The Atlanta Eight-Hour Ozone Attainment Demonstration 

Appendix O 

VISTAS CEM Emission Rate Memo 
Atmospheric Sciences Group 

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MEMORANDUM

To: VISTAS Point Source State Contacts and VISTAS EGU SIWG

From: Gregory Stella, Alpine Geophysics, LLC

Date: June 24, 2005

Subject: Emission Factor/Rate Development for IPM Post-Processing

The purpose of this memorandum is to document a proposed process for developing base year 

2002 emission factor/rate values at EGU sources known to be forecasted to future years using 

IPM. These factors will be derived only for pollutants not forecasted by IPM; VOC, CO, PM, 

and NH3. An earlier memo dated June 13, 2005 details known issues with the application of 

emission factors to sources forecasted with IPM. It is the objective of the VISTAS EGU SIWG 

to develop emission factors at a unit specific level which can then be applied to future year 

forecasts of heat input from IPM to maintain a consistent use of emission factors in both the base 

and future years.

Unit Level Data

Since IPM forecasts unit level data with a single segment (SCC) fuel assumption, the VISTAS 

2002 base year point source emission inventory will be summed to the unit (boiler) level to 

estimate total emissions for each unique point. This process eliminates the ability of VISTAS to 

develop the typical fuel-specific emission factors (i.e., lbs/ton) as multiple fuel types are now 

included in the unit level summary. Instead, VISTAS will calculate pollutant emission rates 

(lbs/MMbtu) based on the unit’s total emissions and heat input. Heat input will be obtained using 

CEM data previously matched to VISTAS base year for purposes of temporal allocation of 

emissions. These heat input data are also collected and provided by EPA at a unit level and 

therefore already match the unit summed emissions. It is expected that this matching will capture 

the majority of VISTAS EGU sources as documented in previous VISTAS presentations.

Calculations

Using annual emissions and heat input information for sources where CEM matches can be 

obtained, VISTAS will calculate emission rates for every non-IPM generated pollutant reported 

in the base year 2002 NIF. These emission rates will then be used to determine future year nonIPM pollutant emissions for these same sources. In cases where CEM data cannot be matched or 

where data are not available to make these calculations, VISTAS will follow existing IPM postprocessing steps to estimate future year non-IPM pollutant emissions.

IPM output includes each unit’s predicted heat input estimate in MMbtu. Using this provided 

value and the emission rates estimated using the base year emissions and heat input, VISTAS 

will calculate CO, VOC, and PM emissions for the future scenario cases. Because of the unique 

configuration of NH3 emission estimates as a result of post-combustion control, an alternate 

method will be used to determine these emissions.
Atmospheric Sciences Group 

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Ammonia (NH3) emissions will be estimated only at sources where post-combustion NOx 

controls have been identified. Although EPA has published emission factors for uncontrolled 

emissions of NH3 at combustion sources, these factors are based on data collected for the 1985 

NAPAP effort and have D or lower ratings and therefore will not be used at sources where no 

post-combustion control is assigned. Methods outlined in EPA’s EIIP document Estimating 

Ammonia Emissions from Anthropogenic Nonagricultural Sources – Draft Final Report, April 

20041 will be used to develop this NH3 emissions associated with slip.

Sources identified during the NEEDS file review as having post-combustion NOx control will be 

reviewed in the base year 2002 EI to determine if NH3 emissions have been estimated. Table 1 

presents those sources initially identified in the VISTAS 2002 EI and NEEDS file that have postcombustion control, yet have no reported NH3 emissions. VISTAS will calculate NH3 emission 

values for these sources and use them in our Base F modeling. Using similar methods, VISTAS 

will obtain post-combustion control information from the IPM outputs and assign NH3 emissions 

associated with slip to those controlled sources in the future year scenarios.

Although no adjustments will be made in the VISTAS base year files, sources listed in Table 2 

have annual NH3 emissions reported in the base year 2002 emissions inventory yet have no or 

inconclusive post-combustion control applied. Emission rates for ammonia from these sources 

will be calculated and used in the future year estimates.

