### 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

1Name of legal owner of facility:

Georgia Power, Oglethorpe Power Corporation (OPC), Municipal Electric Authority of Georgia (MEAG), and Dalton Utilities (DU). 2Name of legal operator of facility, if different from legal owner:

Georgia Power 3Address of ____ legal owner or _X__ operator:

241 Ralph McGill Blvd NE, Bin 10221 Atlanta, GA 30308 4aPlant 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 4bEIA 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 5Complete street address of facility (physical location):

1371 Liberty Church Road Carrollton, GA 30116-7343 6Provide mailing address if different:

241 Ralph McGill Blvd NE, Bin 10221 Atlanta, GA 30308 7Name and title of contact(s) able to answer technical questions about the completed survey:

Sarah Markham, Engineer II 8Contact(s) telephone number(s):

(205) 257-6780 and e-mail address(es):

sasander@southernco.com 9Is 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

10Which 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)

11Which 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)

12If 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 (% _____)

13If 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

14aIf "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.

14bIf "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.
2If 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).
3In 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").
4If 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).
5If 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 None in 2009 Synfuel Used Oil Yes None in 2009 

### Quantity/year None in 2009 None in 2009 

### Actually burn None in 2009 None in 2009 

### Permitted to burn Other Material 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

15Identification (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 ID6Original design fuel (i.e.,coal rank or type of oil)Design heat input,(MMBtu/hr)7Present maximum heatinput, (MMBtu/hr)8MWe Gross capacitysummerMWe Net CapacitysummerOriginal design grossefficiency (%, HHV)Present operating grossefficiency (%, HHV)Design steam pressure(psig)Operating steam pressure(psig)Design steam temperature(oF)Operating steamtemperature (oF)Design steam reheattemperature (oF)9Operating steam reheattemperature (oF)10Fuel11Hours/year operated12Average annual capacityfactor for the past 3 yearsApplicable NSPSEstimated year ofretirement13

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

6Boiler 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).
7Per fuel burned in the boiler. Report this based on higher heating value (HHV).
8Per fuel burned in the boiler. Report this based on higher heating value (HHV).
9Please indicate if more than one steam reheat cycle is utilized, and, if so, please provide information for both.
10Please indicate if more than one steam reheat cycle is utilized, and, if so, please provide information for both.
11Indicate the fuels utilized for the indicated boiler, and percentages, as indicated in questions 11 - 13.
12The "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.
13This 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

15Identification (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 ID6Original design fuel (i.e.,coal rank or type of oil)Design heat input,(MMBtu/hr)7Present maximum heatinput, (MMBtu/hr)8MWe Gross capacitysummerMWe Net CapacitysummerOriginal design grossefficiency (%, HHV)Present operating grossefficiency (%, HHV)Design steam pressure(psig)Operating steam pressure(psig)Design steam temperature(oF)Operating steamtemperature (oF)Design steam reheattemperature (oF)9Operating steam reheattemperature (oF)10Fuel11Hours/year operated12Average annual capacityfactor for the past 3 yearsApplicable NSPSEstimated year ofretirement13



### 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

16For 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)

14Boiler 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).
15Examples: tangential-fired; cyclone; wall-fired; circulating fluidized bed (CFB)
16Examples: 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

16For 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?
17Examples: 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.
18Examples: 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.
19Please 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

17For 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

20A 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.
21Boiler 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

18For 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

22Boiler 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).
23If 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

19For 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

24Boiler 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

20For 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 dateExpected 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

25Boiler 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).
26If 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

21For 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)

27Boiler 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).
28If 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.
29List the compliance test method utilized.
30List the compliance test method utilized.
31Metal 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

22For 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



### 23Was any other guarantee level sought or offered? ____ Yes

_X___ No Please elaborate.

32Boiler 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).
33If the boiler has separate guaranteed emission rate for filterable and condensable PM, respectively, please indicate those separate emission rates.
34Metal 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

24For 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

35Boiler 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).
36If 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.
37Metal 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

25For 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]

26Are 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.

38This 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



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

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

6052

39The 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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 MTNTRAIN 1.06 7.59 13,807

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

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

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

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

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

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

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

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

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

10,936 1, 2 TN ANDERSON PEE WEE, WALNUT MTNTRAIN 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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, LOGANALMA TRAIN 0.64 11.12 13,462 11,982 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.72 12.59 13,207 12,128 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.73 13.09 13,172 11,987 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.68 12.02 13,285 12,053 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.8 12.39 13,251 12,072 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 1.1 12.87 13,122 9,972 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 1.01 12.13 13,205 0 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.76 12.49 13,261 10,792 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.76 12.49 13,261 10,854 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.87 12.14 13,247 10,505 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.92 12.18 13,325 12,132 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.75 13.15 13,015 11,603 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.71 12.18 13,228 10,618 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.75 12.18 13,192 12,096 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.66 11.36 13,426 12,040 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.77 13.66 12,972 12,082 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.8 12.94 13,253 11,644 1, 2 KY, WV LESLIE, LOGANALMA 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

2For 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, LOGANALMA TRAIN 0.72 13.26 13,089 11,892 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.78 12.1 13,289 11,934 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.75 12.4 13,222 11,854 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 1.02 12.66 13,155 12,030 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 1.02 12.69 13,205 11,987 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.84 12.72 13,150 10,561 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.74 10.87 13,420 11,138 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.67 10.74 13,499 10,768 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.89 11.68 13,320 10,819 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.83 11.67 13,387 10,239 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.75 11.83 13,351 10,073 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.99 10.77 13,482 11,791 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.64 10.96 13,546 0 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 12,078 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.87 11.85 13,323 12,044 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.75 13.15 12,834 11,315 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.67 11.02 13,366 9,984 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.79 11.57 13,388 10,263 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.82 10.78 13,542 9,946 1, 2 KY, WV LESLIE, LOGANALMA TRAIN 0.9 12.13 13,350 11,931 1, 2 KY, WV LESLIE, LOGANALMA 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

2For 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 MTNTRAIN 1.07 8.56 13,632

11,663 1, 2 TN ANDERSON PEE WEE, WALNUT MTNTRAIN 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

2For 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

40EPA recognizes that facilities have (sometimes) several months inventory and that the amount received is not necessarily the same as the amount fired.
41Boiler 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).
42If known.



