GEORGIA POWER - Submittal for PLANT WANSLEY

Electric Utility Steam Generating Unit (EGU) Hazardous Air Pollutant Emissions (HAPs) Information Collection Request (ICR), OMB Control No. 2060-0631

April 5, 2010

PART I: GENERAL FACILITY INFORMATION

Process Information

1 Name of legal owner of facility:

Georgia Power, Oglethorpe Power Corporation (OPC), Municipal Electric Authority of Georgia (MEAG), 

and Dalton Utilities (DU).

2 Name of legal operator of facility, if different from legal owner:

Georgia Power

3 Address of ____ legal owner or _X__ operator:

241 Ralph McGill Blvd NE, Bin 10221

Atlanta, GA 30308

4a Plant Name (as reported on U.S. DOE/EIA Form-860 (2007), "Annual Electric Generator Report", schedule 2, line 1, page 37, question 1)

OR Plant Name (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report", schedule 2, page 1, question 1):

Wansley

4b EIA Plant Code (as reported on U.S. DOE/EIA Form-860 (2007), schedule 2, line 1, page 37, question 2) OR Plant ID (as reported on U.S. 

DOE/EIA Form EIA-923 (2008), schedule 2, page 1, question 2):

6052

5 Complete street address of facility (physical location):

1371 Liberty Church Road

Carrollton, GA 30116-7343

6 Provide mailing address if different:

241 Ralph McGill Blvd NE, Bin 10221

Atlanta, GA 30308

7 Name and title of contact(s) able to answer technical questions about the completed survey:

Sarah Markham, Engineer II

8 Contact(s) telephone number(s):

(205) 257-6780

and e-mail address(es):

sasander@southernco.com

9 Is this facility considered to be owned or operated by a small entity as defined by the Regulatory Flexibility Act? 

____ Yes _X__ No ____ Don't know

Page 1 of 73 part I, 1-14
GEORGIA POWER - Submittal for PLANT WANSLEY

Electric Utility Steam Generating Unit (EGU) Hazardous Air Pollutant Emissions (HAPs) Information Collection Request (ICR), OMB Control No. 2060-0631

April 5, 2010

PART I: GENERAL FACILITY INFORMATION

10 Which of the following fossil fuels or other material(s) are fired in any steam generating unit at this facility?

_X__ coal __X__ oil (including pet coke) ___ natural gas

___ other (specify in question 14 below)

11 Which of the following fossil fuel or other material(s) are permitted1

 to be fired in any steam generating unit at this facility?

_X__ coal _X__ oil (including pet coke) ___ natural gas

_X__ other (specify in question 14 below)

12 If coal or solid fuel, as described below, derived from a fossil source is fired, indicate which rank of coal or solid fuel was utilized

during the previous 12 months prior to the receipt of this ICR:2,3

____ lignite (% _____) ____ subbituminous (% _____)

_X___ bituminous (% _100____) ____ anthracite (% _____)

____ coal refuse (including gob, culm, and subbituminous-derived coal refuse) (% _____)

____ synfuel (including, but not limited to, briquettes, pellets, or extrusions which are formed by binding materials, or processes

 that recycle materials) (%_____)

 (please specify the type or form of synfuel used ___________________________________________)

____ petroleum coke (% _____)

13 If oil is fired, indicate which type of oil was utilized during the previous 12 months prior to the receipt of this ICR:4

_X___ distillate (% _100____)

____ other (specify __________) (% _____)

____ residual or bunker C (% _____)

Page 2 of 73 part I, 1-14
GEORGIA POWER - Submittal for PLANT WANSLEY

Electric Utility Steam Generating Unit (EGU) Hazardous Air Pollutant Emissions (HAPs) Information Collection Request (ICR), OMB Control No. 2060-0631

April 5, 2010

PART I: GENERAL FACILITY INFORMATION

14a If "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited to, 

plastics, treated wood, rubber belting or gaskets, whole tires, tire-derived fuel, boiler cleaning solutions, animal wastes, etc.) is 

either utilized or permitted to be used, please indicate below what materials are combusted in the boiler and in what quantities

(specify whether this quantity is on a weight percentage or heat [Btu] basis). Also indicate (yes/no) whether you are permitted5 to 

burn non-fossil fuel(s) or other material(s) even if you do not actually burn them.

14b If "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited to,

plastics, treated wood, rubber belting or gaskets, whole tires, tire-derived fuel, boiler cleaning solutions, animal wastes, etc.) is 

either utilized or permitted to be used, were such material to be classified as "solid waste" under the Resource Conservation and 

Recovery Act and, thus make the utilizing unit subject to CAA section 129, would you continue to utilize (i.e., use as a fuel) the 

material? ____ Yes ____ No

Explain:

Until the regulations are finalized, we cannot determine with certainty whether we would use these other materials or not.

1

 "Permitted" in this context, refers to the fuels that the permit anticipates will be combusted at the facility.

2

 If the boiler is fired by a blend of coal ranks, please specify percentage (separately, on both a mass and on a Btu basis) of each coal rank

(e.g., 85% subbituminuous/15% bituminous).

3

 In reference to footnote 1, if necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting 

the reason the fuel type was combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research

purposes").

4

 If the boiler is fired by a blend of fuel oil ranks, please specify percentage (separately, on both a volume and on a Btu basis) of each

fuel oil rank (e.g., 85% residual oil/15% distillate).

5

 If necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting the reason the fuel was

combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research purposes").

Yes None in 2009

None in 2009

Synfuel None in 2009

Used Oil Yes None in 2009

Quantity/year

None in 2009

None in 2009

Actually burn

None in 2009

None in 2009

Other Material Permitted to burn

Sawdust

Biomass

Yes

Yes

Page 3 of 73 part I, 1-14
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

15 Identification (or designation) of all coal- and oil-fired steam generating units (boilers) (as defined by Clean Air Act section 112(a)(8))

located at this facility.

SEE NOTES BELOW for explanations of responses. Boiler ID

6

coal rank or type of oil)

Original design fuel (i.e., 

Design heat input, 

(MMBtu/hr)

7

Present maximum heat 

input, (MMBtu/hr)

8

MWe Gross capacity

summer

MWe Net Capacity

summer

Original design gross 

efficiency (%, HHV)

Present operating gross 

efficiency (%, HHV)

Design steam pressure 

(psig)

Operating steam pressure 

(psig)

Design steam temperature 

(

oF)

temperature (

Operating steam 

oF)

Design steam reheat 

temperature (

oF)

9

Operating steam reheat 

temperature (

oF)10

Fuel11

Hours/year operated12

Average annual capacity 

factor for the past 3 years

Applicable NSPS

Estimated year of 

retirement13

1 bituminous CBI CBI 920 858 88.7 88.89 3500 3501 1000 998 1000 987 bituminous coal (100%), distillate 

oil (100%)

CBI CBI Not 

applicable

None 

planned

2 bituminous CBI CBI 920 858 88.7 89.42 3500 3500 1000 994 1000 970 bituminous coal (100%), distillate 

oil (100%)

CBI CBI Not 

applicable

None 

planned

6

 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

7

 Per fuel burned in the boiler. Report this based on higher heating value (HHV).

8

 Per fuel burned in the boiler. Report this based on higher heating value (HHV).

9

 Please indicate if more than one steam reheat cycle is utilized, and, if so, please provide information for both.

10 Please indicate if more than one steam reheat cycle is utilized, and, if so, please provide information for both.

11 Indicate the fuels utilized for the indicated boiler, and percentages, as indicated in questions 11 - 13.

12 The "hours/year operated" would be the average of the actual number of hours the unit operated in 1 year based on the last 3 years of operation.

13 This can be treated as CBI and can be submitted through the proper CBI procedure if desired.

NOTES: Original Design Fuel

Based on the original contract boiler data sheet; only the primary fuel is listed if multiple fuels were included on the data sheet. 

Design Heat Input

Confidential Business Information

Present Maximum Heat Input

Confidential Business Information

MWe Gross Capacity Summer

Identifies the gross normal full load. Georgia Power does not change unit capacities season from season. 

MWe Net Capacity Summer

Identifies the net normal full load; taken directly from the 2010 installed and authorized document. Georgia Power does not change unit capacities from season to season. 

Original Design Gross Efficiency

Taken directly from the original contract boiler data sheet.

Present Operating Gross Efficiency 

Based on the most recent actual test of the boiler efficiency, unless no recent boiler efficiency test was available. Where no recent test was available, that status is indicated. 

Page 4 of 73 part I, 15
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

15 Identification (or designation) of all coal- and oil-fired steam generating units (boilers) (as defined by Clean Air Act section 112(a)(8))

located at this facility.

SEE NOTES BELOW for explanations of responses. Boiler ID

6

coal rank or type of oil)

Original design fuel (i.e., 

Design heat input, 

(MMBtu/hr)

7

Present maximum heat 

input, (MMBtu/hr)

8

MWe Gross capacity

summer

MWe Net Capacity

summer

Original design gross 

efficiency (%, HHV)

Present operating gross 

efficiency (%, HHV)

Design steam pressure 

(psig)

Operating steam pressure 

(psig)

Design steam temperature 

(

oF)

temperature (

Operating steam 

oF)

Design steam reheat 

temperature (

oF)

9

Operating steam reheat 

temperature (

oF)10

Fuel11

Hours/year operated12

Average annual capacity 

factor for the past 3 years

Applicable NSPS

Estimated year of 

retirement13

Design Steam Pressure

Based on the thermal design of the unit as represented on the turbine heat balance sheet. 

Operating Steam Pressure

Represents the average throttle pressure when the unit operated at gross normal full load over a three year period (January 2007 to December 2009). 

Design Steam Temperature

Based on the thermal design of the unit as represented on the turbine heat balance sheet. 

Operating Steam Temperature 

Represents the average steam temperature when the unit operated at gross normal full load over a three year period (January 2007 to December 2009). 

Design Steam Reheat Temperature 

Based on the thermal design of the unit as represented on the turbine heat balance sheet. 

Operating Steam Reheat Temperature

Represents the average reheat steam temperature when the unit operated at gross normal full load over a three year period (January 2007 to December 2009). 

Fuel

Indicates the fuels burned in the previous calendar year (January to December 2009). 

Hours/Year Operated

Confidential Business Information

Annual Average Capacity Factor for the Past 3 Years

Confidential Business Information

Applicable NSPS

Where no NSPS is identified, the unit is not currently subject to any NSPS.

Retirement Year

Georgia Power and Plant Wansley co-owners have not committed to actual retirement dates for Units 1-2. Georgia Power continually evaluates retirement scenarios with respect to its generating units for a variety 

of planning purposes, taking into account a wide range of variables. While the company assumes financial "retirement dates" for accounting purposes, for example, for depreciation schedules or for FERC or 

Public Service Commission uses, these dates are not indicative of the unit's actual retirement date.

Page 5 of 73 part I, 15
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

16 For each boiler noted in Part I, question 15, provide the following information for each current emission control device installed

and operating and/or planned (please designate the order of the emission controls - 1 for the first control following the boiler, 2

for the second control following the boiler, etc.):

NOTES: SO3/NH3 flue gas conditioning systems and hydrated lime systems are operated on an as-needed basis.

SCR catalyst: When making catalyst decisions, the primary goal is to achieve the desired NOx performance, with a 

secondary goal of minimizing SO3 formation.

Boiler ID14 Type15 NOx control16 SO2 control17 PM control18 Other control19

1 tangential-fired (1) low-NOX concentric firing 

system + separated overfire 

air (5/1993)

(2) SCR (5/2003); titaniavanadia catalyst and 

anhydrous ammonia 

reductant; the catalyst is 

designed to minimize SO3 

formation (SEE NOTES).

(7) wet flue gas 

desulfurization (FGD) 

(12/2008), calcium-based.

(5) cold-side electrostatic 

precipitator (ESP) (12/1976, 

original install)

(3) flue gas conditioning - SO3 

injection (4/1993)

(6) hydrated lime injection 

(SO3 control, 7/2009)

(4) flue gas conditioning - 

ammonia (SO3 control, 

4/2004)

2 tangential-fired (1) low-NOX concentric firing 

system + separated overfire 

air (4/1994)

(2) SCR (5/2003), titaniavanadia catalyst and 

anhydrous ammonia 

reductant; the catalyst is 

designed to minimize SO3 

formation (SEE NOTES).

(7) wet flue gas 

desulfurization (FGD) 

(5/2009), calcium-based.

(5) cold-side electrostatic 

precipitator (ESP) (4/1978, 

original install)

(3) flue gas conditioning - SO3 

injection (4/1993)

(6) hydrated lime injection 

(SO3 control, 7/2009)

(4) flue gas conditioning - 

ammonia (SO3 control, 

4/2004)

14 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

15 Examples: tangential-fired; cyclone; wall-fired; circulating fluidized bed (CFB)

16 Examples: low-NOx burners; selective catalytic reduction (SCR); selective non-catalytic reduction (SNCR); over-fire air (OFA). Include

specific date that control went online or planned operational date for new installation. If this boiler's control configuration utilizes a SCR,

please include the type of material from which the catalyst is manufactured and the type of reductant used in with the SCR (e.g., anhydrous

Page 6 of 73 part I, 16
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

16 For each boiler noted in Part I, question 15, provide the following information for each current emission control device installed

and operating and/or planned (please designate the order of the emission controls - 1 for the first control following the boiler, 2

for the second control following the boiler, etc.):

NOTES: SO3/NH3 flue gas conditioning systems and hydrated lime systems are operated on an as-needed basis.

SCR catalyst: When making catalyst decisions, the primary goal is to achieve the desired NOx performance, with a 

secondary goal of minimizing SO3 formation.

Boiler ID14 Type15 NOx control16 SO2 control17 PM control18 Other control19

ammonia, urea, other). Also, please note if the catalyst is specifically designed to reduce SO3 formation?

17 Examples: wet flue gas desulfurization (FGD; any type); dry scrubbing (any type); specify whether calcium- or sodium-based. Include 

specific date that control went online or planned operational date for new installation. 

18 Examples: fabric filter; cold-side electrostatic precipitator (ESP); hot-side ESP; cyclone or multiclone; venturi scrubber. Include specific

date that control went online or planned operational date for new installation.

19 Please indicate systems installed specifically to control any other pollutants (e.g., Hg, SO3, etc.). Examples: activated carbon injection (ACI);

Powerspan ECO®; dry sorbent injection or wet ESP for SO3 control; flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other);

additive use for mercury control (e.g., bromine; scrubber additives). Include specific date that control went online or planned operational date for 

new installation. Also include any pollutants controlled by this technology (e.g., control technology [pollutant controlled]).

