### GEORGIA POWER - Submittal for PLANT BOWEN

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

3Address of _X__ legal owner or ____ 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):

Bowen 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):

703 5Complete street address of facility (physical location):

317 Covered Bridge Road Cartersville, Georgia 30120 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 121 part I, 1-14

### GEORGIA POWER - Submittal for PLANT BOWEN

Electric Utility Steam Generating Unit (EGU) Hazardous Air Pollutant Emissions (HAPs) Information Collection Request (ICR), OMB Control No. 2060-0631 April 5, 2010

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 121 part I, 1-14

### GEORGIA POWER - Submittal for PLANT BOWEN

Electric Utility Steam Generating Unit (EGU) Hazardous Air Pollutant Emissions (HAPs) Information Collection Request (ICR), OMB Control No. 2060-0631 April 5, 2010

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 Yes 

### Permitted to burn

Yes 

### Other Material Sawdust Biomass Used Oil 

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

### Actually burn None in 2009 None in 2009 None in 2009 None in 2009 Synfuel Yes None in 2009 None in 2009



### Page 3 of 121 part I, 1-14

### GEORGIA POWER - PLANT BOWEN

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 coal CBI CBI 740 693 89.1 88.9 3500 3500 1000 1000 1000 1000 bituminous coal (100%), distillate oil (100%) CBI CBI Not applicableNone

planned

2 bituminous coal CBI CBI 755 700 89.1 88.2 3500 3500 1000 1000 1000 993 bituminous coal (100%), distillate oil (100%) CBI CBI Not applicableNone

planned

3 bituminous coal CBI CBI 933 876 88.7 89.6 3500 3500 1000 998 1000 975 bituminous coal (100%), distillate oil (100%) CBI CBI Not applicableNone

planned

4 bituminous coal CBI CBI 933 876 88.7 89.9 3500 3500 1000 1000 1000 991 bituminous coal (100%), distillate oil (100%) CBI CBI Not applicableNone

planned

6

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
7

### Per fuel burned in the boiler. Report this based on higher heating value (HHV).
8

### Per fuel burned in the boiler. Report this based on higher heating value (HHV).
9

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

### Please indicate if more than one steam reheat cycle is utilized, and, if so, please provide information for both.
11

### Indicate the fuels utilized for the indicated boiler, and percentages, as indicated in questions 11 - 13.
12

### The "hours/year operated" would be the average of the actual number of hours the unit operated in 1 year based on the last 3 years of operation.
13

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

### NOTES: Original Design Fuel

Based on the original contract boiler data sheet; only the primary fuel is listed if multiple fuels were included on the data sheet. Design Heat Input Confidentail Business Information Present Maximum Heat Input Confidentail Business Information MWe Gross Capacity Summer Identifies the gross normal full load. Georgia Power does not change unit capacities season from season.

Page 4 of 121 part I, 15

### GEORGIA POWER - PLANT BOWEN

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



### 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. 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 Confidentail Business Information Annual Average Capacity Factor for the Past 3 Years Confidentail Business Information Applicable NSPS Where no NSPS is identified, the unit is not currently subject to any NSPS. Retirement Year Georgia Power has not committed to actual retirement dates for Plant Bowen Units 1-4. 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 121 part I, 15

### GEORGIA POWER - PLANT BOWEN

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 and lime injection 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 (5/1994)(2) SCR (4/2001), using titaniavanadia catalyst and anhydrous ammonia reductant; the catalyst is designed to reduce SO3 formation (SEE NOTES). (7) wet flue gas desulfurization (FGD) (4/2010), calcium-based. (5) cold-side electrostatic precipitator (ESP) (10/1971, original install; 4/1981, retrofit ESP arranged in parallel with original ESP) (3) flue gas conditioning - SO3 injection (1998) (6) hydrated lime injection (SO3 control, 4/2010) (4) flue gas conditioning - ammonia (SO3 control, 6/2004)

2 tangential-fired(1) low-NOX concentric firing system + separated overfire air (12/1992)(2) SCR (6/2001), using titaniavanadia catalyst and anhydrous ammonia reductant; the catalyst is designed to reduce SO3 formation (SEE NOTES). (7) wet flue gas desulfurization (FGD) (5/2009), calcium-based. (5) cold-side electrostatic precipitator (ESP) (9/1972, original install; 1/1981, retrofit ESP arranged in parallel with original ESP) (3) flue gas conditioning - SO3 injection (1998) (6) hydrated lime injection (SO3 control, 5/2009) (4) flue gas conditioning - ammonia (SO3 control, 6/2004)

3 tangential-fired(1) low-NOX concentric firing system + separated overfire air (11/1993)(2) SCR (5/2003), using titaniavanadia catalyst and anhydrous ammonia reductant; the catalyst is designed to reduce SO3 formation (SEE NOTES). (7) wet flue gas desulfurization (FGD) (5/2008), calcium-based. (5) cold-side electrostatic precipitator (ESP) (12/1974, original install) (3) flue gas conditioning - SO3 injection (9/1992) (6) hydrated lime injection (SO3 control, 5/2008) (4) flue gas conditioning - ammonia (SO3 control, 3/2006)



### Page 6 of 121 part I, 16

### GEORGIA POWER - PLANT BOWEN

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 and lime injection 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
4 tangential-fired(1) low-NOX concentric firing system + separated overfire air (5/1993)(2) SCR (5/2003), using titaniavanadia catalyst and anhydrous ammonia reductant; the catalyst is designed to reduce SO3 formation (SEE NOTES). (7) wet flue gas desulfurization (FGD) (12/2008), calcium-based. (5) cold-side electrostatic precipitator (ESP) (11/1975, original install) (3) flue gas conditioning - SO3 injection (9/1992) (6) hydrated lime injection (SO3 control, 12/2008) (4) flue gas conditioning - ammonia (SO3 control, 3/2006)

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 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 121 part I, 16

### GEORGIA POWER - PLANT BOWEN

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 3 Not applicable Not applicable Not applicable Not applicable 4 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 121 part I, 17

### GEORGIA POWER - PLANT BOWEN

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-dateType 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 3 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 4 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 121 part I, 18

### GEORGIA POWER - PLANT BOWEN

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 3 Not applicable Not applicable Not applicable Not applicable 4 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 121 part I, 19

### GEORGIA POWER - PLANT BOWEN

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 3 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 4 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 121 part I, 20

### GEORGIA POWER - PLANT BOWEN

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

applicable3% 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, 2012 (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

applicableNOx: 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)
Other NOx Multi-Unit Plans: Southern Company Phase II NOx Averaging Plan 0.46 lb/MMBtu annual average over all units; 7-plant NOx cap 32, 335.8 tons from May 1 to September 30 (Title V permit; 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

applicable3% 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

applicableNOx: 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)
Other NOx Multi-Unit Plans: Southern Company Phase II NOx Averaging Plan 0.46 lb/MMBtu annual average over all units; 7-plant NOx cap 32, 335.8 tons from May 1 to September 30 (Title V permit; determined by CEMS).

