PROGRESS ENERGY FLORIDA, INC. BARTOW PLANT 3 3 12105 1050003 LAKELAND ELECTRIC CHARLES LARSEN MEMORIAL POWER PLANT 4 4 12105 1050221 CALPINE/AUBURNDALE POWER PARTNERS, LP 6 6 12105 1050223 

PROGRESS ENERGY FLORIDA, INC. TIGER BAY COGENERATION FACILITY 3 3 

12105 1050233 TAMPA ELECTRIC COMPANY POLK POWER STATION 1 1 12121 1210003 PROGRESS ENERGY FLORIDA, INC. FL POWER SUWANNEE RVR PLANT 1 1 12121 1210003 PROGRESS ENERGY FLORIDA, INC. FL POWER SUWANNEE RVR PLANT 2 2 12121 1210003 PROGRESS ENERGY FLORIDA, INC. FL POWER SUWANNEE RVR PLANT 3 3 12127 1270009 FLORIDA POWER & LIGHT (PSN) SANFORD POWER PLANT 1 1 12127 1270020 PROGRESS ENERGY FLORIDA, INC. TURNER PLANT 10 10 12127 1270020 PROGRESS ENERGY FLORIDA, INC. TURNER PLANT 9 9 12127 1270028 PROGRESS ENERGY FLORIDA, INC. DEBARY FACILITY 17 17 12127 1270028 PROGRESS ENERGY FLORIDA, INC. DEBARY FACILITY 18 18 13051 05100006 KRAFT STEAM - ELECTRIC GENERATING PLANT SG01 CS1 13051 05100006 KRAFT STEAM - ELECTRIC GENERATING PLANT SG02 CS1 13067 06700003 

GEORGIA POWER COMPANY, MCDONOUGH STEAM-ELECTRIC GENERATING PLANT CT6M ST6M 

13067 06700003 

GEORGIA POWER COMPANY, MCDONOUGH STEAM-ELECTRIC GENERATING PLANT CT7M ST7M 

13115 11500003 

GEORGIA POWER COMPANY, HAMMOND STEAM-ELECTRIC GENERATING PLANT SG01 ST1 

13115 11500003 

GEORGIA POWER COMPANY, HAMMOND STEAM-ELECTRIC GENERATING PLANT SG02 ST1 

13115 11500003 

GEORGIA POWER COMPANY, HAMMOND STEAM-ELECTRIC GENERATING PLANT SG03 ST1 
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FA

FIPS Plant ID Plant Name Point ID Stack ID 

13115 11500003 

GEORGIA POWER COMPANY, HAMMOND STEAM-ELECTRIC GENERATING PLANT SG04 ST2 

13207 20700008 

GEORGIA POWER COMPANY, SCHERER STEAM-ELECTRIC GENERATING PLANT SG01 ST1 

13207 20700008 

GEORGIA POWER COMPANY, SCHERER STEAM-ELECTRIC GENERATING PLANT SG02 ST2 

13207 20700008 

GEORGIA POWER COMPANY, SCHERER STEAM-ELECTRIC GENERATING PLANT SG03 ST3 

13207 20700008 

GEORGIA POWER COMPANY, SCHERER STEAM-ELECTRIC GENERATING PLANT SG04 ST4 

13237 23700008 

GEORGIA POWER COMPANY, BRANCH STEAM-ELECTRIC GENERATING PLANT SG01 ST1 

13237 23700008 

GEORGIA POWER COMPANY, BRANCH STEAM-ELECTRIC GENERATING PLANT SG02 ST1 

13237 23700008 

GEORGIA POWER COMPANY, BRANCH STEAM-ELECTRIC GENERATING PLANT SG03 ST2 

13237 23700008 

GEORGIA POWER COMPANY, BRANCH STEAM-ELECTRIC GENERATING PLANT SG04 ST2 

21111 0126 LOU GAS & ELEC, CANE RUN 06 06 21111 0127 LOU GAS & ELEC, MILL CREEK 03 03 21111 0127 LOU GAS & ELEC, MILL CREEK 04 04 21157 2115700053 DUKE ENERGY MARSHALL COUNTY,LLC 001A 1 21223 2122300002 LOUISVILLE GAS & ELECTRIC TRIMBLE CO GEN STATION 001 1 28007 2800700032 ATTALA GENERATING COMPANY, LLC 003 3 28047 2804700055 MISSISSIPPI POWER COMPANY, PLANT JACK WATSON 004 4 28047 2804700055 MISSISSIPPI POWER COMPANY, PLANT JACK WATSON 005 5 28059 2805900090 MISSISSIPPI POWER COMPANY, PLANT DANIEL 001 1 28059 2805900090 MISSISSIPPI POWER COMPANY, PLANT DANIEL 002 2 28059 2805900090 MISSISSIPPI POWER COMPANY, PLANT DANIEL 003 3 28059 2805900090 MISSISSIPPI POWER COMPANY, PLANT DANIEL 004 4 28059 2805900090 MISSISSIPPI POWER COMPANY, PLANT DANIEL 005 5 28059 2805900090 MISSISSIPPI POWER COMPANY, PLANT DANIEL 006 6 37017 3701700043 ELIZABETHTOWN POWER, LLC G-17A S-1 37035 3703500073 DUKE ENERGY CORPORATION - MARSHALL STEAM STATION G-1 S-3 37035 3703500073 DUKE ENERGY CORPORATION - MARSHALL STEAM STATION G-2 S-4 37035 3703500073 DUKE ENERGY CORPORATION - MARSHALL STEAM STATION G-4 S-1 
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FA