Page 7 of 73 part I, 16
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

17 For each boiler noted in Part I, question 15, provide the company (prime vendor) name and company contact information for each

HAP-specific (e.g., mercury, hydrogen chloride) control technology that you have either contracted for, are installing, or have installed

for the purpose of participating in a control technology demonstration project20 (e.g., U.S. Department of Energy program, consent decree,

etc.).

Name Telephone Address

1 Not applicable Not applicable Not applicable Not applicable

2 Not applicable Not applicable Not applicable Not applicable

20 A control technology demonstration project is defined as a U.S. Government (e.g., U.S. Department of Energy program) sponsored

(in whole or in part) project or mandate (e.g., as a result of a consent decree) that adds a HAP control technology to a facility's unit to

demonstrate the technology's HAP removal performance.

21 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

Company (vendor) contact information Boiler ID21 Company (vendor) name

Page 8 of 73 part I, 17
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

18 For the control technologies identified in Part I, question 17, provide the date of actual start-up of the demonstration (if the control

is currently operating), the date of expected or projected start-up, the date the demonstration was completed, the type of HAP

control installed (e.g., sorbent and type; pre-combustion boiler chemical additive; combustion boiler chemical additive), the desired

HAP emission reduction or rate (if any), and the coal rank(s) upon which the demonstration was conducted. Please specify the format 

of the target HAP emission reduction rate (e.g., lb/MWh, lb/TBtu, percent reduction, etc.). If the format of the target end-point is

percent reduction, provide (1) an estimate of what an equivalent emission rate would be (and specify the format of the equivalent

emission rate), and (2) the basis for calculating the percent reduction (i.e., where the "inlet" and "outlet" are).

Boiler ID22

Demonstration 

activity actual startup date

Demonstration 

activity projected 

start-up date

Demonstration 

activity end-date or 

projected end-date

Type of control (e.g., 

sorbent and type; 

chemical additive23)

Desired HAP 

emission reduction 

(%) or emission rate

Coal rank(s) in use

1 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

2 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

22 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

23 If additive is used, please indicate injection point.

Page 9 of 73 part I, 18
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

19 For each boiler noted in Part I, question 15, provide the company (prime vendor) name and company contact information for each

HAP (e.g., mercury, hydrogen chloride, etc.) control technology that you have either contracted for, are installing, or have installed

for the purpose of provide a non-demonstration, full-scale operating system.

Name Telephone Address

1 Not applicable Not applicable Not applicable Not applicable

2 Not applicable Not applicable Not applicable Not applicable

24 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

Company (vendor) contact information

Boiler ID24 Company (vendor) name

Page 10 of 73 part I, 19
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

20 For the control technologies identified in Part I, question 19, provide the date of actual start-up (if the control is currently operating), the

date of expected or projected start-up, the type of HAP control installed (e.g., sorbent and type; pre-construction boiler chemical additive;

combustion of boiler chemical additive), the guaranteed HAP emission reduction or emission rate, the sorbent feed rate upon which the 

guarantee is based, and the coal rank(s) upon which the guarantee is based. Please specify the format of the guarantee (e.g., lb/MWh,

lb/TBtu, percent reduction, etc.). If the format of the guarantee is percent reduction, provide (1) an estimate of what an equivalent emission

rate would be (and specify the format of the equivalent emission rate), and (2) the basis for calculating the percent reduction (i.e., where the

"inlet" and "outlet" are).

Boiler 

ID25 Actual start-up date Expected or projected 

start-up date

Type of control (e.g., 

sorbent and type; 

chemical additive)26

Guaranteed HAP 

emission reduction 

(%) or emission rate

Sorbent or additive 

feed rate on which 

guarantee is based

Coal rank(s) upon 

which guarantee is 

based

1 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

2 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

25 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

26 If additive is used, please indicate injection point.

Page 11 of 73 part I, 20
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

21 For each boiler noted in Part I, question 15, provide the following information:

PM28 PM10

(29) PM2.5(30) SO2

HCl 

and/or HF HCN

Metal 

HAP31 Hg CO

Other 

organics 

(specify)

Other pollutant (specify)

1 0.24 lb/MMBtu (Title V permit; based on 3-run 

stack test using Method 5 or 17; test required 

once every permit cycle on scrubber stack, once 

every 5 years or operating 8760 hours, 

whichever first, on bypass stack)

Not 

applicable

Not 

applicable

3% fuel sulfur content (Title V permit; based on 

analysis of coal sample acquired for each 

operating day and supplier certification 

statement for No. 2 oil)

5% of potential combustion concentration (95% 

removal by FGD), effective Jan 1, 2010 (State 

rule, Title V permit revision not complete; based 

on 30-day rolling average, monitored by CEMS 

at inlet to scrubber and at scrubber stack during 

scrubber operations, excluding startup, 

shutdown, malfunction, and other exemptions)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

NOx: 0.07 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

lb/MMBtu (Title V permit; based on 30-day 

rolling averages determined by CEMS)

Southern Company Phase II NOx Averaging Plan 

limit of 0.46 lb/MMBtu (average of all units) 

(Phase II NOx Compliance Plan; based on annual 

average determined by CEMS)

2 0.24 lb/MMBtu (Title V permit; based on 3-run 

stack test using Method 5 or 17; test required 

once every permit cycle on scrubber stack, once 

every 5 years or operating 8760 hours, 

whichever first, on bypass stack)

Not 

applicable

Not 

applicable

3% fuel sulfur content (Title V permit; based on 

analysis of coal sample acquired for each 

operating day and supplier certification 

statement for No. 2 oil)

5% of potential combustion concentration (95% 

removal by FGD), effective Jan 1, 2010 (State 

rule, Title V permit revision not complete; based 

on 30-day rolling average, monitored by CEMS 

at inlet to scrubber and at scrubber stack during 

scrubber operations, excluding startup, 

shutdown, malfunction, and other exemptions)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

NOx: 0.07 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

lb/MMBtu (Title V permit; based on 30-day 

rolling averages determined by CEMS)

Southern Company Phase II NOx Averaging Plan 

limit of 0.46 lb/MMBtu (average of all units) 

(Phase II NOx Compliance Plan; based on annual 

average determined by CEMS)

27 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

28 If the boiler has separate permitted emission limits for filterable and condensable PM, respectively, please indicate those separate limits. 

Also include the compliance test method utilized.

29 List the compliance test method utilized.

30 List the compliance test method utilized.

31 Metal HAP include compounds of antimony, arsenic, beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, phosphorus, and selenium;

indicate permit level for all metal HAP for which a permit level has been developed.

Permitted emission limit (indicate type of permit and format of emission limit)

Boiler ID27

Page 12 of 73 part I, 21
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

22 For each boiler noted in Part I, question 15, provide the following information:

NOTES: All guarantees are based on and demonstrated with certain fuel and operating conditions. Guarantees are not necessarily representative of the long term or day to day

variability that may occur with changes in fuel specifications, operating conditions, normal wear and tear of equipment over time, startups, shutdowns, and malfunctions.

Scrubbers (FGD): Values shown for the scrubbers below are not vendor guaranteed rates, but are the performance expectations for the FGD provided by our internal engineering group. 

Like vendor guarantees, these performance expectations are dependent on specific operating conditions. 

PM33 PM10 PM2.5 SO2

HCl 

and/or HF HCN

Metal 

HAP34 Hg CO

Other 

organics 

(specify)

Other pollutant (specify)

1 ESP rebuild: 0.07 lb/MMBtu filterable (expired in 

2006)

Not 

applicable

Not 

applicable

FGD: 98% instantaneous removal efficiency to 

meet a 95% 30-day rolling average removal 

efficiency (SEE NOTES)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Low NOx Burners: 0.45 lb/MMBtu (expiration in 

1994)

2 ESP: 99.12 % collection efficiency filterable 

(expired in 1978)

Not 

applicable

Not 

applicable

FGD: 98% instantaneous removal efficiency to 

meet a 95% 30-day rolling average removal 

efficiency (SEE NOTES)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not applicable

23 Was any other guarantee level sought or offered? ____ Yes _X___ No

Please elaborate.

32 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

33 If the boiler has separate guaranteed emission rate for filterable and condensable PM, respectively, please indicate those separate emission rates.

34 Metal HAP include compounds of antimony, arsenic, beryllium, cadmium, cobalt, lead, manganese, nickel, phosphorus, and selenium; 

indicate permit level for all metal HAP for which a permit level has been developed.

Most recent guaranteed emission rate for each pollutant for which there is a permitted emission limit

Boiler ID32

Page 13 of 73 part I, 22-23
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

24 For each boiler noted in Part I, question15, provide the following information:

PM36 PM10 PM2.5 SO2

HCl 

and/or HF HCN

Metal 

HAP37 Hg CO

Other 

organics 

(specify)

1 Scrubber stack: Stack test performed once during each permit cycle or as requested by 

GA EPD; under the CAM plan, sparger tube submergence level monitored continuously, 

excursions (3-hour block averages less than 5 inches) reported quarterly. 

Bypass stack: Stack test performed within 30 days following 8760 operating hours or 

every 5 years, whichever comes first; under the CAM plan, opacity monitored 

continuously by COMS, excursions (3-hour block averages greater than 40%) reported 

quarterly.

The facility shall submit 30-day advance notifications of required testing and test reports 

within 60 days of completion of the testing.

All records related to the Title V permit are retained for five years.

Not 

applicable

Not 

applicable

Coal sulfur content monitored through daily coal sampling; 

fuel oil sulfur content monitored through vendor 

certification; exceedances of 3% limit reported quarterly; 

records retained for 5 years.

SO2 removal by the scrubber will be monitored by inlet and 

stack SO2 CEMS operated, maintained, and certified using 40 

CFR Part 75 procedures. Data from these monitors will 

provide the SO2 removal percentage on a 30-day rolling 

average, excluding startup, shutdown, and malfunction. 

Exceedances of the 5% limit will be reported quarterly; 

records retained for 5 years (permit revision not yet issued).

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

2 Scrubber stack: Stack test performed once during each permit cycle or as requested by 

GA EPD; under the CAM plan, sparger tube submergence level monitored continuously, 

excursions (3-hour block averages less than 5 inches) reported quarterly. 

Bypass stack: Stack test performed within 30 days following 8760 operating hours or 

every 5 years, whichever comes first; under the CAM plan, opacity monitored 

continuously by COMS, excursions (3-hour block averages greater than 40%) reported 

quarterly.

The facility shall submit 30-day advance notifications of required testing and test reports 

within 60 days of completion of the testing.

All records related to the Title V permit are retained for five years.

Not 

applicable

Not 

applicable

Coal sulfur content monitored through daily coal sampling; 

fuel oil sulfur content monitored through vendor 

certification; exceedances of 3% limit reported quarterly; 

records retained for 5 years.

SO2 removal by the scrubber will be monitored by inlet and 

stack SO2 CEMS operated, maintained, and certified using 40 

CFR Part 75 procedures. Data from these monitors will 

provide the SO2 removal percentage on a 30-day rolling 

average, excluding startup, shutdown, and malfunction. 

Exceedances of the 5% limit will be reported quarterly; 

records retained for 5 years (permit revision not yet issued).

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

35 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

36 If the boiler's monitoring, recordkeeping, and reporting requirements require your company to monitoring, keep records, and report filterable

and condensable PM separately, please describe the separate actions required.

37 Metal HAP include compounds of antimony, arsenic, beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, phosphorus, and selenium;

indicate permit level for all metal HAP for which a permit level has been developed.

Required monitoring, recordkeeping, and reporting requirements for each pollutant for which there is a permitted emission limit

Boiler ID35

Page 14 of 73 part I, 24
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

25 For the control technologies identified in Part I, questions 17 and 19, provide the cost information requested.38

Facility Name/Unit No.: Not applicable

Retrofit to existing boiler? Not applicable

Installation on a new boiler? Not applicable

Total Capital Investment: $ -

Total Annual Operating and Maintenance Costs: $ - (Include base year for operating costs [e.g., 2006]

26 Are any other means of emission control (for any pollutant) employed on any boiler noted in Part I, question 15 (e.g., low-ash coal,

coal or oil with low trace constituents, etc.)? Please specify.

No.

38 This can be treated as CBI and can be submitted through the proper CBI procedure if desired.

Page 15 of 73 part I, 25-26
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

PART II: FUEL ANALYSIS AND EMISSION DATA

Fuel Analysis39

1a Plant or facility name from Part I, question 4a: 

Wansley

1b Plant or facility code from Part I, question 4b:

6052

39 The respondent should reply to this ICR with separate pages 18 through 24 (Part II) for each of their facilities.

Page 16 of 73 part II, 1
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

12,038 1, 2 VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, 

SPLASHDAM TRAIN 1.19 10.83 13,758

12,179 1, 2 VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, 

SPLASHDAM TRAIN 1.23 12.62 13,455

12,244 1, 2 VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, 

SPLASHDAM TRAIN 1.38 12.89 13,438

12,173 1, 2 VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, 

SPLASHDAM TRAIN 1.28 10.44 13,804

12,047 1, 2 VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, 

SPLASHDAM TRAIN 1.42 13.11 13,288

12,092 1, 2 VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, 

SPLASHDAM TRAIN 1.47 9.56 13,879

10,043 1, 2 COLOMBIA N/A GRAN MADRE TRAIN 0.64 5.93 13,119

10,207 1, 2 COLOMBIA N/A GRAN MADRE TRAIN 0.54 5.69 13,166

9,996 1, 2 COLOMBIA N/A GRAN MADRE TRAIN 0.52 6.14 13,072

9,964 1, 2 COLOMBIA N/A GRAN MADRE TRAIN 0.53 5.68 13,110

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

Page 17 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

9,691 1, 2 COLOMBIA N/A GRAN MADRE TRAIN 0.54 5.27 13,219

6,274 1, 2 COLOMBIA N/A GRAN MADRE TRAIN 0.52 5.82 13,126

11,723 1, 2 WV MINGO COALBURG, STOCKTON TRAIN 0.95 13.04 13,149

11,909 1, 2 WV MINGO COALBURG, STOCKTON TRAIN 0.83 13.39 13,089

11,871 1, 2 WV MINGO COALBURG, STOCKTON TRAIN 0.73 13.12 13,063

11,805 1, 2 WV MINGO COALBURG, STOCKTON TRAIN 0.78 14.13 12,838

11,830 1, 2 WV MINGO COALBURG, STOCKTON TRAIN 0.75 13.62 12,980

11,981 1, 2 WV MINGO COALBURG, STOCKTON TRAIN 0.91 13.58 12,996

11,577 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.84 11.6 13,100

11,761 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.9 11.73 13,029

11,907 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.91 12.47 12,880

11,732 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.84 9.93 13,355

Page 18 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,496 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.87 11.46 13,187