Assumptions

It is clear that the use of emission rates vs. emission factors may not fully take into account the 

fuel specific characteristics for each segment originally reported in the VISTAS EI. For example, 

a boiler which is primarily coal-fired but has a startup diesel component would now be

represented as a single segment instead of the separate coal and oil segments. However, using the 

unit’s emission rate as developed for the unit as a whole preserves some of these characteristics 

as the heat content and fuel throughput would be represented as the total heat input value used in 

the emission rate calculation.

Also, due to lack of reported control data in the VISTAS EI, base year emission controls for nonIPM derived pollutants can not be backed out to estimate uncontrolled emission rates. However, 

as the controls assigned in the future year can only be incremental to the base year technologies, 

the use of base year controlled emission rates is a valid starting assumption. In other words, the 

technologies represented in the calculated base year emission rate will also be reflected in the 

application of the rate in the future years. VISTAS will have to make minor modifications to 

NH3 due to slip in the application of some post-combustion controls applied in the future year 

scenarios.

 

1

 http://www.epa.gov/ttn/chief/eiip/techreport/volume03/eiip_areasourcesnh3.pdf
Atmospheric Sciences Group 

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Table 1. Sources with post-combustion control but no reported NH3 emissions.

FIPSST FIPSCNTY Plant ID Point ID ORISID BLRID Plant

Post-Combustion

Control

01 033 0010 014 47 5 TVA COLBERT SCR

01 071 0008 008 50 7 TVA - WIDOWS CREEK SCR

01 071 0008 009 50 8 TVA - WIDOWS CREEK SCR

01 073 010730011 001 6002 1 ALABAMA POWER COMPANY (MILLER POWER PLAN SCR

01 073 010730011 002 6002 2 ALABAMA POWER COMPANY (MILLER POWER PLAN SCR

01 073 010730011 004 6002 3 ALABAMA POWER COMPANY (MILLER POWER PLAN SCR

01 073 010730011 005 6002 4 ALABAMA POWER COMPANY (MILLER POWER PLAN SCR

01 097 1001 007 3 6A ALABAMA POWER COMPANY - BARRY SCR

01 097 1001 008 3 6B ALABAMA POWER COMPANY - BARRY SCR

01 097 1001 009 3 7A ALABAMA POWER COMPANY - BARRY SCR

01 097 1001 010 3 7B ALABAMA POWER COMPANY - BARRY SCR

01 097 8073 001 7721 CC1 ALABAMA POWER COMPANY - THEODORE COGEN SCR

01 117 0005 006 26 5 ALABAMA POWER COMPANY - E C GASTON SCR

01 127 0001 008 8 10 ALABAMA POWER COMPANY - GORGAS SCR

12 009 0090180 1 55286 O-1 OLEANDER POWER PROJECT, LP SCR

12 009 0090180 2 55286 O-2 OLEANDER POWER PROJECT, LP SCR

12 009 0090180 3 55286 O-3 OLEANDER POWER PROJECT, LP SCR

12 009 0090180 4 55286 O-4 OLEANDER POWER PROJECT, LP SCR

12 027 0270016 1 55422 CT1 DESOTO COUNTY GENERATING COMPANY, LLC SCR

12 027 0270016 2 55422 CT2 DESOTO COUNTY GENERATING COMPANY, LLC SCR

12 033 0330045 6 641 6 GULF POWER COMPANY CRIST ELECTRIC GENERA SNCR

12 033 0330045 7 641 7 GULF POWER COMPANY CRIST ELECTRIC GENERA SCR

12 049 0490043 1 55415 GT101 VANDOLAH POWER COMPANY, LLC SCR

12 049 0490043 2 55415 GT201 VANDOLAH POWER COMPANY, LLC SCR

12 049 0490043 3 55415 GT301 VANDOLAH POWER COMPANY, LLC SCR

12 049 0490043 4 55415 GT401 VANDOLAH POWER COMPANY, LLC SCR

12 095 0950137 2 564 2 ORLANDO UTILITIES COMMISSION STANTON ENE SCR

12 097 0970071 3 55192 OSC3 RELIANT ENERGY OSCEOLA, LLC SCR

12 105 1050004 28 676 5 LAKELAND ELECTRIC C.D. MCINTOSH, JR. POW SCR

12 105 1050233 3 7242 **3 TAMPA ELECTRIC COMPANY POLK POWER STATIO SCR

12 105 1050234 1 7302 1A PROGRESS ENERGY FLORIDA, INC. HINES ENER SCR

12 105 1050234 2 7302 1B PROGRESS ENERGY FLORIDA, INC. HINES ENER SCR

12 113 1130168 1 55242 CT-1 SANTA ROSA ENERGY LLC SCR

13 015 01500011 SG01 703 1BLR GEORGIA POWER COMPANY, BOWEN STEAM-ELECT SCR

13 015 01500011 SG02 703 2BLR GEORGIA POWER COMPANY, BOWEN STEAM-ELECT SCR

13 015 01500011 SG03 703 3BLR GEORGIA POWER COMPANY, BOWEN STEAM-ELECT SCR

13 015 01500011 SG04 703 4BLR GEORGIA POWER COMPANY, BOWEN STEAM-ELECT SCR

13 115 11500003 SG04 708 4 GEORGIA POWER COMPANY, HAMMOND STEAM-ELE SCR

13 149 14900001 SG01 6052 1 GEORGIA POWER COMPANY, WANSLEY STEAM-ELE SCR

13 149 14900001 SG02 6052 2 GEORGIA POWER COMPANY, WANSLEY STEAM-ELE SCR

21 015 2101500029 002 6018 2 CINCINNATI GAS & ELECTRIC EAST BEND STAT SCR

21 059 2105900027 001 1374 1 OWENSBORO MUNICIPAL UTIL ELMER SMITH STA SCR

21 111 0127 03 1364 3 LOU GAS & ELEC, MILL CREEK SCR

21 111 0127 04 1364 4 LOU GAS & ELEC, MILL CREEK SCR

21 127 2112700003 002 1353 BSU2 KENTUCKY POWER CO BIG SANDY PLANT SCR

21 157 2115700053 001A 55232 CT1 DUKE ENERGY MARSHALL COUNTY,LLC SCR

21 157 2115700053 001B 55232 CT2 DUKE ENERGY MARSHALL COUNTY,LLC SCR
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FIPSST FIPSCNTY Plant ID Point ID ORISID BLRID Plant