3 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

applicable3% 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

applicableNOx: 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)
Other NOx Multi-Unit Plans: Southern Company Phase II NOx Averaging Plan 0.46 lb/MMBtu annual average over all units; 7-plant NOx cap 32, 335.8 tons from May 1 to September 30 (Title V permit; determined by CEMS). 

### Permitted emission limit (indicate type of permit and format of emission limit)
Boiler ID27



### Page 12 of 121 part I, 21

### GEORGIA POWER - PLANT BOWEN

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) Permitted emission limit (indicate type of permit and format of emission limit)
Boiler ID27



### 4 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

applicable3% 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

applicableNOx: 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)
Other NOx Multi-Unit Plans: Southern Company Phase II NOx Averaging Plan 0.46 lb/MMBtu annual average over all units; 7-plant NOx cap 32, 335.8 tons from May 1 to September 30 (Title V permit; determined by CEMS).

27

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
28

### If the boiler has separate permitted emission limits for filterable and condensable PM, respectively, please indicate those separate limits. Also include the compliance test method utilized.
29

### List the compliance test method utilized.
30

### List the compliance test method utilized.
31

### Metal HAP include compounds of antimony, arsenic, beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, phosphorus, and selenium; indicate permit level for all metal HAP for which a permit level has been developed.



### Page 13 of 121 part I, 21

### GEORGIA POWER - PLANT BOWEN

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 scrubber 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: 98.7 % collection efficiency filterable (expired in 1999) Not applicableNot

applicableFGD: 98% instantaneous removal efficiency to

meet a 95% 30-day rolling average removal efficiency (SEE NOTES) Not applicableNot

applicableNot

applicableNot

applicableNot

applicableNot

applicableLow NOx Burners: 0.45 lb/MMBtu (expired in

1994)

2 ESP rebuild: 98.7 % collection efficiency filterable (expired in 1998) Not applicableNot

applicableFGD: 98% instantaneous removal efficiency to

meet a 95% 30-day rolling average removal efficiency (SEE NOTES) Not applicableNot

applicableNot

applicableNot

applicableNot

applicableNot

applicableLow NOx Burners: 0.45 lb/MMBtu (expired in

1992)

3 ESP rebuild: 99.0 % collection efficiency filterable (expired in 1993) Not applicableNot

applicableFGD: 98% instantaneous removal efficiency to

meet a 95% 30-day rolling average removal efficiency (SEE NOTES) Not applicableNot

applicableNot

applicableNot

applicableNot

applicableNot

applicableLow NOx Burners: 0.45 lb/MMBtu (expired in

1993)

4 ESP rebuild: 99.0 % collection efficiency filterable (expired in 1998) Not applicableNot

applicableFGD: 98% instantaneous removal efficiency to

meet a 95% 30-day rolling average removal efficiency (SEE NOTES) Not applicableNot

applicableNot

applicableNot

applicableNot

applicableNot

applicableLow NOx Burners: 0.45 lb/MMBtu (expired in

1993)



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

_X___ No Please elaborate.

32

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
33

### If the boiler has separate guaranteed emission rate for filterable and condensable PM, respectively, please indicate those separate emission rates.
34

### Metal HAP include compounds of antimony, arsenic, beryllium, cadmium, cobalt, lead, manganese, nickel, phosphorus, and selenium; indicate permit level for all metal HAP for which a permit level has been developed.

### Most recent guaranteed emission rate for each pollutant for which there is a permitted emission limit
Boiler ID32



### Page 14 of 121 part I, 22-23

### GEORGIA POWER - PLANT BOWEN

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 applicableNot

applicableCoal 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. Effective Jan 1, 2012, 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 applicableNot

applicableNot

applicableNot

applicableNot

applicableNot

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 applicableNot

applicableCoal 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 applicableNot

applicableNot

applicableNot

applicableNot

applicableNot

applicable

3 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 applicableNot

applicableCoal 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 applicableNot

applicableNot

applicableNot

applicableNot

applicableNot

applicable 

### Required monitoring, recordkeeping, and reporting requirements for each pollutant for which there is a permitted emission limit
Boiler ID35



### Page 15 of 121 part I, 24

### GEORGIA POWER - PLANT BOWEN

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) Required monitoring, recordkeeping, and reporting requirements for each pollutant for which there is a permitted emission limit
Boiler ID35



### 4 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 applicableNot

applicableCoal 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 applicableNot

applicableNot

applicableNot

applicableNot

applicableNot

applicable

35

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
36

### If the boiler's monitoring, recordkeeping, and reporting requirements require your company to monitoring, keep records, and report filterable and condensable PM separately, please describe the separate actions required.
37

### Metal HAP include compounds of antimony, arsenic, beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, phosphorus, and selenium; indicate permit level for all metal HAP for which a permit level has been developed.



### Page 16 of 121 part I, 24

### GEORGIA POWER - PLANT BOWEN

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 17 of 121 part I, 25-26

### GEORGIA POWER - PLANT BOWEN

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:

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

703

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



### Page 18 of 121 part II, 1

### GEORGIA POWER - PLANT BOWEN

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

9,768 1, 2, 3, 4 KY KNOTT 5A, 7, 8, 9, ELKHORN 2, ELKHORN 3, HAZARD #7 TRAIN 1.15 12.93 12,975

9,718 1, 2, 3, 4 KY KNOTT 5A, 7, 8, 9, ELKHORN 2, ELKHORN 3, HAZARD #7 TRAIN 0.99 12.61 12,976

11,032 1, 2, 3, 4 KY KNOTT 5A, 7, 8, 9, ELKHORN 2, ELKHORN 3, HAZARD #7 TRAIN 1.38 13.57 12,796

9,497 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.32 11.87 12,916

9,893 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.7 11.78 13,125

10,219 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.2 12.24 13,096

10,101 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.2 9.67 13,524

10,118 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.07 7.95 13,706

9,913 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.08 10.62 13,330 9,643 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.48 12.37 13,125 10,357 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.5 11.49 13,301 12,250 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.49 8.48 13,755 12,186 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.43 8.49 13,749 11,947 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.48 9.36 13,649 12,289 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.6 8.27 13,793 12,030 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.44 9.74 13,631