11,704 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.82 11.6 13,013

11,910 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.93 12.82 12,914

11,730 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.84 10.64 13,290

11,805 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.82 10.1 13,362

11,739 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.8 9.48 13,429

11,900 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.86 8.41 13,590

Page 19 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,536 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.87 9.51 13,432

11,831 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.85 10.38 13,290

11,320 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.95 10.98 13,191

11,737 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.94 9.57 13,405

11,591 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.89 9.18 13,491

11,608 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.84 10.74 13,257

12,087 1, 2 VA WISE

IMBODEN, LOW SPLINT, 

TIGER TRAIN 0.9 12.18 13,456

12,088 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.94 11.57 13,448

Page 20 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,982 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.95 14.55 13,111

11,877 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.99 12.14 13,471

12,010 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.02 12.59 13,298

12,068 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.01 14.75 13,069

12,016 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.97 14.52 13,043

12,033 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.96 12.07 13,482

12,011 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.89 11.94 13,516

12,133 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.01 12.15 13,422

12,077 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.95 13.02 13,330

12,053 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.94 11.88 13,490

Page 21 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

12,032 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.93 11.54 13,548

12,027 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.9 12.25 13,457

12,022 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.84 12.88 13,374

12,195 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.84 12.84 13,356

12,008 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.9 12.71 13,379

12,022 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.94 12.99 13,335

12,015 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.96 13.13 13,312

12,057 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.93 12.18 13,392

12,038 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1 13.24 13,256

11,936 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.85 11.39 13,580

Page 22 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,983 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.91 11.97 13,491

11,903 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.04 13.15 13,303

12,058 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.15 13.73 13,057

12,053 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.84 12.13 13,439

12,022 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.86 13.47 13,239

12,058 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.87 12.12 13,487

12,056 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.95 12.59 13,344

12,231 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.97 12.52 13,326

12,093 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.03 11.79 13,499

12,091 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.16 12.77 13,332

Page 23 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

12,132 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.01 13.18 13,283

12,087 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.95 12.81 13,343

12,032 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.91 13.94 13,159

12,090 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.97 13.33 13,224

12,125 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.98 12.13 13,391

12,087 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.98 12.82 13,302

9,888 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.96 13.58 13,193

11,858 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.97 13.55 13,200

11,983 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.92 12.95 13,284

12,234 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.9 13.31 13,228

Page 24 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

12,106 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.87 12.27 13,484

12,206 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.91 12.81 13,328

12,032 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.94 12.42 13,351

11,919 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.89 10.83 13,682

12,053 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.91 12.77 13,363

12,137 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.93 12.63 13,311

12,057 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.88 13.44 13,192

11,983 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.01 12.84 13,337

12,075 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.96 12.43 13,387

11,991 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1.01 12.1 13,397

Page 25 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,992 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1 12.39 13,367

12,047 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.97 13.93 13,068

12,093 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.97 13.31 13,253

11,993 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.98 11.92 13,445

12,144 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.93 12.71 13,372

12,045 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.96 11.35 13,570

11,958 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.87 12.06 13,432

12,043 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.99 12.99 13,294

12,061 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.95 12.46 13,422

12,139 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 1 12.85 13,350

12,019 1, 2 VA LEE PARSON TRAIN 0.95 11.98 13,377

Page 26 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,575 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.2 10.23 13,672

11,484 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.08 11.04 13,581

11,363 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.12 11.93 13,453

Page 27 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,589 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.14 11.01 13,514

11,523 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.18 10.5 13,619

11,862 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.17 11.68 13,543

Page 28 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,681 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.18 12 13,443

11,544 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.11 11.26 13,566

11,598 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.2 10.81 13,626

Page 29 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,538 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, EAGLE, 

ELKHORN 1, 2, 3, 

GLAMORGAN, HAGY, 

RIDER 3.5, SPLASHDAM TRAIN 1.25 10.52 13,702

10,304 1, 2 KY, VA HARLAN, LEE

CREECH, DARBY, 

HARLAN, KELLIOKA TRAIN 0.95 10.88 13,459

10,465 1, 2 KY, VA HARLAN, LEE

CREECH, DARBY, 

HARLAN, KELLIOKA TRAIN 1.08 12.08 13,216

10,325 1, 2 KY, VA HARLAN, LEE

CREECH, DARBY, 

HARLAN, KELLIOKA TRAIN 1.32 11.63 13,318

9,537 1, 2 KY, VA HARLAN, LEE

CREECH, DARBY, 

HARLAN, KELLIOKA TRAIN 1.43 12.36 13,245

9,851 1, 2 KY, VA HARLAN, LEE

CREECH, DARBY, 

HARLAN, KELLIOKA TRAIN 1.22 12.42 12,957

10,259 1, 2 KY, VA HARLAN, LEE

CREECH, DARBY, 

HARLAN, KELLIOKA TRAIN 1.2 10.68 13,539

9,765 1, 2 KY, VA HARLAN, LEE

CREECH, DARBY, 

HARLAN, KELLIOKA TRAIN 1.14 10.11 13,622

11,783 1, 2 N/A N/A TAYLOR TRAIN 0.89 14.59 12,963

11,593 1, 2 N/A N/A TAYLOR TRAIN 0.87 12.56 13,156

Page 30 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,212 1, 2 WV MINGO

5A, #2 GAS, CEDAR 

GROVE TRAIN 0.78 15.08 12,739

11,603 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.06 7.59 13,807

11,624 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 0.97 8.85 13,555

9,835 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.51 11.39 13,153

10,603 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.05 6.57 13,968

11,530 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.22 7.51 13,807

9,856 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.16 12.02 13,104

10,139 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.37 11.42 13,111

9,972 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.37 6.17 14,069

11,185 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.2 10.66 13,273

9,826 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.33 10.81 13,249

10,936 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 0.99 7.43 13,595

6,921 1, 2 IN GIBSON INDIANA #5 TRAIN 1.04 6.51 13,749

Page 31 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

6,943 1, 2 IN GIBSON INDIANA #5 TRAIN 1.03 6.44 13,749

7,156 1, 2 IN GIBSON INDIANA #5 TRAIN 1.07 6.41 13,742

7,268 1, 2 IN GIBSON INDIANA #5 TRAIN 1.13 6.74 13,664

7,436 1, 2 IN GIBSON INDIANA #5 TRAIN 1.15 6.63 13,738

7,001 1, 2 IN GIBSON INDIANA #5 TRAIN 1.08 6.72 13,723

6,941 1, 2 IN GIBSON INDIANA #5 TRAIN 1.21 6.89 13,668

6,950 1, 2 IN GIBSON INDIANA #5 TRAIN 1.24 6.94 13,656

7,045 1, 2 IN GIBSON INDIANA #5 TRAIN 1.31 7.02 13,638

6,906 1, 2 IN GIBSON INDIANA #5 TRAIN 1.25 7.13 13,607

6,980 1, 2 IN GIBSON INDIANA #5 TRAIN 1.25 7.65 13,599

6,930 1, 2 IN GIBSON INDIANA #5 TRAIN 1.22 7.33 13,597

7,009 1, 2 IN GIBSON INDIANA #5 TRAIN 1.31 7.02 13,693

6,931 1, 2 IN GIBSON INDIANA #5 TRAIN 1.28 7.01 13,624

6,990 1, 2 IN GIBSON INDIANA #5 TRAIN 1.35 6.93 13,668

7,025 1, 2 IN GIBSON INDIANA #5 TRAIN 1.4 7.6 13,540

6,880 1, 2 IN GIBSON INDIANA #5 TRAIN 1.37 6.59 13,666

7,099 1, 2 IN GIBSON INDIANA #5 TRAIN 1.37 7.02 13,620

7,089 1, 2 IN GIBSON INDIANA #5 TRAIN 1.36 7.08 13,602

6,931 1, 2 IN GIBSON INDIANA #5 TRAIN 1.38 7.5 13,575

7,015 1, 2 IN GIBSON INDIANA #5 TRAIN 1.39 7.18 13,602

6,898 1, 2 IN GIBSON INDIANA #5 TRAIN 1.35 7.43 13,532

7,073 1, 2 IN GIBSON INDIANA #5 TRAIN 1.47 7.5 13,535

Page 32 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

7,033 1, 2 IN GIBSON INDIANA #5 TRAIN 1.58 7.56 13,553

7,080 1, 2 IN GIBSON INDIANA #5 TRAIN 1.72 7.66 13,477

7,005 1, 2 IN GIBSON INDIANA #5 TRAIN 1.5 7.34 13,477

7,107 1, 2 IN GIBSON INDIANA #5 TRAIN 1.57 7.25 13,567

6,977 1, 2 IN GIBSON INDIANA #5 TRAIN 1.47 8.31 13,470

6,953 1, 2 IN GIBSON INDIANA #5 TRAIN 1.34 7.8 13,540

7,086 1, 2 IN GIBSON INDIANA #5 TRAIN 1.38 8.49 13,414

7,050 1, 2 IN GIBSON INDIANA #5 TRAIN 1.28 7.04 13,589

6,979 1, 2 IN GIBSON INDIANA #5 TRAIN 1.34 7.32 13,550

6,995 1, 2 IN GIBSON INDIANA #5 TRAIN 1.31 7.1 13,375

6,911 1, 2 IN GIBSON INDIANA #5 TRAIN 1.29 7.2 13,597

6,941 1, 2 IN GIBSON INDIANA #5 TRAIN 1.37 7.25 13,615

6,929 1, 2 IN GIBSON INDIANA #5 TRAIN 1.33 7.63 13,740

11,885 1, 2 KY PIKE ALMA TRAIN 1.38 9.64 13,381

11,899 1, 2 KY PIKE ALMA TRAIN 1.61 8.76 13,514

11,762 1, 2 KY PIKE ALMA TRAIN 1.7 8.79 13,500

11,891 1, 2 KY PIKE ALMA TRAIN 1.32 8.63 13,528

11,660 1, 2 KY PIKE ALMA TRAIN 1.55 8.37 13,542

11,953 1, 2 KY PIKE ALMA TRAIN 1.76 9.33 13,466

11,905 1, 2 KY PIKE ALMA TRAIN 1.56 9.4 13,425

11,813 1, 2 KY PIKE ALMA TRAIN 1.53 10.34 13,234

11,860 1, 2 KY PIKE ALMA TRAIN 1.44 8.29 13,583

Page 33 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,735 1, 2 KY PIKE ALMA TRAIN 1.39 9.74 13,407

11,662 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.78 12.15 13,409

11,849 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.76 12.87 13,154

12,105 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.71 11.39 13,381

11,920 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 1.02 11.24 13,383

11,799 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.78 11.82 13,287

11,882 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.75 12.07 13,273

11,890 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.79 9.78 13,737

Page 34 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,981 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.74 11.63 13,395

9,987 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.79 11.12 13,219

11,811 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.83 11.85 13,280

11,580 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.75 11.08 13,485

11,900 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.9 11.49 13,361

11,952 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.8 12.25 13,195

12,178 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 1.06 11.27 13,422

Page 35 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,631 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.86 11.4 13,327

11,078 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 0.99 11.82 13,400

11,380 1, 2 KY PIKE

ALMA, ELKHORN, 

ELKHORN #2, ELKHORN 

#3 TRAIN 1.04 12.97 13,183

11,123 1, 2 WV WAYNE WINIFREDE TRAIN 0.89 10.58 13,218

11,058 1, 2 WV WAYNE WINIFREDE TRAIN 0.89 10.53 13,257

11,077 1, 2 WV WAYNE WINIFREDE TRAIN 0.89 10.15 13,338

11,359 1, 2 WV WAYNE WINIFREDE TRAIN 0.87 9.88 13,348

11,121 1, 2 WV WAYNE WINIFREDE TRAIN 0.93 10.94 13,219

11,436 1, 2 WV WAYNE WINIFREDE TRAIN 0.96 10.63 13,232

11,268 1, 2 WV WAYNE WINIFREDE TRAIN 1.02 10.19 13,235

11,103 1, 2 WV WAYNE WINIFREDE TRAIN 0.93 10.88 13,179

11,216 1, 2 WV WAYNE WINIFREDE TRAIN 0.96 10.47 13,252

11,116 1, 2 WV WAYNE WINIFREDE TRAIN 0.94 10.62 13,216

10,105 1, 2 WV WAYNE WINIFREDE TRAIN 0.9 11.6 13,033

11,042 1, 2 WV WAYNE WINIFREDE TRAIN 0.92 11.1 13,131

11,724 1, 2 WV WAYNE WINIFREDE TRAIN 0.96 10.79 13,170

Page 36 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,191 1, 2 WV WAYNE WINIFREDE TRAIN 0.96 10.7 13,177

11,305 1, 2 WV WAYNE WINIFREDE TRAIN 0.9 10.92 13,189

11,153 1, 2 WV WAYNE WINIFREDE TRAIN 0.94 11.55 13,103

11,113 1, 2 WV WAYNE WINIFREDE TRAIN 0.91 11.22 13,055

11,180 1, 2 WV WAYNE WINIFREDE TRAIN 0.86 10.69 13,174

11,814 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.92 14.11 12,920

11,478 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.86 12.89 13,135

11,449 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.9 11.66 13,336

11,720 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.9 12.57 13,237

11,596 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.96 12.91 13,140

9,767 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.94 12.34 13,246

11,707 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.83 10.88 13,411

11,409 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.91 11.92 13,262

Page 37 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

10,960 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.81 13.92 12,940

10,789 1, 2 KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.92 12.38 13,166

12,244 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.64 11.12 13,462

11,982 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.72 12.59 13,207

12,128 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.73 13.09 13,172

11,987 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.68 12.02 13,285

12,053 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.8 12.39 13,251

12,072 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 1.1 12.87 13,122

9,972 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 1.01 12.13 13,205

0 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.76 12.49 13,261

10,792 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.76 12.49 13,261

10,854 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.87 12.14 13,247

10,505 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.92 12.18 13,325

12,132 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.75 13.15 13,015

11,603 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.71 12.18 13,228

10,618 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.75 12.18 13,192

12,096 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.66 11.36 13,426

12,040 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.77 13.66 12,972

12,082 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.8 12.94 13,253

11,644 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.7 11.59 13,287

Page 38 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,757 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.72 13.26 13,089