FIPS Plant ID Plant Name Point ID Stack ID 

37035 3703500073 DUKE ENERGY CORPORATION - MARSHALL STEAM STATION G-5 S-2 37071 3707100039 DUKE ENERGY CORPORATION - ALLEN STEAM STATION G-14 S-1 37071 3707100039 DUKE ENERGY CORPORATION - ALLEN STEAM STATION G-15 S-2 37071 3707100039 DUKE ENERGY CORPORATION - ALLEN STEAM STATION G-16 S-3 37071 3707100039 DUKE ENERGY CORPORATION - ALLEN STEAM STATION G-17 S-4 37071 3707100039 DUKE ENERGY CORPORATION - ALLEN STEAM STATION G-18 S-5 37071 3707100040 DUKE ENERGY CORPORATION - RIVERBEND STEAM STATION G-17 S-5 37145 3714500029 CP&L - ROXBORO STEAM ELECTRIC PLANT G-29 S-1 37145 3714500029 CP&L - ROXBORO STEAM ELECTRIC PLANT G-35A S-3 37145 3714500029 CP&L - ROXBORO STEAM ELECTRIC PLANT G-35B S-3 37145 3714500029 CP&L - ROXBORO STEAM ELECTRIC PLANT G-36A S-4 37145 3714500029 CP&L - ROXBORO STEAM ELECTRIC PLANT G-36B S-4 37145 3714500045 CP&L - MAYO FACILITY G-46A S-1 37145 3714500045 CP&L - MAYO FACILITY G-46B S-1 37155 3715500147 PROGRESS ENERGY CAROLINAS, INC., W.H. WEATHERSPOON PLANT G-26 S-2 37155 3715500166 LUMBERTON POWER, LLC G-17A S-1 37159 3715900004 DUKE ENERGY CORPORATION - BUCK STEAM STATION G-4 S-6 37159 3715900163 ROWAN COUNTY POWER LLC G-1 S-1 37159 3715900163 ROWAN COUNTY POWER LLC G-2 S-2 37159 3715900163 ROWAN COUNTY POWER LLC G-3 S-3 37169 3716900004 DUKE ENERGY CORP - BELEWS CREEK STEAM STATION G-17 S-1 37169 3716900004 DUKE ENERGY CORP - BELEWS CREEK STEAM STATION G-18 S-2 37191 3719100017 PROGRESS ENERGY - F LEE PLANT G-3 S-1 37191 3719100017 PROGRESS ENERGY - F LEE PLANT G-4 S-2 45021 0600-0081 DUKE ENERGY:MILL CREEK CA1 1 45021 0600-0081 DUKE ENERGY:MILL CREEK CA2 2 45021 0600-0081 DUKE ENERGY:MILL CREEK CA3 3 47145 0013 TVA KINGSTON FOSSIL PLANT 001 S-1 47145 0013 TVA KINGSTON FOSSIL PLANT 002 S-1 47145 0013 TVA KINGSTON FOSSIL PLANT 003 S-1 47145 0013 TVA KINGSTON FOSSIL PLANT 004 S-1 47145 0013 TVA KINGSTON FOSSIL PLANT 005 S-1 47145 0013 TVA KINGSTON FOSSIL PLANT 006 S-2 47145 0013 TVA KINGSTON FOSSIL PLANT 007 S-2 
Atmospheric Sciences Group 

Alpine Geophysics, LLC ▪ 387 Pollard Mine Road ▪ Burnsville, NC 28714 ▪ (828) 675-9045 ▪ (828) 675-5801 FA

FIPS Plant ID Plant Name Point ID Stack ID 

47145 0013 TVA KINGSTON FOSSIL PLANT 008 S-2 47145 0013 TVA KINGSTON FOSSIL PLANT 009 S-2 47157 00528 ALLEN FOSSIL PLANT CTrb10 CTrb10 47161 0011 TVA CUMBERLAND FOSSIL PLANT 001 S-01 47161 0011 TVA CUMBERLAND FOSSIL PLANT 002 S-02 51001 00030 COMMONWEALTH CHESAPEAKE POWER STATION 1A 1 51001 00030 COMMONWEALTH CHESAPEAKE POWER STATION 1B 1 51001 00030 COMMONWEALTH CHESAPEAKE POWER STATION 1C 1 51001 00030 COMMONWEALTH CHESAPEAKE POWER STATION 1D 1 51001 00030 COMMONWEALTH CHESAPEAKE POWER STATION 1E 1 51001 00030 COMMONWEALTH CHESAPEAKE POWER STATION 1F 1 51001 00030 COMMONWEALTH CHESAPEAKE POWER STATION 1G 1 51083 00046 DOMINION - CLOVER POWER STATION 1 1 51083 00046 DOMINION - CLOVER POWER STATION 2 2 51153 00002 DOMINION - POSSUM POINT 3 3 51175 00051 DOMINION - SOUTHAMPTON POWER STATION 1 1 51191 00180 WOLF HILLS ENERGY LLC 21 1 51191 00180 WOLF HILLS ENERGY LLC 22 2 51191 00180 WOLF HILLS ENERGY LLC 23 3 51191 00180 WOLF HILLS ENERGY LLC 24 4 51191 00180 WOLF HILLS ENERGY LLC 25 5 51760 00389 DOMINION - BELLEMEADE 20 1 51760 00389 DOMINION - BELLEMEADE 21 2 54023 0014 NORTH BRANCH POWER STATION 002 001