10,314 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.72 10.75 13,460 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

Page 19 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,486 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.78 11.36 13,330

10,463 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.87 11.69 13,252

9,811 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.71 13.07 13,064

10,329 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.75 10.79 13,467

10,389 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1 10.75 13,486

10,190 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.72 12.04 13,228

10,389 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.17 10.32 13,520

10,288 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.06 9.52 13,627

10,491 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.78 10.9 13,434

10,532 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.82 10.73 13,466

10,529 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.78 11.37 13,357

10,648 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.07 10.23 13,525

10,546 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.88 8.95 13,222

10,597 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.97 10.06 13,532



### Page 20 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

12,001 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.07 10.23 13,520

11,924 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.98 9.71 13,537

12,110 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.06 8.21 13,857

12,012 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.03 10.68 13,439

12,099 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.01 9.9 13,576

12,009 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.99 9.83 13,539

12,062 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.07 10.51 13,455

12,174 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.96 8.81 13,743

11,993 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.05 10.48 13,471

12,163 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.02 9.62 13,622

11,997 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.9 9.25 13,679

12,073 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.86 10.04 13,482

11,982 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.9 9.27 13,704

10,139 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.85 9.05 13,645



### Page 21 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

12,137 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.23 9.01 13,685

11,914 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.79 9.86 13,591

12,032 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.84 9.9 13,577

11,996 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.79 10.09 13,567

11,940 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 0.78 10.29 13,473

12,010 1, 2, 3, 4 KY PERRY, LETCHER AMBURGY, HAZARD #4, AMBURGY, HAZARD TRAIN 1.02 9.54 13,643

11,943 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.33 7.86 13,891

10,619 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.46 8.17 13,867

10,382 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.44 8.36 13,762

12,000 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.45 9.79 13,562

11,955 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.63 9.24 13,614

8,673 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.01 7.48 14,318

10,100 1, 2, 3, 4 KY LETCHER LOW SPLINT, HIGH SPLINT, WINIFREDE, HARLAN TRAIN 0.98 9.81 13,701



### Page 22 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,112 1, 2, 3, 4 KY LETCHER LOW SPLINT, HIGH SPLINT, WINIFREDE, HARLAN TRAIN 0.98 10.76 13,536

10,342 1, 2, 3, 4 KY LETCHER LOW SPLINT, HIGH SPLINT, WINIFREDE, HARLAN TRAIN 1.13 11.11 13,450

10,127 1, 2, 3, 4 KY LETCHER LOW SPLINT, HIGH SPLINT, WINIFREDE, HARLAN TRAIN 1.08 10.33 13,580

10,376 1, 2, 3, 4 KY LETCHER LOW SPLINT, HIGH SPLINT, WINIFREDE, HARLAN TRAIN 1.12 10.23 13,632

11,761 1, 2, 3, 4 KY LETCHER LOW SPLINT, HIGH SPLINT, WINIFREDE, HARLAN TRAIN 0.89 12.03 13,342

11,756 1, 2, 3, 4 KY LETCHER LOW SPLINT, HIGH SPLINT, WINIFREDE, HARLAN TRAIN 0.92 10.48 13,485

11,838 1, 2, 3, 4 KY LETCHER LOW SPLINT, HIGH SPLINT, WINIFREDE, HARLAN TRAIN 0.89 9.34 13,742

10,089 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 0.93 11.74 13,299

10,210 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 0.72 10.91 13,355

10,618 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 0.64 10.68 13,462



### Page 23 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

9,995 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 0.73 10.84 13,425

9,789 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 0.72 10.91 13,355

10,362 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 0.81 11.65 13,273

9,965 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.31 13.44 13,009

10,423 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.47 11.72 13,320

10,466 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.1 10.92 13,478

10,492 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.2 12.99 13,143

10,555 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 0.93 11.23 13,296

10,505 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.15 11.71 13,399

10,061 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 0.79 11.93 13,358

10,448 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.5 11.73 13,367

10,599 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.32 11.46 13,437

9,759 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.36 10.9 13,460

10,220 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.32 13.01 13,132



### Page 24 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,181 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.56 10.23 13,606

10,717 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.56 10.89 13,447

10,390 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.41 11.59 13,275

10,172 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.43 10.8 13,410

10,175 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.3 10.65 13,432

10,076 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.35 11.19 13,335

10,095 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.65 10.53 13,478

10,075 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.31 10.54 13,511

10,543 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.28 10.36 13,576

10,374 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.36 10 13,620

11,814 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.31 10.3 13,608

10,444 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.67 11 13,398

10,286 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.21 11.81 13,312

10,369 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.2 13.42 13,073



### Page 25 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,846 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.55 13.03 13,138

9,888 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.44 12.91 13,169

10,467 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.44 12.67 13,198

10,472 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.31 11.58 13,238

10,356 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.45 10.94 13,422

10,436 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.52 13.13 13,118

10,381 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.54 12.87 13,139

11,778 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.2 12.41 13,147

10,528 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.44 11.37 13,440

10,339 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.48 11.58 13,386

10,395 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.46 13.45 13,016

10,354 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.34 11.16 13,412

10,436 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.26 10.98 13,371

10,431 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.39 10.86 13,473



### Page 26 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,472 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.45 11.97 13,363

10,456 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.37 11.52 13,472

10,407 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.49 11.4 13,479

10,039 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3TRAIN 1.24 11.13 13,475

10,053 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.7 13.19 12,890

10,068 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.92 13.26 12,854

9,828 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.77 11.57 13,192

10,097 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.42 12.77 12,985

9,868 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.19 11.68 13,081

10,374 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.36 10.89 13,262



### Page 27 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,842 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.64 12.47 12,954