11,892 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.78 12.1 13,289

11,934 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.75 12.4 13,222

11,854 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 1.02 12.66 13,155

12,030 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 1.02 12.69 13,205

11,987 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.84 12.72 13,150

10,561 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.74 10.87 13,420

11,138 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.67 10.74 13,499

10,768 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.89 11.68 13,320

10,819 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.83 11.67 13,387

10,239 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.75 11.83 13,351

10,073 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.99 10.77 13,482

11,791 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.64 10.96 13,546

0 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN

12,078 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.87 11.85 13,323

12,044 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.75 13.15 12,834

11,315 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.67 11.02 13,366

9,984 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.79 11.57 13,388

10,263 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.82 10.78 13,542

9,946 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.9 12.13 13,350

11,931 1, 2 KY, WV LESLIE, LOGAN ALMA TRAIN 0.87 11.67 13,260

Page 39 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

10,945 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.07 8.56 13,632

11,663 1, 2 TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.09 6.67 13,930

12,174 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 1.1 13.14 13,387

11,980 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 0.94 13.54 13,226

12,130 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 1.18 13.29 13,328

12,168 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 1.16 13.5 13,302

12,235 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 1.27 12.69 13,484

12,108 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 1.32 9.76 13,971

Page 40 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,310 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 0.95 12.74 13,244

12,425 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 1.3 12.32 13,437

12,162 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 1.27 14.05 13,201

12,055 1, 2 VA WISE

BANNER, EDWARDS, 

JAWBONE, NORTON, 

SPLASHDAM TRAIN 1.25 13.61 13,281

11,543 1, 2 KY MARTIN POND CREEK TRAIN 1.06 8.22 13,698

11,320 1, 2 KY MARTIN POND CREEK TRAIN 1.12 6.14 14,031

11,330 1, 2 KY MARTIN POND CREEK TRAIN 0.96 10.78 13,203

11,237 1, 2 KY MARTIN POND CREEK TRAIN 0.92 10.49 13,243

11,418 1, 2 KY MARTIN POND CREEK TRAIN 1.06 8.22 13,698

11,203 1, 2 KY MARTIN POND CREEK TRAIN 0.95 10.88 13,157

11,023 1, 2 KY MARTIN POND CREEK TRAIN 1 6.95 13,898

Page 41 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,432 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.21 10.97 13,717

11,469 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 0.98 11.23 13,626

11,714 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.07 12.63 13,409

11,714 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 0.94 12.01 13,512

9,774 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.09 10.84 13,660

Page 42 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,782 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.13 11.84 13,555

11,720 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.09 12.59 13,397

11,436 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 0.97 12.42 13,378

11,540 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.09 12.3 13,447

11,787 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.02 12.22 13,429

Page 43 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,754 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.11 10.63 13,710

11,679 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.19 11.94 13,452

11,673 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.15 11.48 13,513

11,248 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.19 11.49 13,591

11,651 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.03 10.94 13,667

Page 44 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

10,002 1, 2 KY PIKE

AMBURGEY, BLAIR, 

BLAIR FLOOR, 

CLINTWOOD, CREECH, 

DARBY, EAGLE TRAIN 1.1 12.45 13,437

9,825 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.92 12.5 12,914

11,813 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.92 10.34 13,216

11,718 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.86 10.69 13,183

11,582 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.79 10.84 13,217

11,345 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.8 10.82 13,226

Page 45 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,858 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.8 13.41 12,811

11,221 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.77 10.89 13,291

11,510 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.82 12.28 13,063

11,679 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.72 11.88 13,064

11,813 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.78 11.98 13,079

11,764 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.8 11.03 13,247

Page 46 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,505 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.78 11.83 13,081

11,742 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.8 12.88 12,949

11,659 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.93 11.07 13,208

11,690 1, 2 KY PIKE

COALBURG, FIRECLAY, 

HAMLIN, STOCKTON, 

TAYLOR TRAIN 0.78 11.72 13,153

11,037 1, 2 VA WISE

IMBODEN, KELLY, LOW 

SPLINT TRAIN 0.98 10.52 13,704

40 EPA recognizes that facilities have (sometimes) several months inventory and that the amount received is not necessarily the same as the 

amount fired.

41 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

42 If known.

Page 47 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

NOTE: Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated 

from each seam listed. The information being provided is on a shipment by shipment basis. Georgia Power cannot guarantee that what was

shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

43 If known.

Page 48 of 73 part II, 2 (coal)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

State/Country County42 Coal seam43

7,596 1, 2 Georgia/USA N/A N/A Truck

7,623 1, 2 Georgia/USA N/A N/A Truck

7,618 1, 2 Georgia/USA N/A N/A Truck

45,724 1, 2 Georgia/USA N/A N/A Truck

15,262 1, 2 Georgia/USA N/A N/A Truck

15,237 1, 2 Georgia/USA N/A N/A Truck

22,881 1, 2 Georgia/USA N/A N/A Truck

7,627 1, 2 Georgia/USA N/A N/A Truck

15,282 1, 2 Georgia/USA N/A N/A Truck

7,591 1, 2 Georgia/USA N/A N/A Truck

15,127 1, 2 Georgia/USA N/A N/A Truck

30,260 1, 2 Georgia/USA N/A N/A Truck

30,264 1, 2 Georgia/USA N/A N/A Truck

30,247 1, 2 Georgia/USA N/A N/A Truck

45,415 1, 2 Georgia/USA N/A N/A Truck

15,143 1, 2 Georgia/USA N/A N/A Truck

7,552 1, 2 Georgia/USA N/A N/A Truck

7,200 1, 2 Plant McDonough N/A N/A Truck

36,124 1, 2 Plant McDonough N/A N/A Truck

28,812 1, 2 Plant McDonough N/A N/A Truck

7,210 1, 2 Plant McDonough N/A N/A Truck

21,603 1, 2 Plant McDonough N/A N/A Truck

21,600 1, 2 Plant McDonough N/A N/A Truck

14,002 1, 2 Plant McDonough N/A N/A Truck

FUEL OIL SHIPMENTS

Amount received, 

gallons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

Page 49 of 73 part II, 2 (oil)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

as available (indicated N/A if not available; use additional pages, as necessary):

State/Country County42 Coal seam43

FUEL OIL SHIPMENTS

Amount received, 

gallons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

15,201 1, 2 Plant McDonough N/A N/A Truck

14,000 1, 2 Plant McDonough N/A N/A Truck

14,000 1, 2 Plant McDonough N/A N/A Truck

14,000 1, 2 Plant McDonough N/A N/A Truck

14,003 1, 2 Plant McDonough N/A N/A Truck

30,395 1, 2 Georgia/USA N/A N/A Truck

7,603 1, 2 Georgia/USA N/A N/A Truck

22,826 1, 2 Georgia/USA N/A N/A Truck

30,428 1, 2 Georgia/USA N/A N/A Truck

15,234 1, 2 Georgia/USA N/A N/A Truck

7,616 1, 2 Georgia/USA N/A N/A Truck

7,577 1, 2 Georgia/USA N/A N/A Truck

15,179 1, 2 Georgia/USA N/A N/A Truck

40 EPA recognizes that facilities have (sometimes) several months inventory and that the amount received is not necessarily the same as the 

amount fired.

41 Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, 

[for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW])

OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).

42 If known.

43 If known.

Page 50 of 73 part II, 2 (oil)
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

3 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information44

, as

available (dry basis) (indicate N/A if not available):

NOTES: "ND" indicates results are non detect. All results presented on a dry basis.

Georgia Power collects this information on select coal shipments on a quarterly basis, but does not have this information available on a shipment by shipment basis. The information Georgia Power provides in this question cannot be 

linked to the information in Part II, Question 2 because the information comes from two separate databases. Thus the information provided in this question represents only a very small portion of our actual shipments.

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

09-100 8,223 1.06 6.73 13,675 0.101 2237 61 20.0 1.8 17.4 2.2 0.09 9.3 6.9 12.1 11.4 0.8 IN Gibson Herron # 5 Seam Train

09-500 12,831 1.11 12.61 13,387 0.080 385 121 12.3 1.2 18.4 2.0 0.04 18.6 7.0 8.9 27.8 2.1 KY, VA

KY - Harlan 

VA - 

Buchanan, 

Dickenson, 

Wise

Clintwood 28.82%, 

Blair 9.16%, Eagle 

10.89%, Norton 

15.19%, L. Banner 

5.15%, Tiller 6.27%, 

Bolling 6.06%, Blue 

Gem 0.91%, Aily 

6.81%, Banner 

6.55%, Jawbone 

4.19% Train

09-501 12,832 0.99 12.79 13,239 0.070 86 116 14.7 1.2 7.9 2.1 <0.02 19.0 7.8 9.7 41.6 2.3 VA Wise

 (1)Parsons (2) 

Imboden (3)Taggart 

(4)Taggert Marker 

(5)Low Splint C (6) 

Low splint (7) Low 

Splint A Train

09-702 11,762 0.62 6.45 13,017 0.082 56 36 5.8 1.0 6.4 0.4 0.11 5.4 2.5 2.6 18.1 5.3

Colombia

, SA

Cesar / La 

Loma Gran Madre group Train

09-503 12,722 0.8 14.3 13,258 0.070 1064 112 15.8 1.9 19.2 3.3 0.04 17.6 9.3 8.3 37.9 2.8 KY Pike

Lower Elkhorn, 

Elkhorn , Alma, 

Clintwood Train

09-506 12,911 0.71 13.2 13,019 0.053 895 92 12.9 1.0 5.3 2.5 <0.02 17.2 8.3 7.7 16.8 3.7 WV

Mingo, 

Logan

Coalburg, Pond 

Creek, Cedar Grove, 

Alma, Mixed Train

09-507 12,420 0.91 13.36 13,049 0.073 995 103 12.9 1.0 12.1 2.9 0.03 17.6 8.9 9.1 50.0 3.0 KY Pike

Broaz, Haddix, 

Chilton, Middle 

Whitesburg, 

Upper/Lower Alma, 

Haddix, Cedar 

Grove, Williamson Train

09-508 12,573 1.15 10.56 13,548 0.090 1044 80 12.2 1.3 12.3 2.6 0.05 15.8 6.9 7.9 15.9 2.7 KY Pike

Elkhorn #2, #3, 

Lower Elkhorn, 

Clintwood Train

09-509 12,514 0.82 12.33 12,932 0.074 712 99 15.7 1.0 7.8 3.0 <0.02 17.3 10.1 8.2 16.1 3.6 KY Pike

Coalburg, Buffalo, 

Williamson, 

Stockton Train

09-104 12,000 1.29 7.39 13,538 0.099 2318 52 20.6 1.5 20.5 2.0 0.10 10.6 6.2 12.0 11.2 1.0 IN Gibson Herron # 5 seam Barge

Total amount of 

fuel represented 

by sample, tons

Sample 

ID #

State/ 

Country

County

Fuel 

Shipment 

Method

Nickel, 

ppm

Other trace metal HAP, ppm45

Total 

Sulfur, %

Ash 

Content, 

%

Heating 

Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Coal Seam

Page 51 of 73 part II, 3
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

3 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information44

, as

available (dry basis) (indicate N/A if not available):

NOTES: "ND" indicates results are non detect. All results presented on a dry basis.

Georgia Power collects this information on select coal shipments on a quarterly basis, but does not have this information available on a shipment by shipment basis. The information Georgia Power provides in this question cannot be 

linked to the information in Part II, Question 2 because the information comes from two separate databases. Thus the information provided in this question represents only a very small portion of our actual shipments.

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

Total amount of 

fuel represented 

by sample, tons

Sample 

ID #

State/ 

Country

County

Fuel 

Shipment 

Method

Nickel, 

ppm

Other trace metal HAP, ppm45

Total 

Sulfur, %

Ash 

Content, 

%

Heating 

Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Coal Seam

09-203 10,065 1.45 12.64 13,192 0.116 51 102 10.2 <1 25.6 1.5 0.19 14.2 6.8 6.1 29.3 2.2 VA Lee Creech, House Coal Train

09-400 11,412 1.22 7.45 13,789 0.081 1182 82 20.5 <1 7.1 2.4 0.11 12.9 10.5 6.4 10.2 3.4 TN Clairborne

Braden, Red Ash, 

Walnut Mountain Train

09-401 8,500 2.01 8.93 13,675 0.099 643 74 15.6 <1 15.5 1.9 0.13 13.2 6.4 6.2 14.6 2.9 TN Clairborne

Walnut Mountain, 

Windrock, Pee Wee Train

09-205 22,000 0.87 10.51 13,205 0.071 1209 74 24.2 1.8 18.4 2.6 ND 25.3 13.1 9.8 9.0 4.8 WV Wayne Coalburg Train

09-211 12,571 1.06 8.63 13,663 ND 2333 49 14.3 1.2 6.4 2.8 ND 12.1 8.3 7.8 39.7 3.9 KY Martin Alma, Pond Creek Train

09-510 12,792 1.07 13.2 13,252 0.066 ND 73 14.4 1.5 14.6 2.5 0.04 18.2 8.2 9.7 43.1 2.5 VA Wise

(1) Low Splint (2) 

Imboden (3)Taggart 

(4)Upper Parsons 

(5)Taggart Marker 

(6)Lower Parsons Train

09-517 12,882 1.18 13.47 13,283 0.081 654 108 11.5 1.4 22.5 2.0 0.14 16.0 7.0 8.3 60.1 1.9 VA

Buchanan, 

Dickenson 

and Wise

Blair 26.61%, 

Clintwoood 20.34%, 

Raven 18.16%, Aily 

12.22%, Eagle 

11.99%, L. Banner 

5.69%, Banner 

4.99% Train

09-511 12,581 1.2 10.99 13,642 0.090 791 77 12.1 1.5 16.4 2.9 0.06 17.8 7.5 9.1 17.5 2.8 KY Pike

Elkhorn #2, #3, 

Lower Elkhorn, 

Clintwood Train

09-512 12,469 0.72 13.16 13,086 ND 1150 101 15.9 1.4 4.7 4.4 ND 20.4 12.4 10.3 16.4 3.7 WV

Mingo, 

Logan

Coalbug, Pond 

Creek, Cedar Grove, 

Alma Mixed Train

09-513 12,538 0.84 9.58 13,401 ND 813 87 17.7 1.0 8.8 3.5 ND 14.8 11.3 7.0 17.7 3.9 KY Pike

Coalburg, Buffalo, 

Whitesburg, 

Stockton Train

09-515 12,746 0.87 11.76 13,275 ND 992 90 15.5 1.1 12.8 2.9 ND 16.2 8.5 7.8 38.4 2.7 KY Pike

Lower Elkhorn, 

Elkhorn , Alma, 

Clintwood Train

09-516 12,427 0.94 14.5 12,864 ND 1178 108 17.1 1.1 16.6 3.2 ND 18.1 10.8 9.5 134.3 2.4 KY Pike

Chilton, Whitesburg, 

Upper/Lower Alma, 

Cedar Grove Train

Page 52 of 73 part II, 3
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

3 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information44

, as

available (dry basis) (indicate N/A if not available):

NOTES: "ND" indicates results are non detect. All results presented on a dry basis.