Post-Combustion

Control

21 157 2115700053 001C 55232 CT3 DUKE ENERGY MARSHALL COUNTY,LLC SCR

21 157 2115700053 001D 55232 CT4 DUKE ENERGY MARSHALL COUNTY,LLC SCR

21 157 2115700053 001E 55232 CT5 DUKE ENERGY MARSHALL COUNTY,LLC SCR

21 157 2115700053 001F 55232 CT6 DUKE ENERGY MARSHALL COUNTY,LLC SCR

21 157 2115700053 001G 55232 CT7 DUKE ENERGY MARSHALL COUNTY,LLC SCR

21 157 2115700053 001H 55232 CT8 DUKE ENERGY MARSHALL COUNTY,LLC SCR

21 161 2116100009 001 6041 1 EAST KY POWER COOP SPURLOCK ST. MAYSVILL SCR

21 161 2116100009 002 6041 2 EAST KY POWER COOP SPURLOCK ST. MAYSVILL SCR

21 177 2117700006 001 1378 1 TVA PARADISE STEAM PLANT SCR

21 177 2117700006 002 1378 2 TVA PARADISE STEAM PLANT SCR

21 177 2117700006 003 1378 3 TVA PARADISE STEAM PLANT SCR

21 183 2118300069 001 6823 W1 WESTERN KY ENERGY CORP WILSON STATION SCR

21 185 2118500036 001 55164 GTG1 BLUEGRASS GENERATION CO SCR

21 185 2118500036 002 55164 GTG2 BLUEGRASS GENERATION CO SCR

21 185 2118500036 003 55164 GTG3 BLUEGRASS GENERATION CO SCR

21 199 2119900005 002 1384 2 EAST KY POWER COOP JOHN SHERMAN COOPER P SCR

21 223 2122300002 001 6071 1 LOUISVILLE GAS & ELECTRIC TRIMBLE CO GEN SCR

21 223 2122300002 025 6071 5 LOUISVILLE GAS & ELECTRIC TRIMBLE CO GEN SCR

21 223 2122300002 026 6071 6 LOUISVILLE GAS & ELECTRIC TRIMBLE CO GEN SCR

21 233 2123300001-A 002 1382 H1 HENDERSON STATION 2 SCR

28 007 2800700032 001 55220 A01 ATTALA GENERATING COMPANY, LLC SCR

28 007 2800700032 002 55220 A02 ATTALA GENERATING COMPANY, LLC SCR

28 019 2801900011 001A 55076 AA001 CHOCTAW GENERATION LLP, RED HILLS GENERA SCR

28 019 2801900011 001B 55076 AA002 CHOCTAW GENERATION LLP, RED HILLS GENERA SCR

28 027 2802700079 001 55395 CT01 CLARKSDALE PUBLIC UTILITIES, CROSSROADS SCR

28 027 2802700079 002 55395 CT02 CLARKSDALE PUBLIC UTILITIES, CROSSROADS SCR

28 027 2802700079 003 55395 CT03 CLARKSDALE PUBLIC UTILITIES, CROSSROADS SCR

28 027 2802700079 004 55395 CT04 CLARKSDALE PUBLIC UTILITIES, CROSSROADS SCR

37 145 3714500029 G-35A 2712 3A CP&L - ROXBORO STEAM ELECTRIC PLANT SCR

37 145 3714500029 G-35B 2712 3B CP&L - ROXBORO STEAM ELECTRIC PLANT SCR

45 015 0420-0006 001 3298 WIL1 SCE&G:WILLIAMS SCR

45 015 0420-0030 001 130 1 SANTEE COOPER CROSS SCR

45 015 0420-0030 002 130 2 SANTEE COOPER CROSS SCR

45 021 0600-0081 CA1 7981 1 DUKE ENERGY:MILL CREEK SCR

45 021 0600-0081 CA2 7981 2 DUKE ENERGY:MILL CREEK SCR

45 021 0600-0081 CA3 7981 3 DUKE ENERGY:MILL CREEK SCR

45 021 0600-0081 CA4 7981 4 DUKE ENERGY:MILL CREEK SCR

45 043 1140-0005 001 6249 1 SANTEE COOPER WINYAH SCR

45 043 1140-0005 002 6249 2 SANTEE COOPER WINYAH SCR

45 043 1140-0005 003 6249 3 SANTEE COOPER WINYAH SCR

45 043 1140-0005 004 6249 4 SANTEE COOPER WINYAH SCR

45 079 1900-0013 001 3297 WAT1 SCE&G:WATEREE SCR

45 079 1900-0013 002 3297 WAT2 SCE&G:WATEREE SCR

47 001 0009 001 3396 1 TVA BULL RUN FOSSIL PLANT SCR

47 145 0013 001 3407 1 TVA KINGSTON FOSSIL PLANT SCR

47 145 0013 002 3407 2 TVA KINGSTON FOSSIL PLANT SCR

47 145 0013 003 3407 3 TVA KINGSTON FOSSIL PLANT SCR

47 145 0013 004 3407 4 TVA KINGSTON FOSSIL PLANT SCR

47 145 0013 005 3407 5 TVA KINGSTON FOSSIL PLANT SCR
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FIPSST FIPSCNTY Plant ID Point ID ORISID BLRID Plant