11,722 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.86 12.55 12,974

10,471 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.35 12.12 13,076

10,200 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.21 12.12 13,035

11,337 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.3 11.24 13,231

11,868 1, 2, 3, 4 KY KNOTT, LETCHER ELKHORN #1, ELKHORN #3, HAZARD 4, FLOYD, HAZARD 5A TRAIN 1.67 11.74 13,114 9,789 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.83 11.85 12,783 10,094 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.79 14.13 12,572 10,199 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.84 12.79 12,835 10,071 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.78 12.82 12,787 10,037 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.93 11.89 12,969 9,925 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.93 13.79 12,703 10,191 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1 13.27 12,775 9,989 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.93 13.53 12,739



### Page 28 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 9,974 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.11 12.1 12,875 9,772 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 12.85 12,761 10,112 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 14.23 12,633 9,953 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.13 13.38 12,656 9,935 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.16 12.95 12,661 10,179 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.84 12.85 12,786 9,910 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 14.43 12,560 10,017 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.85 13.7 12,718 10,179 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.94 12.68 12,753 10,281 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.86 11.63 13,029 10,558 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.9 14.36 12,616 10,005 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.82 14.32 12,641 10,289 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.8 13.8 12,714 10,106 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.12 12.88 12,891 10,065 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.94 13.2 12,755 10,091 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.87 13.4 12,810 9,958 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.89 11.56 13,046 10,044 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.08 12.8 12,871 10,051 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.97 11.72 13,016 10,135 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.98 12.15 13,040 10,284 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.01 13.09 12,836 10,239 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.8 12.19 13,005 10,070 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.91 13.61 12,679 9,926 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.77 12.33 12,839



### Page 29 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 9,935 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.13 14.45 12,557 10,112 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.01 14.07 12,629 10,311 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.13 13.9 12,631 10,065 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.09 12.64 12,908 10,061 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.16 12.93 12,755 9,892 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.91 12.22 12,930 10,011 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.13 12.45 12,879 9,920 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.82 12.04 12,945 10,210 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.85 11.52 13,000 10,240 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.9 12.24 12,953 10,029 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.87 11.07 13,137 10,352 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.9 13.84 12,646 10,279 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 14.19 12,597 10,251 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.92 14.62 12,556 10,035 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.85 12.85 12,778 10,498 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.79 12.58 12,877 10,009 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.9 12.02 12,951 10,131 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.92 13.3 12,748 10,105 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.91 12.21 12,938 10,335 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.86 12.89 12,800 9,969 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.9 13.14 12,777 9,813 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.87 11.37 13,055 10,234 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.97 12.21 12,910 11,475 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.98 12.18 12,968



### Page 30 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 10,289 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.96 14.18 12,625 10,038 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.03 14.7 12,480 9,992 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.18 15.23 12,371 11,574 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1 12.98 12,824 11,416 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.98 13.33 12,722 11,681 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.94 12.82 12,814 9,940 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1 11.86 13,007 10,039 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.94 12.7 12,879 11,488 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.93 14.41 12,575 11,489 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.04 14.37 12,579 11,362 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.94 14.17 12,570 11,636 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.92 12.61 12,865 11,813 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.84 12.72 12,856 11,299 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.96 13.3 12,665 11,814 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1 13.95 12,594 11,887 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.06 13.76 12,653 12,010 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.99 15.09 12,470 11,553 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.97 14.64 12,525 11,781 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.96 14.77 12,545 11,720 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.98 14.3 12,611 10,409 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.85 13.18 12,779 11,524 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.27 13.94 12,603 11,583 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.2 12.58 12,841 11,576 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.94 12 12,981



### Page 31 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 12,119 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 10.48 13,247 11,677 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.89 13.48 12,738 11,733 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.06 14.94 12,465 11,521 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.84 12.21 12,933 11,561 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.92 14.23 12,644 11,474 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.9 13.02 12,762 11,857 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.76 14.82 12,532 11,639 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.84 12.92 12,799 11,558 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.14 14.15 12,644 11,618 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.97 12.97 12,789 11,826 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.05 15.75 12,297 11,839 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.92 12.84 12,818 11,779 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.96 13.96 12,630 11,839 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.99 14.76 12,499 11,634 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.81 13.44 12,696 11,824 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.91 15.13 12,423 11,792 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.07 14.14 12,582 11,935 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.02 13.9 12,654 11,868 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.76 13.34 12,740 11,799 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.15 14.52 12,524 11,903 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.95 11.81 13,052 11,919 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.03 13.65 12,708 11,751 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.03 12.45 12,870 11,597 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.97 11.23 13,061



### Page 32 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 11,743 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.97 12.93 12,755 11,797 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.07 13.29 12,733 11,705 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.97 12.87 12,820 11,571 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.04 14.01 12,647 11,331 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1 12.23 12,887 11,651 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.02 12.91 12,609 11,716 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.89 12.01 12,916 11,564 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.9 13.88 12,628 11,600 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.93 13.27 12,722 11,898 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.83 13.2 12,767 11,813 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 14.12 12,565 11,497 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.78 13.21 12,788 11,638 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.77 10.08 13,248 11,474 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.81 13.02 12,674 11,221 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.89 14.27 12,455 11,516 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 13.62 12,683 11,994 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 13.62 12,665 11,466 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.89 12.84 12,810 11,414 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 11.93 12,958 11,443 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.93 11.59 13,022 11,102 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.86 10.99 13,103 11,678 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.93 14.56 12,671 11,411 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.84 13.11 12,835 11,219 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.09 13.47 12,720



### Page 33 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 11,705 1, 2, 3, 4 KY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.02 13.9 12,667 10,343 1, 2, 3, 4 KY KNOTT, PERRY VARIOUS HAZARD TRAIN 1.12 12.82 12,952 10,176 1, 2, 3, 4 KY KNOTT, PERRY VARIOUS HAZARD TRAIN 1.02 12.45 13,061 10,670 1, 2, 3, 4 KY KNOTT, PERRY VARIOUS HAZARD TRAIN 1.26 13.58 12,872 10,351 1, 2, 3, 4 KY KNOTT, PERRY VARIOUS HAZARD TRAIN 1.34 12.02 13,024 10,498 1, 2, 3, 4 KY KNOTT, PERRY VARIOUS HAZARD TRAIN 1.33 12.68 12,909 12,055 1, 2, 3, 4 KY KNOTT, PERRY VARIOUS HAZARD TRAIN 1.26 11.93 13,032 11,809 1, 2, 3, 4 KY KNOTT, PERRY VARIOUS HAZARD TRAIN 1.23 11.83 13,070 10,132 1, 2, 3, 4 KY KNOTT, PERRY VARIOUS HAZARD TRAIN 1.19 11.96 12,996 10,533 1, 2, 3, 4 KY KNOTT, PERRY VARIOUS HAZARD TRAIN 1.33 11.32 13,146