Georgia Power collects this information on select coal shipments on a quarterly basis, but does not have this information available on a shipment by shipment basis. The information Georgia Power provides in this question cannot be 

linked to the information in Part II, Question 2 because the information comes from two separate databases. Thus the information provided in this question represents only a very small portion of our actual shipments.

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

Total amount of 

fuel represented 

by sample, tons

Sample 

ID #

State/ 

Country

County

Fuel 

Shipment 

Method

Nickel, 

ppm

Other trace metal HAP, ppm45

Total 

Sulfur, %

Ash 

Content, 

%

Heating 

Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Coal Seam

09-411 10,522 1.63 9.32 13,586 0.115 298 82 16.3 1.6 9.6 2.2 0.12 14.4 6.4 7.9 13.9 3.5 TN Clairborne

Walnut Mountain, 

Windrock, Pee Wee Train

09-412 12,474 0.98 9.01 13,460 0.071 1310 98 26.4 1.2 5.0 3.0 0.10 16.9 13.5 9.7 21.9 3.8 TN Clairborne

Braden, Red Ash, 

Walnut Mountain Train

09-216 12,723 1.59 9.41 13,416 0.115 2317 60 13.0 1.4 7.9 2.1 0.04 16.0 7.0 9.1 18.9 3.9 KY Martin Alma, Taylor Train

09-217 12,700 0.95 9.81 13,351 ND 1563 59 21.5 1.3 4.5 2.8 ND 22.5 12.0 10.0 6.2 4.7 WV Wayne Coalburg Train

09-519 12,850 0.9 13.36 13,230 ND 68 119 14.5 1.1 9.7 2.0 ND 19.9 8.0 8.9 49.4 2.5 VA Wise

(1) Imboden 

(2)Taggart (3)Lower 

Parsons (4)Taggart 

Marker (5)Low 

Splint (6) Low Splint 

A (7) Low Splint D 

(8) Upper Parsons Train

09-520 12,855 1.28 9.91 13,626 ND 464 89 12.5 1.3 21.0 2.0 0.08 16.8 7.5 7.5 62.5 2.1 VA

Buchanan, 

Dickenson 

and Wise

Clintwoood 34.89%, 

Norton 26.08% Blair 

14.43% Aily 6.83%, 

Jawbone 5.33% 

Eagle 4.99 (7) Cedar 

Grove 3.10% (8) 

Bolling 2.96% (9) 

Raven 1.38% Train

09-521 12,634 0.75 12.11 13,220 ND 1028 100 12.7 1.1 10.1 3.1 ND 16.0 8.1 6.9 24.8 3.4 KY Pike

Lower Elkhorn, 

Elkhorn , Alma, 

Clintwood Train

09-524 12,596 0.86 11.74 13,000 ND 704 98 18.9 <1 0.9 4.3 ND 14.2 10.5 7.3 19.0 2.9 KY Pike

Coalburg, Buffalo, 

Stockton, Hamlen Train

09-226 11,981 0.98 10.72 13,199 ND 1129 65 22.0 1.5 3.8 2.8 ND 22.4 11.8 10.3 6.4 4.7 WV Wayne Coalburg Train

09-105 8,099 1.38 8.04 13,393 0.123 1783 36 21.3 1.6 22.3 1.9 0.13 11.4 7.2 20.2 13.4 0.9 IN Gibson Herron # 5 seam Train

09-525 12,737 0.94 13.89 12,933 ND 975 99 11.7 <1 11.2 2.8 0.04 15.6 7.7 9.0 21.7 3.4 WV

Mingo, 

Logan

Coalbug, Pond 

Creek, Cedar Grove, 

Alma Mixed Train

09-526 12,475 1.18 12.04 13,450 ND 849 91 11.9 1.1 10.0 2.7 0.08 18.1 7.1 10.7 18.5 2.7 KY Pike

Elkhorn #2, #3, 

Lower Elkhorn, 

Clintwood Train

Page 53 of 73 part II, 3
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

3 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information44

, as

available (dry basis) (indicate N/A if not available):

NOTES: "ND" indicates results are non detect. All results presented on a dry basis.

Georgia Power collects this information on select coal shipments on a quarterly basis, but does not have this information available on a shipment by shipment basis. The information Georgia Power provides in this question cannot be 

linked to the information in Part II, Question 2 because the information comes from two separate databases. Thus the information provided in this question represents only a very small portion of our actual shipments.

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

Total amount of 

fuel represented 

by sample, tons

Sample 

ID #

State/ 

Country

County

Fuel 

Shipment 

Method

Nickel, 

ppm

Other trace metal HAP, ppm45

Total 

Sulfur, %

Ash 

Content, 

%

Heating 

Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Coal Seam

09-527 12,691 0.81 11.8 13,156 ND 1018 80 13.8 1.2 13.7 3.6 0.07 12.0 10.9 8.5 130.1 2.2 KY Pike

Chilton, Whitesburg, 

Upper/Lower Alma, 

Cedar Grove Train

09-231 12,707 1.47 8.58 13,470 0.076 1951 51 17.9 1.2 7.7 2.6 0.06 17.5 9.9 11.0 14.6 4.1 KY Martin

Alma, Taylor, 

Stockton Train

09-429 10,084 2 10.27 13,305 0.107 534 92 30.5 1.9 12.0 2.7 0.31 23.9 11.4 13.2 19.0 4.3 TN Clairborne

Walnut Mountain, 

Windrock, Pee Wee Train

09-430 11,546 0.94 7.32 13,811 ND 1103 70 28.7 1.1 5.1 3.6 0.11 16.5 14.1 10.2 18.5 3.6 TN Clairborne

Braden, Red Ash, 

Walnut Mountain Train

09-233 11,610 0.74 12.37 13,164 0.067 1151 76 15.4 1.0 13.3 3.9 0.03 13.8 12.6 7.9 157.6 2.2 KY Pike

Chilton, Lower 

Alma, Cedar Grove, 

#3 Elkhorn Train

09-234 12,612 1.14 10.28 13,800 ND 1062 71 11.1 1.1 9.1 3.0 0.06 17.4 7.0 8.2 14.5 3.1 KY Pike

Elkhorn #2, #3, 

Lower Elkhorn, 

Clintwood Train

09-436 10,210 1.87 9.45 13,497 0.096 392 80 23.1 1.6 11.6 2.1 0.20 18.0 8.8 10.2 14.1 4.1 TN Clairborne

Walnut Mountain, 

Windrock, Pee Wee Train

09-437 11,880 1.31 6.61 13,825 0.058 1205 56 22.9 1.2 6.7 2.9 0.10 13.3 12.2 7.9 9.9 3.9 TN Clairborne

Braden, Red Ash, 

Walnut Mountain Train

09-529 12,893 1.01 12.13 13,403 ND 155 109 13.5 1.2 7.1 2.2 0.06 20.5 7.8 10.5 26.3 2.8 VA Wise

(1) Parsons 

(2)Taggart (3)Low 

Splint A 

(4)Dorchester Train

09-530 12,463 0.8 12.06 13,315 0.078 124 47 5.3 ND 0.9 0.3 0.03 3.4 2.5 3.0 13.6 0.9 WV

Mingo, 

Logan

Coalburg, Stockton, 

Alma, Lower Cedar 

Grove Train

09-111 8,195 1.45 8.78 13,275 0.123 1975 47 25.0 1.8 23.9 2.1 0.14 13.2 6.9 22.5 14.7 1.0 IL Gibson Herron # 5 Seam Train

09-241 12,019 0.89 11.46 13,096 ND 1180 72 23.0 1.7 4.0 3.1 ND 27.4 13.3 11.1 9.8 4.8 WV Wayne Coalburg Train

09-531 12,276 0.82 12.07 13,075 0.066 744 83 15.2 <1 6.0 2.2 ND 18.4 10.6 7.6 16.1 4.0 KY Pike

Coalburg, Buffalo, 

Taylor, A Top Train

Page 54 of 73 part II, 3
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

3 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information44

, as

available (dry basis) (indicate N/A if not available):

NOTES: "ND" indicates results are non detect. All results presented on a dry basis.

Georgia Power collects this information on select coal shipments on a quarterly basis, but does not have this information available on a shipment by shipment basis. The information Georgia Power provides in this question cannot be 

linked to the information in Part II, Question 2 because the information comes from two separate databases. Thus the information provided in this question represents only a very small portion of our actual shipments.

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

Total amount of 

fuel represented 

by sample, tons

Sample 

ID #

State/ 

Country

County

Fuel 

Shipment 

Method

Nickel, 

ppm

Other trace metal HAP, ppm45

Total 

Sulfur, %

Ash 

Content, 

%

Heating 

Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Coal Seam

09-534 12,889 1.07 13.4 13,260 0.060 426 59 14.1 <1 18.0 1.9 0.17 17.3 7.9 6.8 39.1 2.7 VA

Buchanan, 

Dickenson 

and Wise

Bolling 24.88%, 

Clintwoood 19.15%, 

Aily 15.35%, Blair 

14.42% L. Banner 

13.23%, Raven 

4.52% Eagle 4.02%, 

U. Banner 3.44%, 

Taggart 0.98% Train

09-535 12,753 1.35 9.27 13,431 0.086 1981 103 16.6 1.3 8.0 2.4 ND 16.4 7.9 8.4 14.5 4.1 KY Martin

Alma, Taylor, 

Stockton Train

09-239 12,757 0.89 11.8 13,371 ND 1048 88 15.5 1.3 10.5 3.4 ND 18.5 10.4 8.7 24.6 3.1 KY Pike

Lower Elkhorn, 

Elkhorn , Alma, 

Clintwood Train

44 To the extent that a vendor provides these data or that a facility is required by State or local agency to analyze its fuel for HAP constituents (e.g., Cl, F), 

and any metallic HAP (e.g., Hg, Pb, As, Se, etc.), EPA wishes the responding facility to provide those fuel analyses results. Otherwise, this 12-month fuel

analysis requirement can be bypassed by the respondent.

45 Metal HAP includes compounds of antimony, arsenic, beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, phosphorus, and selenium.

Page 55 of 73 part II, 3
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

4 Were the data provided in Part II, question 3 above, acquired pursuant to:

__X__ permit requirements (for coal)

____ contractual obligations

____ standard operational procedures

__X__ other (please specify _at the discretion of the plant and to support other projects__)

5 Analyses provided in Part II, question 3 above, supplied by

____ Fuel supplier (name and address)

__X__ Other (name and address)

Georgia Power Environmental Lab

5131 Maner Road, Smyrna GA 30080

6 Name and address of laboratory performing analyses:

Georgia Power Environmental Lab (same as above)

Page 56 of 73 part II, 4-6
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

7 In addition to the analyses required in Part II, question 3 above, for samples for which analyses of chlorine and/or any of the HAP metals were 

conducted, please provide copies of any analyses conducted over the preceding 12 calendar months for (a) complete proximate and ultimate 

analyses, (b) additional trace metals, and (c) the mineralogy of the ash that are readily available for the oil(s) or coal(s) listed in Part II, question

2 above. The Agency is requesting these data only as they may already be available; no additional sampling or analyses are required to provide

these data.

Total 

Moisture

Volatiles Ash Fixed 

Carbon Carbon Hydrogen Nitrogen Total Sulfur Oxygen Barium Copper Magnesium Sodium Vanadium Zinc Al2O3 Fe2O3 CaO MgO MnO2 P2O5 K2O SiO2 Na2O SO3 TiO2

09-100 15.91 34.69 6.73 58.58 79.53 4.7 1.78 1.06 6.2 30 6.8 0.034 0.065 21.1 20.2 23.7 10.88 2.39 0.85 0.027 0.6 2.67 54.06 1.29 2.1 1.35

09-500 4.94 30.41 12.61 56.98 76.22 4.6 1.52 1.11 3.94 181 20.6 0.087 0.033 36.2 16.0 25.7 9.28 1.7 1.03 ND 0.491 2.2 50.2 0.434 1.28 1.55

09-501 6.35 32.47 12.79 54.74 75.28 4.65 1.41 0.99 4.88 121 21.1 0.102 0.044 43.2 22.6 27.6 7.96 0.992 1.25 ND ND 3.05 54.2 0.554 0.561 1.45

09-702 13.92 39.69 6.45 53.86 74.85 4.73 1.43 0.62 11.92 226 5.5 0.061 0.099 17.7 6.7 20.2 7.35 4.72 1.67 ND ND ND 53 2.41 4.45 0.869

09-503 6.81 30.55 14.3 55.15 73.53 4.51 1.37 0.8 5.49 486 21.6 0.108 0.045 34.7 14.6 27.5 6.72 0.962 1.35 ND ND 3.41 55.2 0.563 0.592 1.27

09-506 6.04 31.9 13.2 54.9 76.53 4.63 1.34 0.71 3.6 132 18.6 0.003 0.000 30.2 11.7 28.6 4.92 0.986 1.14 ND ND 2.78 60.7 0.296 0.39 1.76

09-507 4.92 31.63 13.36 55.01 75.87 4.63 1.35 0.91 3.88 386 20.0 0.092 0.037 29.4 14.7 24.2 6.89 0.858 1.11 ND ND 2.78 55.1 0.397 0.715 1.38

09-508 8.34 32.7 10.56 56.73 78.97 4.8 1.45 1.15 3.07 162 22.0 0.067 0.031 30.4 15.7 26.7 10 1.34 1.01 ND ND 2.63 49.6 0.51 0.859 1.48

09-509 6.54 33.63 12.33 54.03 73.76 4.58 1.35 0.82 7.16 92 17.7 0.071 0.019 27.7 22.2 27.9 5.36 1.08 0.968 ND ND 2.46 56.4 0.272 0.593 1.32

09-104 13.14 35.3 7.39 57.31 76.78 3.99 1.7 1.29 8.85 30 7.5 0.038 0.065 24.1 14.4 23.4 13.2 1.75 0.84 0.024 0.6 2.68 53.67 1.19 1.22 1.35

09-203 5.28 34.06 12.64 53.31 75.25 4.72 1.41 1.45 4.52 152 18.5 0.088 0.027 27.1 15.3 24.6 10.7 1.34 1.13 ND ND 2.5 50.9 0.336 0.658 1.33

09-400 5.42 36.88 7.45 55.68 79.19 4.91 1.83 1.22 5.39 122 21.6 0.063 0.014 31.6 18.9 27.6 11.3 3.44 1.24 ND ND 2.23 49.2 0.36 2.24 1.33

09-401 5.83 36.96 8.93 54.11 77.62 4.92 1.9 2.01 4.63 91 23.9 0.059 0.016 34.8 13.8 22.8 16.7 2.13 0.982 ND ND 2.19 47.5 0.264 1.1 1.19