Post-Combustion

Control

47 145 0013 006 3407 6 TVA KINGSTON FOSSIL PLANT SCR

47 145 0013 007 3407 7 TVA KINGSTON FOSSIL PLANT SCR

47 145 0013 008 3407 8 TVA KINGSTON FOSSIL PLANT SCR

47 161 0011 001 3399 1 TVA CUMBERLAND FOSSIL PLANT SCR

47 161 0011 002 3399 2 TVA CUMBERLAND FOSSIL PLANT SCR

51 065 00001 2 3796 4 DOMINION - BREMO POWER STATION SNCR

51 153 00002 3 3804 3 DOMINION - POSSUM POINT SCR

51 153 00002 4 3804 4 DOMINION - POSSUM POINT SCR

51 670 00058 1 10771 1 HOPEWELL COGENERATION LTD PARTNERSHIP SNCR

51 670 00058 2 10771 2 HOPEWELL COGENERATION LTD PARTNERSHIP SNCR

54 033 0015 001 3944 1 MONONGAHELA POWER CO-HARRISON SCR

54 033 0015 002 3944 2 MONONGAHELA POWER CO-HARRISON SCR

54 033 0015 003 3944 3 MONONGAHELA POWER CO-HARRISON SCR

54 061 0001 001 3943 1 MONONGAHELA POWER CO.- FORT MARTIN POWER SNCR

54 061 0001 002 3943 2 MONONGAHELA POWER CO.- FORT MARTIN POWER SNCR

54 073 0005 001 6004 1 MONONGAHELA POWER CO-PLEASANTS POWER STA SCR

54 073 0005 002 6004 2 MONONGAHELA POWER CO-PLEASANTS POW ER STA SCR

54 073 0022 001 55349 1 PLEASANTS ENERGY LLC SCR

54 073 0022 002 55349 2 PLEASANTS ENERGY LLC SCR
Atmospheric Sciences Group 

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Table 2. Sources with annual NH3 emissions but none or inconclusive post-combustion control.

2002 Annual Values

NH3 Emiss NH3 Rate Heat Input

FIPSST FIPSCNTY Plant ID Point ID ORISID BLRID Plant (Tons) (lbs/MMBtu) (MMBtu)