10,241 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.23 13.02 12,840

9,950 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.08 11.29 13,107



### Page 34 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,433 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.95 12.62 12,990

10,608 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.25 13.14 12,864

10,790 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.96 11.69 13,102

10,600 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.86 12.09 13,114



### Page 35 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,616 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.88 12.12 13,057

12,050 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.84 12.53 12,968

12,012 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1 12.32 13,005

12,216 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.02 10.64 13,308



### Page 36 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,495 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.06 11.36 13,155

10,623 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.04 10.63 13,324

12,027 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.95 10.13 13,386

10,599 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.21 12 12,995



### Page 37 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

12,092 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.08 10.93 13,175

12,070 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.97 12.7 12,871

12,048 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.12 10.34 13,302

12,076 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.04 10.62 13,245



### Page 38 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,812 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.09 12.52 13,013

11,937 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.51 10.87 13,175

11,921 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.99 10.45 13,236

11,992 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.92 8.29 13,629



### Page 39 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,840 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.92 10.31 13,343

9,980 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.67 8.72 13,512

10,049 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.92 12.81 12,884

9,911 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.16 12.3 12,907



### Page 40 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,304 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.98 11.92 12,874

12,073 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.9 12.76 12,981

11,951 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.33 11.59 13,111

11,553 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.47 12.37 12,931



### Page 41 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

12,139 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.5 12.13 12,979

12,080 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.42 10.51 13,297

12,224 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.19 11.21 13,261

12,187 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 0.96 9.54 13,518



### Page 42 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,491 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.59 12.02 12,938

11,697 1, 2, 3, 4 KY HARLAN, LESLIE HADDIX, HAZARD, HAZARD 10, HAZARD 4, HAZARD 5A, HAZARD 7, HAZARD 8, HAZARD 9, SPLINT, VARIOUS HAZARD, ELKHORN TRAIN 1.6 11.98 13,071 10,352 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.89 8.81 13,749 10,457 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.91 6.95 13,659 10,326 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.88 7.38 13,943 10,385 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.97 9.03 13,627 10,278 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.88 9.09 13,605 10,384 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.82 8.3 13,810 10,203 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.88 7.21 13,904 10,492 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.88 8.71 13,728 10,469 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.89 8.82 13,616 10,437 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.08 7.33 13,940 11,891 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.02 7.42 13,945 11,867 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.96 8.3 13,764 11,954 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.02 8.74 13,633



### Page 43 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 11,806 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.09 8.5 13,655 10,796 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.09 8.09 13,777 11,922 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.08 7.71 13,885 10,420 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.14 8.4 13,711 11,858 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.01 8.01 13,768 11,785 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.12 8.61 13,676 11,933 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.14 9.76 13,499 11,904 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.93 8.16 13,742 11,892 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.99 10.2 13,462 11,791 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.98 8.44 13,735 11,884 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.88 9.21 13,518 11,823 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.98 7.9 13,814 11,955 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.02 8.76 13,654 11,949 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.86 7.8 13,826 11,915 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.99 7.42 13,925 11,854 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.96 8.12 13,779 11,839 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.06 8.17 13,769 10,433 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.82 8.85 13,680 11,895 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.91 8.39 13,759 10,436 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.9 8.32 13,741 10,372 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1 7.97 13,821 10,374 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.98 7.45 13,941 10,322 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.02 8.66 13,707 11,758 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 0.96 8.8 13,668



### Page 44 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 11,278 1, 2, 3, 4 KY PERRY HAZARD 4 TRAIN 1.23 8.63 13,615

9,857 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.97 10.89 13,516

10,212 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.02 10.86 13,416

10,289 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.97 10.42 13,595

10,575 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.97 10.58 13,555

10,516 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.96 9.87 13,721

10,324 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.98 9.41 13,702

10,188 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.97 9.44 13,709

10,452 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.96 10.81 13,514



### Page 45 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,348 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.92 9.37 13,732

10,631 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.97 8.86 13,822

9,902 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.96 9.08 13,785

10,271 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.04 9.6 13,715

10,052 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.03 8.89 13,812

11,788 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.1 9.19 13,745

11,777 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.1 9.18 13,868

11,880 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.03 9.19 13,732

11,835 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.11 9.45 13,732



### Page 46 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,798 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.12 9.56 13,760

11,710 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.14 9.61 13,724

10,201 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.05 10.23 13,584

10,416 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.06 9.96 13,692

11,845 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.02 9.19 13,761

11,704 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.03 9.52 13,708

11,583 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.2 9.5 13,744

11,530 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.99 9.2 13,793

11,936 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.97 10.11 13,636



### Page 47 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,832 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.17 9.81 13,512

11,523 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.01 9.8 13,653

11,763 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.05 10.29 13,548

11,846 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.01 10.39 13,541

11,755 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.05 9.81 13,678

11,892 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.07 10.07 13,583

11,769 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.04 9.54 13,654

11,927 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.99 10.33 13,520

11,713 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.98 10.05 13,574



### Page 48 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,820 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.92 10.11 13,583

10,359 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.95 10.03 13,597

11,731 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.95 9.93 13,584

9,886 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.88 10.23 13,602

11,652 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.88 9.76 13,681

11,536 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.82 10.07 13,632

11,903 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.97 10.35 13,640

11,720 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.92 10 13,653

11,623 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.86 9.83 13,756



### Page 49 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,857 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.88 9.91 13,708

11,911 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.83 10.24 13,625

11,585 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.91 9.37 13,724

11,837 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.88 9.44 13,752

11,808 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.91 9.63 13,739

11,710 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.9 9.89 13,694

11,754 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.91 9.35 13,719

11,395 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.14 10.05 13,695

11,601 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.85 9.72 13,653



### Page 50 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,844 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN N/A N/A N/A

10,030 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.97 11.41 13,428

10,414 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.03 12.5 13,230

10,201 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.98 10.7 13,551

10,191 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.95 10.32 13,633

10,333 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.95 10.3 13,632

10,327 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.99 10.05 13,572

10,331 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.94 10.46 13,563

11,913 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.03 10.78 13,541



### Page 51 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,824 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.05 10.55 13,575