09-205 7.44 35.84 10.51 53.65 76.32 4.84 1.44 0.87 6.02 41 21.9 0.047 0.026 50.1 30.7 32.3 4.42 1.08 0.756 ND ND 2.22 53.5 0.405 0.396 1.49

09-211 8.19 37.02 8.63 54.35 75.32 4.94 1.64 1.06 8.41 92 21.7 0.064 0.043 29.5 16.1 24.9 12.5 3.09 1.23 ND ND 2.63 51.4 0.73 2.24 1.34

09-510 6.98 32.91 13.2 53.89 75.61 4.8 1.4 1.07 3.92 132 22.3 0.109 0.042 39.1 22.4 26.6 9.47 1.34 1.26 ND ND 3.26 53.5 0.531 0.96 1.34

09-517 5.05 28.35 13.47 58.17 75.07 4.5 1.45 1.18 4.33 172 23.8 0.101 0.036 30.8 19.1 24.1 10.4 1.71 1.12 ND ND 2.77 54.7 0.412 1.19 1.21

09-511 7.98 31.56 10.99 57.45 79.3 4.85 1.46 1.2 2.19 152 25.1 0.062 0.039 34.0 12.7 25.4 9.09 1.4 0.924 ND ND 2.4 52.6 0.567 0.862 1.52

09-512 5.8 31.96 13.16 54.89 75.3 4.72 1.37 0.72 4.73 193 22.8 0.086 0.028 36.9 14.4 27.8 4.35 1.44 1.24 ND ND 3.14 58.7 0.352 0.964 1.62

09-513 5.57 34.43 9.58 55.99 76.39 4.83 1.37 0.84 6.99 72 15.9 0.056 0.000 24.1 28.2 27 5.46 1.3 0.925 ND ND 2.1 53.5 0.239 0.57 1.24

09-515 5.67 31.26 11.76 56.97 75.97 4.62 1.33 0.87 5.45 417 18.6 0.084 0.047 27.3 15.6 25.2 7.17 0.964 1.09 ND ND 3.18 55 0.562 0.727 1.26

09-516 5.81 32.04 14.5 53.46 73.4 4.63 1.25 0.94 5.28 386 21.7 0.110 0.038 31.2 21.0 24.4 10.4 1.48 1.24 ND ND 2.92 56.4 0.42 1.17 1.31

09-411 5.82 36.75 9.32 53.92 75.84 4.98 1.77 1.63 6.46 122 26.6 0.063 0.017 35.5 14.7 28.2 11.7 2.56 1.22 ND 0.459 2.41 58.5 0.615 1.21 1.4

Sample 

ID #

Proximate Analyses, % by wt Ultimate Analyses, % by wt Other Trace Metals, ppm, dry basis Ash Mineralogy, % by wt

Page 57 of 73 part II, 7
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

7 In addition to the analyses required in Part II, question 3 above, for samples for which analyses of chlorine and/or any of the HAP metals were 

conducted, please provide copies of any analyses conducted over the preceding 12 calendar months for (a) complete proximate and ultimate 

analyses, (b) additional trace metals, and (c) the mineralogy of the ash that are readily available for the oil(s) or coal(s) listed in Part II, question

2 above. The Agency is requesting these data only as they may already be available; no additional sampling or analyses are required to provide

these data.

Total 

Moisture

Volatiles Ash Fixed 

Carbon Carbon Hydrogen Nitrogen Total Sulfur Oxygen Barium Copper Magnesium Sodium Vanadium Zinc Al2O3 Fe2O3 CaO MgO MnO2 P2O5 K2O SiO2 Na2O SO3 TiO2

Sample 

ID #

Proximate Analyses, % by wt Ultimate Analyses, % by wt Other Trace Metals, ppm, dry basis Ash Mineralogy, % by wt

09-412 6.19 36.01 9.01 54.99 76.13 4.9 1.63 0.98 7.36 113 28.7 0.081 0.019 45.4 25.6 28.5 7.19 3.26 1.56 ND 0.502 2.59 51 0.349 1.9 1.28

09-216 6.72 38.03 9.41 52.56 72.88 4.8 1.52 1.59 9.79 82 23.2 0.047 0.033 34.8 14.2 27.7 12.7 3.07 0.839 ND ND 1.86 46.9 0.546 2.15 1.26

09-217 6.04 36.73 9.81 53.45 73.44 4.77 1.47 0.95 9.57 31 20.8 0.038 0.023 43.1 21.9 32.7 5.17 1.15 0.612 ND ND 1.89 52.7 0.375 0.386 1.28

09-519 6.16 32.55 13.36 54.1 75.2 4.82 1.56 0.9 4.16 132 21.5 0.109 0.048 40.3 22.7 26.8 8.44 1.64 1.35 ND ND 3.29 58.4 0.542 1.25 1.3

09-520 4.92 35.57 9.91 54.52 77.95 4.74 1.69 1.28 4.43 172 20.4 0.075 0.034 31.0 17.7 25.8 12.5 1.78 1.09 ND ND 2.43 58 0.509 1.28 1.42

09-521 5.15 31.19 12.11 56.71 75.69 4.76 1.56 0.75 5.13 285 18.6 0.086 0.048 28.6 12.6 27.4 6.87 1.13 1.18 ND ND 3.27 57.8 0.54 0.715 1.35

09-524 6.91 34.13 11.74 54.13 72.22 4.66 1.41 0.86 9.11 110 16.9 0.070 0.019 24.1 26.0 27.1 5.68 1.33 1.03 ND ND 2.68 55.3 0.262 0.742 1.18

09-226 6.43 36.29 10.72 52.99 74.53 4.93 1.59 0.98 7.25 41 21.0 0.042 0.026 45.6 27.4 32.4 4.36 0.883 0.64 ND ND 2.1 56.5 0.37 0.272 1.29

09-105 14.39 34.98 8.04 56.98 75.91 4.79 1.32 1.38 8.56 30 7.5 0.039 0.060 22.6 21.5 22.09 12.26 1.69 0.8 0.026 0.4 2.63 56.29 1.01 1.37 1.29

09-525 5.82 31.42 13.89 54.69 72.04 4.35 1.4 0.94 7.37 224 16.5 0.083 0.022 24.9 11.7 27.9 6.39 1.24 1.16 ND ND 2.9 57.8 0.292 0.95 1.48

09-526 7.57 32.14 12.04 55.82 74.56 4.49 1.56 1.18 6.17 152 25.2 0.073 0.042 35.0 13.4 29.5 7.43 0.983 0.903 ND ND 2.46 53.7 0.519 0.443 1.54

09-527 7.86 32.37 11.8 55.83 74.02 4.43 1.5 0.81 7.44 285 17.6 0.083 0.039 20.4 15.6 24.8 11 1.74 1.33 ND ND 3.03 51.8 0.507 1.42 1.11

09-231 6.67 38.81 8.58 52.6 74.73 4.82 1.6 1.47 8.8 62 29.3 14.578 0.029 44.2 18.7 30 9.74 2.59 0.789 ND ND 1.81 47.7 0.501 2.47 1.21

09-429 6.36 35.29 10.27 54.44 73.63 4.69 1.62 2 7.78 92 45.9 0.085 0.015 61.3 34.8 27.5 11.6 2.72 1.35 ND ND 2.21 45.2 0.273 2.14 1.41

09-430 5.44 35.86 7.32 56.82 76.71 4.86 1.61 0.94 8.56 82 32.3 0.056 0.029 49.0 22.6 28.5 7.98 3.13 1.46 ND 0.441 2.25 48.3 0.376 2.33 1.37

09-233 7.03 31.74 12.37 55.89 73.57 4.52 1.35 0.74 7.46 255 20.5 0.084 0.034 23.3 17.2 23.7 12.7 1.67 1.04 0.132 ND 2.9 50.1 0.451 1.27 1.22

09-234 6.8 32.61 10.28 57.11 77.25 4.72 1.56 1.14 5.05 172 26.4 0.063 0.040 31.3 11.7 29.4 8.66 1.22 0.912 ND ND 2.27 49.4 0.581 0.788 1.74

09-436 6.32 35.44 9.45 55.11 75 4.78 1.83 1.87 7.06 112 35.2 0.070 0.015 47.6 23.3 28 11.4 2.48 1.25 ND 0.477 2.17 48.2 0.253 2.19 1.38

09-437 6.02 36.44 6.61 56.95 77.61 4.94 1.74 1.31 7.79 71 28.2 0.054 0.015 39.6 20.3 32.3 4.08 0.902 0.651 ND ND 1.54 56.5 0.173 ND 1.75

09-529 6.24 33.15 12.13 54.71 75.15 4.65 1.44 1.01 5.62 122 24.1 0.092 0.037 41.2 20.5 26.9 6.59 1.2 1.06 ND 0.403 2.65 52.4 0.435 0.695 1.51

09-530 6.14 32.04 12.06 55.9 74.64 4.58 1.36 0.8 6.56 317 10.6 0.226 0.082 13.6 14.1 25.3 5.02 0.88 0.998 ND ND 2.38 56.1 0.291 0.556 1.44

09-111 14.31 34.8 8.78 56.42 75.24 5.08 1.94 1.45 7.51 30 7.4 0.043 0.072 24.2 21.6 20.93 12.44 1.24 0.82 0.026 0.3 2.51 58.15 1.1 1.08 1.31

09-241 7.18 35.8 11.46 52.75 73.15 4.74 1.45 0.89 8.31 31 22.7 0.052 0.026 48.8 23.3 28.5 3.76 0.833 0.679 ND ND 1.97 52.9 0.325 0.353 1.24

09-531 6.13 33.7 12.07 54.23 73.72 4.62 1.36 0.82 7.42 72 15.3 0.066 0.022 28.0 13.7 30.9 4.71 1.06 0.932 ND ND 2.8 58.4 0.354 0.504 1.35

09-534 5.91 28.73 13.4 57.87 71.07 4.35 1.49 1.07 8.62 162 17.8 0.087 0.033 29.8 22.0 27.5 9.14 2.04 1.11 ND 0.353 2.64 58.4 0.431 1.09 1.78

09-535 6.75 37.55 9.27 53.18 74.41 4.84 1.6 1.35 8.53 62 21.3 0.045 0.033 35.5 15.3 30.1 11.7 2.59 0.809 ND ND 1.89 48.5 0.545 1.51 1.34

09-239 6.42 31.36 11.8 56.85 74.7 4.56 1.5 0.89 6.56 315 21.4 0.080 0.043 33.1 13.0 30.3 5.64 1.14 1.15 ND ND 2.9 51 0.57 1.08 1.4

Page 58 of 73 part II, 7
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

8a What emission test report(s), parametric monitoring data, and other data or monitoring are available for the boilers noted in Part I,

question 15, for tests conducted since January 1, 2005. Please consider reports prepared for all testing and monitoring programs, for

all pollutants, including (but not limited to) those required under Title V, compliance with State or local requirements, fulfillment of

contractual obligations, U.S. Department of Energy (DOE) programs, etc. (NOTE: EPA is not requesting copies of the test reports or data

at this time; however we may request actual copies in the future.) Use additional pages as necessary.

Report 1 Unit 1 Particulate Emissions Test (February 22,2005)

Report 2 Unit 2 Particulate Emissions Test (January 5, 2006)

Report 3 Unit 1 Particulate Emissions Test (January 4, 2007)

Report 4 Unit 2 Particulate Emissions Test (January 4, 2007)

Report 5 Unit 1 Particulate Emissions Test (September 24, 2008)

Report 6 Unit 2 Particulate Emissions Test (September 24, 2008)

Report 7 Unit 1 Particulate Emissions Test, FGD Stack (October 30, 2008)

Report 8 Unit 2 Particulate Emissions Test, FGD Stack (May 20, 2009)

Report 9 Unit 1 Economizer Performance (April 1, 2009 to April 9, 2009)

Report 10 Unit 2 Scrubber Particulate Tests (October 27, 2009 to November 6, 2009, final results not yet available)

Report 11 Unit 2 SO3 testing (July to August 2009)

8b Please indicate the date(s) and types (e.g., stack, fuel, parametric, etc.) of the test(s) and the constituents (including criteria and hazardous

air pollutants) sampled for:

Report 1 Date: 2/22/2005 Type: stack Constituents: PM

Report 2 Date: 1/5/2006 Type: stack Constituents: PM

Report 3 Date: 1/4/2007 Type: stack Constituents: PM

Report 4 Date: 1/4/2007 Type: stack Constituents: PM

Report 5 Date: 9/24/2008 Type: stack Constituents: PM

Report 6 Date: 9/24/2008 Type: stack Constituents: PM

Report 7 Date: 10/30/2008 Type: stack Constituents: PM

Report 8 Date: 5/20/2009 Type: stack Constituents: PM

Report 9 Date: 4/1/2009-4/9/2009 Type: duct Constituents: CO

Report 10 Date: 10/27/2009-11/6/2009 Type: duct/stack Constituents: PM

Report 11 Date: July to Aug 2009 Type: duct/stack Constituents: SO3

Page 59 of 73 part II, 8
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

8c Do any of these test reports reflect testing at a location upstream of any emission control devices?

Yes _X___ No ____ If yes, please note which reports and provide a detailed description of the location of the emissions sampling point(s).

Although Report 9 reflects testing at the economizer outlet (upstream of all post-combustion control devices), there are

no control devices downstream designed to reduce CO.

Report 10 reflects testing upstream of the scrubber, at the inlet duct.

Report 11 reflects testing SO3 data was collected at the economizer outlet, SCR outlet, and upstream of the FGD.

8d Were any of these test reports conducted when use of other material(s) or non-fossil fuels were fired in the boiler?

Yes ____ No _X___ If yes, please not which reports and identify the other material(s) or non-fossil fuels used.

8e Do any of these test reports reflect testing during periods of startup, shutdown, and malfunction?

Yes ____ No _X___ If yes, please note which reports.

8f Did the unit's control configuration differ from that shown in Part I, question 16, at the time of these test results?

Yes _X___ No ____ If yes, please list the unit's complete control configuration at time of testing in a similar format to Part I, question 16.

The control configuration shown below is representative of the conditions present during Reports 1, 2, 3, 4.

NOTE: Status of SO3 injection during Report 2 is unknown.

Boiler ID Type NOx control SO2 control PM control Other control

1 tangentialfired(1) low-NOX concentric 

firing system + separated 

overfire air

(3) cold-side 

electrostatic 

precipitator

(2) flue gas 

conditioning (SO3 

injection)

2 tangentialfired(1) low-NOX concentric 

firing system + separated 

overfire air

(3) cold-side 

electrostatic 

precipitator

(2) flue gas 

conditioning (SO3 

injection)

Page 60 of 73 part II, 8
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

The control configuration shown below is representative of the conditions present during Reports 5, 6.