01 001 0008 001 55271 CT1 TENASKA ALABAMA GENERATING STATION 2.140 0.001174 3,645,276

01 039 0001 006 533 **V1 ALABAMA ELECTRIC COOPERATIVE - MCWILLIAM 12.310 0.003218 7,651,684

01 039 0001 007 533 **V2 ALABAMA ELECTRIC COOPERATIVE - MCWILLIAM 9.920 0.003934 5,043,248

01 081 0036 001 7840 1A GEORGIA POWER COMPANY - FRANKLIN 4.510 0.001671 5,398,934

01 081 0036 002 7840 1B GEORGIA POWER COMPANY - FRANKLIN 4.330 0.001672 5,179,918

01 097 8066 001 55241 COG01 MOBILE ENERGY LLC - HOG BAYOUR ENERGY CE 5.690 0.002843 4,002,968

12 103 1030011 1 634 1 PROGRESS ENERGY FLORIDA, INC. BARTOW PLA 12.440 0.004286 5,805,143

12 103 1030011 2 634 2 PROGRESS ENERGY FLORIDA, INC. BARTOW PLA 15.050 0.004309 6,984,802

12 103 1030011 3 634 3 PROGRESS ENERGY FLORIDA, INC. BARTOW PLA 26.540 0.004174 12,716,189

13 021 0002 1 699 1 ARKWRIGHT 2.106 0.029488 142,839

13 021 0002 2 699 2 ARKWRIGHT 2.340 0.037032 126,378

13 021 0002 3 699 3 ARKWRIGHT 0.499 0.000842 1,185,096

13 021 0002 4 699 4 ARKWRIGHT 0.093 0.003055 60,874

37 021 0628 1 2706 1 CAROLINA POWER & LIGHT ASHEVILLE STEAM E 2.846 0.000423 13,448,054

37 071 3707100039 G-16 2718 3 DUKE ENERGY CORPORATION - ALLEN STEAM ST 0.311 0.000067 9,225,806

37 071 3707100039 G-17 2718 4 DUKE ENERGY CORPORATION - ALLEN STEAM ST 0.427 0.000068 12,551,792

37 071 3707100039 G-18 2718 5 DUKE ENERGY CORPORATION - ALLEN STEAM ST 0.462 0.000065 14,146,683

37 153 3715300070 G-15 7805 7 CP&L - RICHMOND CNTY COMBUSTN TURBINE 3.862 0.002643 2,922,928

37 153 3715300070 G-9 7805 8 CP&L - RICHMOND CNTY COMBUSTN TURBINE 2.721 0.001717 3,168,714

45 007 0200-0004 001 3264 1 DUKE ENERGY:LEE 0.016 0.000012 2,618,179

45 007 0200-0004 002 3264 2 DUKE ENERGY:LEE 0.016 0.000013 2,495,463

45 007 0200-0004 003 3264 3 DUKE ENERGY:LEE 0.028 0.000011 5,131,805

51 041 00002 3 3797 3 DOMINION - CHESTERFIELD POWER STATION 0.117 0.000067 3,494,532

51 041 00002 4 3797 4 DOMINION - CHESTERFIELD POWER STATION 0.206 0.000038 10,708,221

51 041 00002 6 3797 5 DOMINION - CHESTERFIELD POWER STATION 0.426 0.000038 22,584,280

51 041 00002 8 3797 6 DOMINION - CHESTERFIELD POWER STATION 0.691 0.00003 46,648,052

51 071 00002 1 3776 51 AMERICAN ELECTRIC POWER GLEN LYN 0.110 0.000081 2,714,078