11,418 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.06 10.96 13,480

10,366 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.06 11.19 13,484

11,894 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.17 10.41 13,598

11,723 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.99 10.98 13,497

11,621 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.13 10.81 13,536

10,216 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.07 10.68 13,529

10,424 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.15 11.04 13,478

11,731 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.15 11.03 13,456



### Page 52 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,364 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.99 11.37 13,417

11,699 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.11 10.83 13,540

11,430 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.15 10.3 13,611

11,875 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.09 10.87 13,488

12,044 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.1 11.53 13,370

11,606 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.03 10.26 13,574

10,652 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.03 10.44 13,528

11,761 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.99 10.57 13,492

11,774 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.04 10.13 13,585



### Page 53 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,768 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.01 11.58 13,286

11,798 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.97 11.19 13,350

11,727 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.04 11.04 13,365

11,731 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.06 11.04 13,507

11,826 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.87 10.05 13,508

11,758 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.93 10.74 13,528

11,816 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.9 11.33 13,443

11,605 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.9 10.79 13,478

11,785 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.84 10.97 13,515



### Page 54 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,814 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1 11.71 13,369

11,423 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.89 10.3 13,602

11,899 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.92 10.34 13,630

10,340 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.88 10.36 13,646

11,339 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.98 10.94 13,414

11,852 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.95 9.83 13,674

11,226 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.93 9.71 13,710

11,619 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.93 9.76 13,712

11,563 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.94 9.76 13,714



### Page 55 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,845 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.9 9.42 13,767

11,980 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.99 10.16 13,598

11,691 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.03 9.63 13,713

11,899 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 1.1 9.89 13,702

11,656 1, 2, 3, 4 KY HARLAN HARLAN, HIGH SPLINT, IMBODE, LOW SPLINT, WINIFREDE TRAIN 0.86 9.42 13,663 10,578 1, 2, 3, 4 KY HARLAN LOW SPLINT TRAIN 0.91 12.91 12,857

10,325 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.46 11.69 13,227

9,997 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.26 11.53 12,953

10,305 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.3 11.54 13,119

10,039 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.35 11.13 13,243

10,121 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.33 13.44 12,840

10,537 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.53 7.9 13,803



### Page 56 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 10,359 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.78 12.16 13,260 10,274 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.62 13.73 12,961 10,634 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.6 11.7 13,280 10,481 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.64 12.48 13,157 10,343 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.53 12.68 13,185 10,569 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.83 12.66 13,189 10,674 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.72 11.83 13,308 10,690 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.3 9.31 13,649 9,258 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.36 9.17 13,594 10,058 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.31 8.86 13,659 12,161 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.37 9.51 13,613 12,363 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.43 8.37 13,759 12,048 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.47 10.71 13,404 12,119 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.55 8.87 13,715 10,295 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.89 12.56 13,340 10,511 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.82 12.56 13,352 10,465 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.89 10.47 13,508 10,390 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.94 12.21 13,206 10,419 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.99 10.06 13,585 10,458 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.06 10.3 13,456 10,485 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.11 11.05 13,300 10,520 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.77 11.57 13,314 10,551 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.74 10.72 13,444 10,298 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.83 11.97 13,207



### Page 57 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 10,203 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.06 11.39 13,305 10,319 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.79 11.61 13,313 10,430 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.05 10.99 13,405 10,717 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.1 11.18 13,381 10,648 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.84 11.02 13,406 10,414 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.79 12.07 13,210 10,531 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.76 10.81 13,446 10,499 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.96 10.25 13,452 10,454 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.04 9.97 13,518 10,431 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.83 10.14 13,546 11,811 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.82 10.31 13,489 10,439 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.91 10.62 13,393 11,946 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.07 8.64 13,753 11,784 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.82 10.4 13,495 10,472 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.88 10.19 13,490 11,851 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.94 10.38 13,435 12,148 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.83 10.72 13,451 11,923 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.98 10.31 13,461 12,095 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.81 10.71 13,442 12,184 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.86 10.2 13,508 12,043 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.86 11.17 13,325 10,548 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.87 8.65 13,717 11,921 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.79 9.99 13,582 10,471 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.91 11.32 13,341



### Page 58 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 12,078 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.02 9.12 13,737 11,992 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.05 8.71 13,767 12,062 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.95 9.66 13,567 12,005 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.03 10.4 13,496 12,150 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.03 9.49 13,618 11,950 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.03 9.71 13,580 12,135 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.98 9.24 13,687 11,901 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.84 9.9 13,563 12,109 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.86 9.42 13,589 12,173 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.05 9.37 13,638 12,117 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.26 9.49 13,614 11,987 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.88 11.14 13,320 10,705 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.19 9.22 13,649 12,129 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.08 9.06 13,676 11,915 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.08 8.96 13,645 12,055 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.05 8.51 13,729 11,991 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1 9.68 13,615 10,647 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.84 10.11 13,557 12,062 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.83 11.21 13,352 12,071 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.91 10.29 13,480 12,138 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.15 8.93 13,740 11,976 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.87 10.4 13,468 12,201 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.85 10.26 13,500 12,223 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.84 11.41 13,357



### Page 59 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 12,093 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.83 9.66 13,553 12,125 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.83 9.51 13,539 12,104 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.16 9.2 13,671 12,230 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.91 8.46 13,776 11,867 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.74 9.55 13,601 11,892 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 0.77 10.29 13,510 10,556 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.57 7.87 13,877 11,856 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.48 7.81 13,901 9,992 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.45 8.27 13,770 10,158 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.38 8.42 13,759 11,917 1, 2, 3, 4 KY LESLIE, BELL 4, 5A, 7, 8, COAL CREEK TRAIN 1.55 9.12 13,681 10,309 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.05 12.97 12,709 10,532 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.33 13.23 12,853 10,525 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.39 12.52 12,952 10,363 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.33 11.98 13,062 10,501 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.4 11.59 13,054 10,698 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.49 12.01 13,001 10,414 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.53 12.86 12,912 10,622 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.37 12.76 12,868 10,264 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.56 13.5 12,808 10,561 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.4 12.33 12,990 10,421 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.45 13.5 12,769 10,345 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.52 14.03 12,642 10,330 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.47 12.39 12,926