Boiler ID Type NOx control SO2 control PM control Other control

1 tangentialfired(1) low-NOX concentric 

firing system + separated 

overfire air

(2) SCR

(4) cold-side 

electrostatic 

precipitator

(3) flue gas 

conditioning (SO3 

injection)

2 tangentialfired(1) low-NOX concentric 

firing system + separated 

overfire air

(2) SCR

(3) cold-side 

electrostatic 

precipitator

The control configuration shown below is representative of the conditions present during Reports 7, 8, 9.

Boiler ID Type NOx control SO2 control PM control Other control

1 tangentialfired(1) low-NOX concentric 

firing system + separated 

overfire air

(2) SCR

(5) wet flue gas 

desulfurization (FGD)

(4) cold-side 

electrostatic 

precipitator

(3) flue gas 

conditioning (SO3 

injection) 

2 tangentialfired(1) low-NOX concentric 

firing system + separated 

overfire air

(2) SCR

(5) wet flue gas 

desulfurization (FGD)

(4) cold-side 

electrostatic 

precipitator

(3) flue gas 

conditioning (SO3 

injection) 

Page 61 of 73 part II, 8
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

The control configuration shown below is representative of the conditions present during Reports 10, 11.

Boiler ID Type NOx control SO2 control PM control Other control

2 tangentialfired(1) low-NOX concentric 

firing system + separated 

overfire air

(2) SCR

(6) wet flue gas 

desulfurization (FGD)

(4) cold-side 

electrostatic 

precipitator

(3) flue gas 

conditioning (SO3 

injection) 

(5) hydrated lime 

injection

8g Do any of these test reports reflect testing at a location before a post combustion SO2 emission control device (e.g., FGD, SDA, Dry Scrubber)?

Yes _X___ No ____ If yes, please note which reports and, in addition to the detailed description of the location of the sampling point(s)

(question 8c above), include detail about how much, if any, bypass of unscrubbed flue gas was utilized at at the time of testing (including

percentage of total scrubber flue gas flow). Note by diagram where sampling ports were located in relation to the bypass ductwork.

Reports 10, 11 include testing at locations before a post combustion SO2 emission control device.

No bypass of unscrubbed flue gas was utilized at the time of testing.

Page 62 of 73 part II, 8
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

9 What type of deviation reporting is required for violations of permit requirements?

Specified deviations are reported quarterly. Emissions exceeding a standard for 

a period of 4 hours or more are reported within 7 days. 

Other deviations are reported semiannually.

Note: Not all reported deviations are considered violations of permit requirements

10 Are deviation reports available for malfunctions or other periods of noncompliance with permit terms and conditions?

Yes _X__ No ____ If yes, please note which reports.

Deviation reports including periods of malfunction are available where required in quarterly monitor 

breakdown reports and excess emissions, exdeedances, and excursion reports.

Note: A malfunction is not necessarily a period of noncompliance with permit terms and conditions. 

Not all reported deviations are considered violations of permit requirements

11 Are continuous emissions monitoring system (CEMS) data available (e.g., mercury, continuous opacity monitoring systems) that are not

already being provided to the U.S. EPA, even if from short-term testing?

Yes _X__ No ____ If yes46, please note for which pollutants CEMS data are available and the period of time (both total period and calendar

period) for which the data are available. If CEM data are being provided to EPA, please note to which Office the data are being provided.

Mercury CEMS data are available for the following periods of time:

Unit 1 (scrubber stack): Janaury 1, 2009 - December 31, 2009

EPA requested in Footnote 46 to Part II, Question 11 that facilities submit available mercury CEMS data that follow recognized 

QA/QC procedures. While EPA did not make the submittal mandatory, Georgia Power wishes to provide available mercury 

CEMS data in a separate submittal to assist the rulemaking process. Georgia Power has installed and operated monitors on 

certain units that, as closely as possible, follow the QA/QC procedures as written under the vacated Clean Air Mercury Rule 

("CAMR"). However, Georgia Power does not regularly submit reports to a regulatory agency on an ongoing basis. Thus, 

Georgia Power will require additional time to review and prepare the data for submittal to EPA. Georgia Power plans to submit 

this data by May 3, 2010.

COMS data are available for the last five years or more.

46 Where units are monitored by CEMs (either following CAMR, State, or NIST QA/QC procedures), and where data are available, EPA requests

that this CEM data by submitted by the respondent. The respondent should also mark the periods of start up, shut down and malfunction events (SSM) 

in the data sets.

Page 63 of 73 part II, 9-11
GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

12 For each boiler noted in Part I, question 15, provide the following information:

NOTE: Net generation data not available in test reports. Other parameters may or may not be available depending on the test report.

Date of test PM49 SO2 HCl/HF/HCN Metal HAP50 Hg51 CO

Other organics 

(specify)

1 2/22/2005 See Attachment 1 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

2 1/5/2006 See Attachment 2 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

1 1/4/2007 See Attachment 3 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

2 1/4/2007 See Attachment 4 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

1 9/24/2008 See Attachment 5 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

2 9/24/2008 See Attachment 6 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

1 10/30/2008 See Attachment 7 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

2 5/20/2009 See Attachment 8 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

1 4/1/2009-4/9/2009 Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 9 Not applicable

2 10/27/2009-11/6/2009

Final data not yet 

available Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

47 Provide emission test data for all tests conducted since January 1, 2005. Please indicate test data acquired both before and after

any control device. Use additional pages as necessary. EPA may, at some future date, request a copy of one or more emission test reports.

Data generated to fulfill both Federal and State requirements must be provided. Note that data generated pursuant to CAA Title V

must be maintained and available for 5 years. Also include averaging times and measurement units for all pollutants.

48 For each emissions test run the respondent should provide the following process information: Unit Load (MW), Net generation during run (MWh net),

Flue gas moisture content (%), Flue gas flow rate (dscfm or Nm3/hr), Flue gas oxygen content (%, dry), Flue gas carbon dioxide content (%, dry), Flue gas

temperature at sampling point (oF), Flue gas pressure at sampling point (atm), Standard temperature (oF), Standard pressure (atm).

49 If emission testing recorded the emissions of filterable and condensable PM, separately, please include those separate emission results. 

Also, please include separate emission results for total PM, PM10, and PM2.5.

50 Metal HAP include compounds of antimony, arsenic, beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, phosphorus, and selenium;

indicate emission level for all metal HAP for which an emission test has been conducted.

51 Please provide separate results for total Hg, elemental Hg, oxidized Hg, and particulate Hg, as available. If the emissions testing recorded

the amount of unburned carbon in fly ash (as reflected by the "Loss of Ignition" [L.O.I]) at the time of any Hg testing, please include these data.

Boiler 

ID

Emissions test results (indicate format of emission data)47,48

Page 64 of 73 part II, 12
ATTACHMENT 1 - Wansley Report 1 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3

Test Date 2/22/2005 2/22/2005 2/22/2005

Run Start Time 10:40 12:25 14:05

Run End Time 11:55 13:36 15:25

Meter Volume (dacf), Vm: 43.856 43.992 44.474

Sqrt Delta P ("wc): 1.54 1.54 1.54

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.18 29.18 29.14

Delta H ("wc): 1.5 1.5 1.5

Volume in Impingers (mls), VIc: 72.4 74.0 67.5

Static Pressure ("wc), Pg: -3.00 -3.20 -3.40

Stack Pressure ("Hg), Ps: 28.96 28.94 28.89

Stack Temperature (F), Ts: 303 307 309

Meter Coefficient (no units), Y: 0.983 0.983 0.983

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 86 91 93

Stack Diameter (inches): 300 300 300

Area Stack (sq. ft.), As: 490.87 490.87 490.87

Nozzle Diameter (inches), dp: 0.178 0.178 0.178

Area Nozzle (sq. ft.), An: 0.000172 0.000172 0.000172

Percent CO2 (% dry volume): 13.4 13.5 13.2

Percent O2 (% dry volume): 5.3 5.3 5.4

Percent (N2 + CO) (% dry volume): 81.3 81.2 81.4

Particulate Collected (mg), Mn: 64.1 91.5 80.1

Molec. Wt. Dry (lb/lb-mole), Md: 30.357 30.368 30.333

Volume Water (scf), Vwstd 3.408 3.483 3.177

Meter Volume (dscf), Vmstd: 40.776 40.544 40.765

Wet Fraction (v/v), Bws: 0.077 0.079 0.072

Molec. Wt. Wet (lb/lb-mole), Ms: 29.404 29.390 29.441

Stack Gas Sampled (acf), Vma: 65.975 66.075 66.309 Averages

Stack Gas Velocity (fps), Vs: 104.81 105.11 104.95 105

Volumetric Flowrate (dscfm), Qs: 1,907,914 1,899,572 1,900,183 1,902,556

Volumetric Flowrate (acfm), Qa: 3,086,935 3,095,764 3,090,900 3,091,200

Grainloading (gr/dscf), cs: 0.0242 0.0348 0.0303 0.03

Emission Rate (lb/hour), E: 396.36 566.67 493.50 485.5

Percent Isokinetic Sampling (%), I: 101.53 101.40 101.92 101.61

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 8722.74 8698.54 8631.62 8684.30

Emission Rate (lbs/mmBtu), E: 0.045 0.065 0.057 0.056

Allowable Rate (lb/mmBtu): 0.240 0.240 0.240 0.240

Average Unit Gross Load (MW) 950 950 950 950

Particulate Emission Results Summary

Wansley Unit 1

Page 65 of 73 Att. 1
ATTACHMENT 2 - Wansley Report 2 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3

Test Date 1/6/2006 1/5/2006 1/5/2006

Run Start Time 8:20 10:05 11:50

Run End Time 9:35 11:20 13:05

Meter Volume (dacf), Vm: 41.063 41.09 41.558

Sqrt Delta P ("wc): 1.58 1.58 1.58

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 28.85 28.85 28.85

Delta H ("wc): 1.4 1.4 1.4

Volume in Impingers (mls), VIc: 50.8 55.7 59.1

Static Pressure ("wc), Pg: -3.00 -3.10 -3.30

Stack Pressure ("Hg), Ps: 28.63 28.62 28.61

Stack Temperature (F), Ts: 299 301 300

Meter Coefficient (no units), Y: 0.989 0.989 0.989

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 76 78 77

Stack Diameter (inches): 300 300 300

Area Stack (sq. ft.), As: 490.87 490.87 490.87

Nozzle Diameter (inches), dp: 0.174 0.174 0.174

Area Nozzle (sq. ft.), An: 0.000165 0.000165 0.000165

Percent CO2 (% dry volume): 12.5 12.6 12.6

Percent O2 (% dry volume): 6.1 5.9 6.1

Percent (N2 + CO) (% dry volume): 81.4 81.5 81.3

Particulate Collected (mg), Mn: 82.8 73.5 83.8

Molec. Wt. Dry (lb/lb-mole), Md: 30.248 30.257 30.264

Volume Water (scf), Vwstd 2.391 2.622 2.782

Meter Volume (dscf), Vmstd: 38.684 38.611 39.112

Wet Fraction (v/v), Bws: 0.058 0.064 0.066

Molec. Wt. Wet (lb/lb-mole), Ms: 29.535 29.478 29.450

Stack Gas Sampled (acf), Vma: 61.707 62.116 63.089 Averages

Stack Gas Velocity (fps), Vs: 107.32 107.76 108.12 108

Volumetric Flowrate (dscfm), Qs: 1,981,459 1,972,839 1,974,174 1,976,157

Volumetric Flowrate (acfm), Qa: 3,160,750 3,173,860 3,184,433 3,173,014

Grainloading (gr/dscf), cs: 0.0330 0.0294 0.0330 0.03

Emission Rate (lb/hour), E: 560.73 496.83 559.22 538.9

Percent Isokinetic Sampling (%), I: 96.79 97.03 98.22 97.34

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 8627.60 8686.59 8595.88 8636.69

Emission Rate (lbs/mmBtu), E: 0.06 0.06 0.07 0.06

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.240

Average Unit Gross Load (MW) 949 949 949 949

Particulate Emission Results Summary

Wansley Unit 2

Page 66 of 73 Att. 2
ATTACHMENT 3 - Wansley Report 3 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3

Test Date 1/4/2007 1/4/2007 1/4/2007

Run Start Time 9:15 11:05 12:35

Run End Time 10:35 12:15 13:45

Meter Volume (dacf), Vm: 41.809 42.055 43.739

Sqrt Delta P ("wc): 1.54 1.55 1.56

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.18 29.18 29.20

Delta H ("wc): 1.5 1.5 1.5

Volume in Impingers (mls), VIc: 66.2 65.1 68.3

Static Pressure ("wc), Pg: -3.40 -3.30 -3.30

Stack Pressure ("Hg), Ps: 28.93 28.94 28.96

Stack Temperature (F), Ts: 300 304 308

Meter Coefficient (no units), Y: 0.987 0.987 0.987

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 75 82 85

Stack Diameter (inches): 300 300 300

Area Stack (sq. ft.), As: 490.87 490.87 490.87

Nozzle Diameter (inches), dp: 0.178 0.178 0.178

Area Nozzle (sq. ft.), An: 0.000173 0.000173 0.000173

Percent CO2 (% dry volume): 12.2 12.2 12.1

Percent O2 (% dry volume): 7.0 6.9 7.0

Percent (N2 + CO) (% dry volume): 80.8 80.8 80.8

Particulate Collected (mg), Mn: 66.6 64.4 66.4

Molec. Wt. Dry (lb/lb-mole), Md: 30.232 30.235 30.223

Volume Water (scf), Vwstd 3.116 3.064 3.215

Meter Volume (dscf), Vmstd: 39.825 39.552 40.946

Wet Fraction (v/v), Bws: 0.073 0.072 0.073

Molec. Wt. Wet (lb/lb-mole), Ms: 29.344 29.355 29.333

Stack Gas Sampled (acf), Vma: 63.932 63.794 66.334 Averages

Stack Gas Velocity (fps), Vs: 104.75 105.26 106.19 105

Volumetric Flowrate (dscfm), Qs: 1,921,764 1,922,188 1,930,527 1,924,826

Volumetric Flowrate (acfm), Qa: 3,085,013 3,100,284 3,127,493 3,104,263

Grainloading (gr/dscf), cs: 0.0258 0.0251 0.0250 0.03

Emission Rate (lb/hour), E: 425.15 414.23 413.89 417.8

Percent Isokinetic Sampling (%), I: 98.17 97.48 100.48 98.71

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 7841.17 7880.52 7858.04 7859.91