51 071 00002 2 3776 52 AMERICAN ELECTRIC POWER GLEN LYN 0.112 0.000078 2,879,042

51 071 00002 3 3776 6 AMERICAN ELECTRIC POWER GLEN LYN 0.066 0.000011 11,837,961

51 085 00061 1 52019 CT1 DOSWELL LIMITED PARTNERSHIP 13.188 0.020726 1,272,579

51 167 00003 1 3775 1 AMERICAN ELECTRIC POWER-CLINCH RIVER PLA 0.332 0.000049 13,645,102
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2002 Annual Values

NH3 Emiss NH3 Rate Heat Input

FIPSST FIPSCNTY Plant ID Point ID ORISID BLRID Plant (Tons) (lbs/MMBtu) (MMBtu)

51 167 00003 2 3775 2 AMERICAN ELECTRIC POWER-CLINCH RIVER PLA 0.329 0.000046 14,295,031

51 167 00003 3 3775 3 AMERICAN ELECTRIC POWER-CLINCH RIVER PLA 0.358 0.000048 14,931,820

51 175 00051 1 10774 1 DOMINION - SOUTHAMPTON POWER STATION 0.043 0.000042 2,071,747

51 175 00051 2 10774 2 DOMINION - SOUTHAMPTON POWER STATION 0.043 0.000041 2,087,198

51 199 00001 3 3809 3 DOMINION - YORKTOWN POWER STATION 59.923 0.00465 25,772,283

51 550 00026 3 3803 3 DOMINION - CHESAPEAKE 0.246 0.000042 11,600,238

51 550 00026 4 3803 4 DOMINION - CHESAPEAKE 0.274 0.000043 12,880,910

51 760 00389 20 50966 1 DOMINION - BELLEMEADE 0.017 0.000013 2,576,299

51 760 00389 21 50966 2 DOMINION - BELLEMEADE 0.013 0.000011 2,382,091

54 023 0014 001 7537 1A NORTH BRANCH POWER STATION 0.050 0.000046 2,151,857

54 023 0014 002 7537 1B NORTH BRANCH POWER STATION 0.050 0.000047 2,150,507

54 039 0006 001 3936 1 APPALACHIAN POWER - KANAWHA RIVER PLANT 0.190 0.000029 13,080,072

54 039 0006 002 3936 2 APPALACHIAN POWER - KANAWHA RIVER PLANT 0.190 0.000031 12,412,111

54 051 0006 001 3947 1 OHIO POWER - KAMMER PLANT 0.180 0.000029 12,334,572

54 051 0006 002 3947 2 OHIO POWER - KAMMER PLANT 0.180 0.000032 11,149,675

54 051 0006 003 3947 3 OHIO POWER - KAMMER PLANT 0.180 0.000029 12,521,657

54 053 0001 001 3938 11 APPALACHIAN POWER CO.-PHILIP SPORN PLANT 0.250 0.000065 7,656,247

54 053 0001 002 3938 21 APPALACHIAN POWER CO.-PHILIP SPORN PLANT 0.240 0.000059 8,130,551

54 053 0001 003 3938 31 APPALACHIAN POWER CO.-PHILIP SPORN PLANT 0.260 0.000062 8,360,645

54 053 0001 004 3938 41 APPALACHIAN POWER CO.-PHILIP SPORN PLANT 0.240 0.000056 8,508,520

54 053 0001 005 3938 51 APPALACHIAN POWER CO.-PHILIP SPORN PLANT 0.480 0.000058 16,584,643