### Page 60 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 10,241 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.46 12.79 12,877 10,769 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.42 12.55 12,915 10,400 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.45 12.62 12,935 10,223 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.57 12.87 12,828 10,202 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.32 13.18 12,766 10,578 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.51 13.67 12,702 10,760 1, 2, 3, 4 KY PERRY MULTIPLE TRAIN 1.62 12.4 12,977 10,706 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.74 14.27 12,901 10,601 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.71 13.82 12,989 10,884 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.87 14.14 12,931 10,511 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.98 13.77 12,930 10,687 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.98 9.36 13,752 10,721 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.68 13.97 12,895 10,798 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.94 13.2 13,143 10,568 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.69 13.89 12,922 10,405 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.62 14.56 12,868 10,745 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.6 14.16 12,974 10,528 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.61 14.56 12,944 10,649 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.95 13.55 12,964 10,738 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.93 13.72 12,943 10,693 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.93 12.79 13,174 10,732 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.97 12.5 13,219 12,357 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.61 13.7 12,983 12,202 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.64 13.7 12,991



### Page 61 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 10,476 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.61 12.8 13,062 12,051 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.6 13.16 13,016 12,015 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.63 13.79 12,945 11,983 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.61 12.98 13,014 12,153 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.56 13.91 12,924 12,072 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.58 14.19 12,863 11,956 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.65 14.7 12,777 11,980 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.63 12.21 13,025 11,981 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.65 13.42 13,038 12,092 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.82 12.47 12,918 12,053 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.82 13.06 12,857 12,024 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.66 14.08 12,890 12,230 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.8 13.26 12,715 11,912 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.82 13.31 12,688 11,972 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.62 12.48 12,997 11,940 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.59 12.93 13,022 11,972 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.6 13.01 12,924 11,964 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.62 13.43 12,953 12,048 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.66 13.07 12,968 12,186 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.64 12.73 13,064 12,154 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.68 13.65 12,917 12,029 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.65 13.27 12,936 11,895 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.76 12.37 12,953 11,869 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.74 11.21 13,179



### Page 62 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 12,130 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.76 12.49 12,907 11,994 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.81 12.05 13,032 11,848 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.87 12.64 12,881 11,939 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.81 12.68 12,934 11,989 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.83 12.43 12,953 12,061 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.81 12.12 12,975 12,001 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.82 12.92 12,873 12,003 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.82 12.25 12,970 12,080 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.77 12.14 13,004 11,805 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.81 13.58 12,751 11,653 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.88 11.57 13,015 10,497 1, 2, 3, 4 WV LOGAN COALBURG TRAIN 0.82 12.71 12,859 11,962 1, 2, 3, 4 WV LOGAN COALBURG TRAIN N/A N/A N/A 9,651 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1 9.4 13,631 9,676 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.03 9.32 13,631 10,122 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.03 9.26 13,645 9,853 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 0.94 7.9 13,756 9,765 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 0.9 8.52 13,749 9,785 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 0.89 11.93 13,170 11,466 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.05 10.79 13,274 11,424 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 0.9 9.76 13,478 11,421 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.13 10.68 13,393 11,585 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.13 8.98 13,620 10,272 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.16 8.97 13,657



### Page 63 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 11,347 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.03 7.93 13,840 11,608 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.16 8.2 13,822 11,686 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.11 9.55 13,407 10,577 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.05 9.18 13,521 10,370 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 0.97 10.13 13,468 10,433 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 1.04 10.37 13,424 10,389 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 0.92 9.38 13,538 10,361 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 0.98 9.87 13,481 11,765 1, 2, 3, 4 KY HARLAN HARLAN, KELLIOKIA TRAIN 0.98 9.87 13,481 10,128 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.04 11.24 12,990 9,961 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.13 12.32 12,892 10,127 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.06 13.1 12,730 10,175 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 0.99 12.16 12,914 10,298 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 0.97 10.25 13,265 10,075 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 0.95 10.98 13,067 10,192 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.03 9.99 13,217 10,515 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.1 10 13,287 11,815 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.3 9.73 13,298 11,639 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.31 10.45 13,232 10,588 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.47 9.63 13,342 9,502 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.48 10.53 13,204 10,322 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.29 10.13 13,259 10,474 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.45 10.99 13,084 11,646 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.14 11.52 12,983



### Page 64 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 11,768 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.31 10.13 13,234 11,705 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.17 11.96 12,872 11,715 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.1 12.64 12,808 11,811 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.61 11.41 13,016 10,043 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.12 11.55 13,017 11,598 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.18 13.47 12,716 10,229 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.29 10.39 13,252 11,924 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.23 12.54 12,810 10,314 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.44 11.14 13,117 11,720 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.3 12.46 12,895 11,766 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.22 10.47 13,211 10,288 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.15 9.9 13,292 11,578 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.34 10.47 13,205 11,454 1, 2, 3, 4 KY MARTIN MULTIPLE TRAIN 1.29 10.82 13,199 9,934 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.27 9.62 13,512 9,985 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.09 7.68 13,834 9,744 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.27 12.05 13,087 9,891 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.16 11.54 13,092 10,266 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.11 12.07 13,094 10,190 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.28 11.83 13,109 10,505 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.16 9.35 13,535 10,388 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.16 11.26 13,214 10,380 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.08 10.59 13,251 10,197 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.08 10.54 13,260



### Page 65 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 10,401 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.12 10.51 13,334 10,330 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.28 10.44 13,291 10,387 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1 10.31 13,326 10,336 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.12 10.31 13,322 10,572 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.11 8.87 13,579 10,425 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.14 8.8 13,575 10,383 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.06 9.33 13,508 10,398 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.06 11.21 13,142 10,481 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.08 10.13 13,317 10,616 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.03 10.54 13,272 10,340 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.13 10.5 13,322 10,916 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.23 8 13,702 10,427 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.21 8.69 13,595 10,379 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.18 8.91 13,549 9,823 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.16 8.01 13,744 10,606 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.14 9.57 13,474 10,698 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.3 11.03 13,262 10,068 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.42 10.73 13,319 10,236 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.33 8.91 13,553 10,701 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.33 10.71 13,273 10,267 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.3 8.1 13,725 10,320 1, 2, 3, 4 KY BELL, PIKE RIM TRAIN 1.28 8.53 13,618

10,336 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.28 12.31 13,125



### Page 66 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,557 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.29 12.56 13,092