Emission Rate (lbs/mmBtu), E: 0.05 0.05 0.05 0.053

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.240

Average Unit Gross Load (MW) 949 949 950 949

Particulate Emission Results Summary

Wansley Unit 1

Page 67 of 73 Att. 3
ATTACHMENT 4 - Wansley Report 4 Test Results

Performed Dy: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3

Test Date 1/4/2007 1/4/2007 1/4/2007

Run Start Time 9:15 11:05 12:35

Run End Time 10:35 12:15 13:45

Meter Volume (dacf), Vm: 43.422 44.895 44.833

Sqrt Delta P ("wc): 1.59 1.59 1.59

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.18 29.18 29.20

Delta H ("wc): 1.6 1.6 1.6

Volume in Impingers (mls), VIc: 71.7 73.5 73.0

Static Pressure ("wc), Pg: -3.30 -3.10 -3.20

Stack Pressure ("Hg), Ps: 28.94 28.95 28.96

Stack Temperature (F), Ts: 296 300 304

Meter Coefficient (no units), Y: 0.997 0.997 0.997

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 73 79 82

Stack Diameter (inches): 300 300 300

Area Stack (sq. ft.), As: 490.87 490.87 490.87

Nozzle Diameter (inches), dp: 0.178 0.178 0.178

Area Nozzle (sq. ft.), An: 0.000172 0.000172 0.000172

Percent CO2 (% dry volume): 12.1 12.2 12.2

Percent O2 (% dry volume): 7.2 7.2 7.2

Percent (N2 + CO) (% dry volume): 80.7 80.6 80.6

Particulate Collected (mg), Mn: 62.6 62.6 65.6

Molec. Wt. Dry (lb/lb-mole), Md: 30.228 30.235 30.241

Volume Water (scf), Vwstd 3.375 3.460 3.434

Meter Volume (dscf), Vmstd: 41.941 42.923 42.670

Wet Fraction (v/v), Bws: 0.074 0.075 0.074

Molec. Wt. Wet (lb/lb-mole), Ms: 29.317 29.322 29.330

Stack Gas Sampled (acf), Vma: 67.110 69.011 68.895 Averages

Stack Gas Velocity (fps), Vs: 108.02 107.72 108.12 108

Volumetric Flowrate (dscfm), Qs: 1,988,293 1,973,246 1,972,290 1,977,943

Volumetric Flowrate (acfm), Qa: 3,181,458 3,172,513 3,184,506 3,179,492

Grainloading (gr/dscf), cs: 0.0230 0.0225 0.0237 0.02

Emission Rate (lb/hour), E: 392.65 380.76 401.31 391.6

Percent Isokinetic Sampling (%), I: 100.21 103.34 102.78 102.11

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 8015.35 7935.38 7912.24 7954.32

Emission Rate (lbs/mmBtu), E: 0.05 0.05 0.05 0.049

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.240

Average Unit Gross Load (MW) 950 950 950 950

Particulate Emission Results Summary

Wansley Unit 2

Page 68 of 73 Att. 4
ATTACHMENT 5 - Wansley Report 5 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3

Test Date 9/24/2008 9/24/2008 9/24/2008

Run Start Time 6:35 8:15 09:45

Run End Time 7:45 9:25 10:55

Meter Volume (dacf), Vm: 43.665 45.685 45.588

Sqrt Delta P ("wc): 1.54 1.57 1.57

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.22 29.22 29.22

Delta H ("wc): 1.5 1.6 1.6

Volume in Impingers (mls), VIc: 66.9 67.6 67.5

Static Pressure ("wc), Pg: -3.70 -3.70 -3.60

Stack Pressure ("Hg), Ps: 28.95 28.95 28.96

Stack Temperature (F), Ts: 311 315 316

Meter Coefficient (no units), Y: 0.998 0.998 0.998

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 82 84 87

Stack Diameter (inches): 300 300 300

Area Stack (sq. ft.), As: 490.87 490.87 490.87

Nozzle Diameter (inches), dp: 0.178 0.178 0.178

Area Nozzle (sq. ft.), An: 0.000173 0.000173 0.000173

Percent CO2 (% dry volume): 11.9 11.8 11.9

Percent O2 (% dry volume): 6.5 6.5 6.5

Percent (N2 + CO) (% dry volume): 81.6 81.6 81.7

Particulate Collected (mg), Mn: 118.5 133.1 135.8

Molec. Wt. Dry (lb/lb-mole), Md: 30.164 30.155 30.157

Volume Water (scf), Vwstd 3.149 3.182 3.177

Meter Volume (dscf), Vmstd: 41.591 43.358 43.068

Wet Fraction (v/v), Bws: 0.070 0.068 0.069

Molec. Wt. Wet (lb/lb-mole), Ms: 29.308 29.324 29.322

Stack Gas Sampled (acf), Vma: 67.510 70.597 70.208 Averages

Stack Gas Velocity (fps), Vs: 105.55 107.53 107.65 107

Volumetric Flowrate (dscfm), Qs: 1,915,104 1,945,128 1,944,829 1,935,020

Volumetric Flowrate (acfm), Qa: 3,108,560 3,167,158 3,170,408 3,148,709

Grainloading (gr/dscf), cs: 0.0440 0.0473 0.0487 0.05

Emission Rate (lb/hour), E: 721.66 789.43 811.05 774.0

Percent Isokinetic Sampling (%), I: 102.59 105.30 104.61 104.17

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 8095.08 8202.95 8239.75 8179.26

Emission Rate (lbs/mmBtu), E: 0.09 0.10 0.10 0.09

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit Gross Load (MW) 919 919 919 919

Particulate Emission Results Summary

Wansley Unit 1

Page 69 of 73 Att. 5
ATTACHMENT 6 - Wansley Report 6 Test Results

Performed Dy: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3

Test Date 9/24/2008 9/24/2008 9/24/2008

Run Start Time 11:15 12:45 14:15

Run End Time 12:25 13:55 15:25

Meter Volume (dacf), Vm: 45.585 44.11 44.117

Sqrt Delta P ("wc): 1.55 1.57 1.57

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.20 29.20 29.20

Delta H ("wc): 1.6 1.6 1.6

Volume in Impingers (mls), VIc: 70.6 66.6 66.3

Static Pressure ("wc), Pg: -3.30 -3.00 -3.20

Stack Pressure ("Hg), Ps: 28.96 28.98 28.96

Stack Temperature (F), Ts: 310 314 316

Meter Coefficient (no units), Y: 0.998 0.998 0.998

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 89 91 93

Stack Diameter (inches): 300 300 300

Area Stack (sq. ft.), As: 490.87 490.87 490.87

Nozzle Diameter (inches), dp: 0.178 0.178 0.178

Area Nozzle (sq. ft.), An: 0.000173 0.000173 0.000173

Percent CO2 (% dry volume): 11.8 11.6 11.8

Percent O2 (% dry volume): 6.7 6.8 6.7

Percent (N2 + CO) (% dry volume): 81.5 81.6 81.5

Particulate Collected (mg), Mn: 127.2 112.1 101.9

Molec. Wt. Dry (lb/lb-mole), Md: 30.157 30.127 30.160

Volume Water (scf), Vwstd 3.323 3.135 3.121

Meter Volume (dscf), Vmstd: 42.856 41.345 41.167

Wet Fraction (v/v), Bws: 0.072 0.070 0.070

Molec. Wt. Wet (lb/lb-mole), Ms: 29.282 29.272 29.303

Stack Gas Sampled (acf), Vma: 69.561 67.341 67.265 Averages

Stack Gas Velocity (fps), Vs: 106.33 107.86 107.63 107

Volumetric Flowrate (dscfm), Qs: 1,929,459 1,950,384 1,940,074 1,939,972

Volumetric Flowrate (acfm), Qa: 3,131,756 3,176,727 3,170,004 3,159,496

Grainloading (gr/dscf), cs: 0.0458 0.0418 0.0382 0.04

Emission Rate (lb/hour), E: 757.40 699.36 635.14 697.3

Percent Isokinetic Sampling (%), I: 105.22 100.42 100.52 102.06

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 8023.60 8091.53 8105.71 8073.61

Emission Rate (lbs/mmBtu), E: 0.09 0.09 0.08 0.09

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit Gross Load (MW) 919 919 919 919

Particulate Emission Results Summary

Wansley Unit 2

Page 70 of 73 Att. 6
ATTACHMENT 7 - Wansley Report 7 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3

Test Date 10/30/2008 10/30/2008 10/30/2008

Run Start Time 11:05 13:40 16:00

Run End Time 12:20 14:55 17:20

Meter Volume (dacf), Vm: 36.296 36.348 36.594

Sqrt Delta P ("wc): 0.81 0.81 0.81

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.50 29.55 29.57

Delta H ("wc): 1.0 1.0 1.0

Volume in Impingers (mls), VIc: 109.3 107.2 105.4

Static Pressure ("wc), Pg: -0.90 -0.85 -0.90

Stack Pressure ("Hg), Ps: 29.43 29.49 29.50

Stack Temperature (F), Ts: 122 123 122

Meter Coefficient (no units), Y: 0.998 0.998 0.998

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 75 78 80

Stack Diameter (inches): 408 408 408

Area Stack (sq. ft.), As: 907.92 907.92 907.92

Nozzle Diameter (inches), dp: 0.217 0.217 0.217

Area Nozzle (sq. ft.), An: 0.000257 0.000257 0.000257

Percent CO2 (% dry volume): 10.9 10.9 10.9

Percent O2 (% dry volume): 8.0 8.0 8.0

Percent (N2 + CO) (% dry volume): 81.1 81.1 81.0

Particulate Collected (mg), Mn: 33.1 23.0 20.5

Molec. Wt. Dry (lb/lb-mole), Md: 30.063 30.064 30.071

Volume Water (scf), Vwstd 5.145 5.046 4.961

Meter Volume (dscf), Vmstd: 35.326 35.228 35.341

Wet Fraction (v/v), Bws: 0.127 0.125 0.123

Molec. Wt. Wet (lb/lb-mole), Ms: 28.529 28.553 28.585

Stack Gas Sampled (acf), Vma: 45.353 45.147 45.057 Averages

Stack Gas Velocity (fps), Vs: 48.32 48.36 48.51 48

Volumetric Flowrate (dscfm), Qs: 2,050,081 2,055,589 2,072,637 2,059,436

Volumetric Flowrate (acfm), Qa: 2,631,989 2,634,381 2,642,456 2,636,275

Grainloading (gr/dscf), cs: 0.0145 0.0101 0.0089 0.01

Emission Rate (lb/hour), E: 254.25 177.11 158.62 196.7

Percent Isokinetic Sampling (%), I: 101.59 101.04 100.53 101.05

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 7783.01 7783.81 7828.08 7798.30

Emission Rate (lbs/mmBtu), E: 0.03 0.02 0.02 0.03

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit Gross Load (MW) 934 934 934 934

Particulate Emission Results Summary

Wansley Unit 1 FGD

Page 71 of 73 Att. 7
ATTACHMENT 8 - Wansley Report 8 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3

Test Date 5/20/2009 5/20/2009 5/20/2009

Run Start Time 9:45 11:35 13:15

Run End Time 11:00 12:45 13:25

Meter Volume (dacf), Vm: 36.049 36.863 36.955

Sqrt Delta P ("wc): 0.81 0.83 0.84

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.10 29.10 29.10

Delta H ("wc): 1.0 1.0 1.0

Volume in Impingers (mls), VIc: 102.7 106.1 109.1

Static Pressure ("wc), Pg: -0.70 -0.75 -0.75

Stack Pressure ("Hg), Ps: 29.05 29.04 29.04

Stack Temperature (F), Ts: 125 125 126

Meter Coefficient (no units), Y: 0.985 0.985 0.985

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 83 87 89

Stack Diameter (inches): 408 408 408

Area Stack (sq. ft.), As: 907.92 907.92 907.92

Nozzle Diameter (inches), dp: 0.214 0.214 0.214

Area Nozzle (sq. ft.), An: 0.000250 0.000250 0.000250

Percent CO2 (% dry volume): 12.5 12.4 12.6

Percent O2 (% dry volume): 6.1 6.1 6.0

Percent (N2 + CO) (% dry volume): 81.5 81.5 81.4

Particulate Collected (mg), Mn: 43.8 45.1 31.2

Molec. Wt. Dry (lb/lb-mole), Md: 30.237 30.233 30.256

Volume Water (scf), Vwstd 4.834 4.994 5.135

Meter Volume (dscf), Vmstd: 33.650 34.133 34.103

Wet Fraction (v/v), Bws: 0.126 0.128 0.131

Molec. Wt. Wet (lb/lb-mole), Ms: 28.700 28.672 28.652

Stack Gas Sampled (acf), Vma: 43.899 44.657 44.829 Averages

Stack Gas Velocity (fps), Vs: 48.88 49.87 50.35 50

Volumetric Flowrate (dscfm), Qs: 2,041,131 2,076,413 2,086,731 2,068,092

Volumetric Flowrate (acfm), Qa: 2,662,811 2,716,635 2,743,037 2,707,495

Grainloading (gr/dscf), cs: 0.0201 0.0204 0.0141 0.02

Emission Rate (lb/hour), E: 350.98 362.45 252.09 321.8

Percent Isokinetic Sampling (%), I: 99.71 99.42 98.84 99.33

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 8887.42 9020.73 9126.81 9011.65

Emission Rate (lbs/mmBtu), E: 0.04 0.04 0.03 0.04

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit Gross Load (MW) 919 919 919 919

Particulate Emission Results Summary

Wansley Unit 2 FGD

Page 72 of 73 Att. 8
ATTACHMENT 9 - Wansley Report 9 Test Results

Title of 

Run

Description Date

Start 

Time

End 

Time

Unit 

Load

Avg. 

Econ. Gas 

Outlet CO 

Avg. 

Econ. Gas 

Outlet O2 

Avg. 

Econ. Gas 

Outlet 

CO2

Avg. 

Econ. Gas 

Outlet 

Temp

Military Military MW ppm % Dry % Dry Deg F 

1 Baseline Econ Test 4/1/2009 6:49 7:52 920 26 3.87 14.67 687

2 Baseline Econ Test 4/1/2009 8:31 9:45 920 30 3.82 14.74 687

3 Econ Test CO Creation Test, E 

Mill Out of Service

4/1/2009 11:25 12:39 920 97 3.48 15.03 681

4 Low Load Baseline Test 4/9/2009 15:26 16:29 460 15 4.9 13.86 634

5 Low Load Tuned Test [Closed 

off Sofa 6 to 5% (from 10%); 

Closed off Sofa 5 to 5% (from 

30%); Sofa 1 -4 all at 5% (no 

change)]

4/9/2009 21:00 22:06 461 17 4.7 14.01 637

Economizer Performance Test Results Summary

Wansley Unit 1

Page 73 of 73 Att. 9