### Page 47 of 73 part II, 2 (coal)

### GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631 April 5, 2010

2For 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

43If known.



### Page 48 of 73 part II, 2 (coal)

### GEORGIA POWER - PLANT WANSLEY

EGU HAPs ICR, OMB Control No. 2060-0631 April 5, 2010

2For 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

2For 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

40EPA recognizes that facilities have (sometimes) several months inventory and that the amount received is not necessarily the same as the amount fired.
41Boiler 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).
42If known.
43If known.



### Page 50 of 73 part II, 2 (oil)

### GEORGIA POWER - PLANT WANSLEY EGU HAPs ICR, OMB Control No. 2060-0631 April 5, 2010

3For 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 0.8IN 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 2.1KY, 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 2.3VA 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 5.3Colombia , 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 2.8KY 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 3.7WV 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 3.0KY 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 2.7KY 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 3.6KY 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 1.0IN 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

3For 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 2.2VA Lee Creech, House CoalTrain

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 3.4TN 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 2.9TN Clairborne Walnut Mountain, Windrock, Pee WeeTrain 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 4.8WV 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 3.9KY 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 2.5VA 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 1.9VA 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 2.8KY 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 3.7WV 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 3.9KY 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 2.7KY 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 2.4KY 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

3For 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 3.5TN Clairborne Walnut Mountain, Windrock, Pee WeeTrain

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 3.8TN 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 3.9KY 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 4.7WV 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 2.5VA 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 2.1VA 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 3.4KY 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 2.9KY 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 4.7WV 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 0.9IN 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 3.4WV 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 2.7KY 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

3For 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 2.2KY 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 4.1KY 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 4.3TN Clairborne Walnut Mountain, Windrock, Pee WeeTrain

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 3.6TN 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 2.2KY 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 3.1KY 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 4.1TN Clairborne Walnut Mountain, Windrock, Pee WeeTrain

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 3.9TN 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 2.8VA 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 0.9WV 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 1.0IL 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 4.8WV 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 4.0KY 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

3For 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 2.7VA 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 4.1KY 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 3.1KY Pike Lower Elkhorn, Elkhorn , Alma, Clintwood Train

44To 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.
45Metal 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

4Were 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__)

5Analyses 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 6Name 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

7In 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

MoistureVolatiles Ash Fixed Carbon Carbon Hydrogen Nitrogen Total Sulfur Oxygen Barium Copper Magnesium Sodium Vanadium Zinc Al2O3Fe2O3 CaO MgO MnO2P2O5 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 ND0.491 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 7.960.992 1.25 ND ND 3.05 54.2 0.5540.561 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 60.70.296 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 0.3970.715 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 1.080.968 ND ND 2.46 56.40.272 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 0.840.024 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 0.3360.658 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 1.080.756 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 54.70.412 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 1.40.924 ND ND 2.4 52.60.5670.862 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 58.70.352 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 7.170.964 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 ND0.459 2.41 58.5 0.615 1.21 1.4 Sample ID # Proximate Analyses, % by wt Ultimate Analyses, % by wt Ash Mineralogy, % by wt Other Trace Metals, ppm, dry basis

Page 57 of 73 part II, 7

### GEORGIA POWER - PLANT WANSLEY EGU HAPs ICR, OMB Control No. 2060-0631 April 5, 2010

7In 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

MoistureVolatiles Ash Fixed Carbon Carbon Hydrogen Nitrogen Total Sulfur Oxygen Barium Copper Magnesium Sodium Vanadium Zinc Al2O3Fe2O3 CaO MgO MnO2P2O5 K2O SiO2 Na2O SO3 TiO2 Sample ID # Proximate Analyses, % by wt Ultimate Analyses, % by wt Ash Mineralogy, % by wt Other Trace Metals, ppm, dry basis

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 ND0.502 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 3.070.839 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 52.70.375 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 58.40.542 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 2.43 580.509 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 0.540.715 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 4.360.883 0.64 ND ND 2.1 56.5 0.370.272 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 0.80.026 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 57.80.292 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 53.70.519 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 51.80.507 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 47.70.501 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 ND0.441 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 1.040.132 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 49.40.581 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 ND0.477 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 4.080.902 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 ND0.403 2.65 52.40.435 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 0.880.998 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 3.760.833 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 1.060.932 ND ND 2.8 58.40.3540.504 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 ND0.353 2.64 58.40.431 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

8aWhat 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 10Unit 2 Scrubber Particulate Tests (October 27, 2009 to November 6, 2009, final results not yet available) Report 11Unit 2 SO3 testing (July to August 2009)

8bPlease 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

8cDo 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.

8dWere 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.

8eDo any of these test reports reflect testing during periods of startup, shutdown, and malfunction? Yes ____ No _X

___If yes, please note which reports.

8fDid 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



### 8gDo 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

9What 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

10Are 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

11Are 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.

46Where 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

12For 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 9Not 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

47Provide 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.
48For 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).
49If 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. 50Metal 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.
51Please 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