10,026 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 0.99 12.03 13,077

10,456 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 0.85 11.72 13,196

10,270 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.1 13.39 12,880

10,400 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.01 13.53 12,855

10,764 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.11 13.65 12,823

10,670 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.38 13.42 12,972

10,615 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.04 12.95 13,001

10,462 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1 12.87 12,990

10,678 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.05 12.64 13,028

10,588 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.04 12.08 13,031

10,547 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.14 14.16 12,791

10,604 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 0.9 14.42 12,790

10,442 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.08 13 13,007



### Page 67 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,766 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.05 13.19 13,014

10,575 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1 12.55 13,074

10,645 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.03 11.2 13,274

12,155 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.1 11.28 13,286

11,598 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.11 13.01 13,007

11,812 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.1 11.75 13,195

10,809 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.12 12.21 13,184

12,024 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.05 11.68 13,178

11,923 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.12 11.61 13,179

11,862 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.15 12.61 13,046

11,880 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.13 11.82 13,179

12,188 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.26 11.08 13,341

12,012 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.3 11.35 13,217

12,087 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.23 12.05 13,137



### Page 68 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,929 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.13 12.21 13,126

11,919 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.03 10.09 13,453

12,086 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.13 12.63 12,968

12,060 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.14 10.69 13,253

11,764 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.14 11.52 13,184

11,900 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.31 11.43 13,135

11,999 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.29 13.91 12,842

12,099 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.29 12.54 12,996

12,081 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.45 11.42 13,222

12,086 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.2 12.3 13,172

12,165 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.2 11.44 13,265

12,307 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.16 11.59 13,242

12,204 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.28 10.22 13,470

12,105 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.26 12.3 13,109



### Page 69 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,987 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.2 13.21 13,030

12,148 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.18 11.16 13,380

11,875 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.07 10.9 13,227

11,985 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.24 10.27 13,287

12,183 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.3 10.81 13,300

12,131 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.12 11.33 13,295

12,237 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.15 10.79 13,359

11,899 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.07 8.8 13,720

11,908 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.06 9.34 13,635

11,856 1, 2, 3, 4 WV BOONE CEDAR GROVE, NO 2 GAS, POWELLTON TRAIN 1.23 11.91 13,136

9,844 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.16 11.07 13,292

10,182 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.21 12.59 12,919

10,123 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.23 12.12 13,016

9,624 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.13 10.65 13,388



### Page 70 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

9,060 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.18 12.19 13,048

10,122 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.11 12.06 13,088

9,029 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.14 12.19 13,098

10,324 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.12 11.04 13,332

10,042 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.17 12.13 13,040

9,961 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.17 13.63 12,812

10,423 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.13 11.43 13,260

10,142 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.18 11.38 13,184

10,696 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.26 11.85 13,122

10,399 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.19 11.52 13,168

12,116 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.16 11.44 13,259

10,792 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.31 11.82 13,137

10,396 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.12 11.18 13,213

10,547 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.16 10.67 13,328



### Page 71 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

10,706 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.34 12.99 12,930

12,144 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.24 12.38 13,021

10,746 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.29 12.17 13,079

10,705 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.4 13.68 12,857

12,215 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.44 12.84 12,974

12,106 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.27 12.19 12,944

12,115 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.25 11.34 13,176

12,107 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.12 8.18 13,712

12,191 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.21 12.1 13,030

12,119 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.35 12.4 13,079

12,155 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.35 11.67 13,224

12,270 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.31 10.41 13,365

12,080 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.16 11.7 13,161

12,336 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.27 11.58 13,221



### Page 72 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

12,203 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.25 11.28 13,277

12,188 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.28 12.73 13,101

12,304 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.24 11.3 13,354

12,222 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.16 10.73 13,410

12,346 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.26 9.88 13,471

12,226 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.43 10.34 13,400

11,761 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.34 10.83 13,286

12,233 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.35 11.12 13,299

12,245 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.28 10.83 13,325

12,175 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.44 9.86 13,437

10,807 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.36 8.96 13,631

12,250 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.49 9.79 13,468

10,684 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.39 8.97 13,582

12,225 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.21 8.08 13,732



### Page 73 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,915 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.44 9.84 13,426

12,034 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.57 8.52 13,651

11,861 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.49 10.01 13,393

12,123 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.47 8.95 13,579

12,060 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.41 9.47 13,500

11,932 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.2 8.33 13,663

12,037 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.43 11.83 13,076

11,915 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.34 10.27 13,344

10,163 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.51 10.56 13,448

11,639 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.64 10.37 13,356

11,688 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.4 10.07 13,358

11,854 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.48 9.6 13,464

11,889 1, 2, 3, 4 KY HARLAN CREECH, DARBY, LOWER HARLAN, UPPER HARLANTRAIN 1.44 9.37 13,425

12,276 1, 2, 3, 4 KY HARLAN HAZARD 4, HAZARD 8, VARIOUS HAZARD TRAIN 0.62 8.22 13,893



### Page 74 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

11,695 1, 2, 3, 4 KY HARLAN HAZARD 4, HAZARD 8, VARIOUS HAZARD TRAIN 0.62 8.65 13,866

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 75 of 121 part II, 2 (coal)

### GEORGIA POWER - PLANT BOWEN

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 30,406 1, 2 Georgia/USA N/A N/A Truck 30,210 1, 2 Georgia/USA N/A N/A Truck 22,614 3, 4 Georgia/USA N/A N/A Truck 15,008 1, 2 Georgia/USA N/A N/A Truck 37,630 1, 2 Georgia/USA N/A N/A Truck 15,004 1, 2 Georgia/USA N/A N/A Truck 7,498 1, 2 Georgia/USA N/A N/A Truck 7,500 1, 2 Georgia/USA N/A N/A Truck 38,582 1, 2 Georgia/USA N/A N/A Truck 14,004 3, 4 Georgia/USA N/A N/A Truck 15,002 3, 4 Georgia/USA N/A N/A Truck 7,596 3, 4 Georgia/USA N/A N/A Truck 14,994 3, 4 Georgia/USA N/A N/A Truck 29,997 3, 4 Georgia/USA N/A N/A Truck 15,006 3, 4 Georgia/USA N/A N/A Truck 22,502 3, 4 Georgia/USA N/A N/A Truck 29,993 3, 4 Georgia/USA N/A N/A Truck 22,506 1, 2 Georgia/USA N/A N/A Truck 30,301 3, 4 Georgia/USA N/A N/A Truck 7,802 3, 4 Georgia/USA N/A N/A Truck 22,511 1, 2 Georgia/USA N/A N/A Truck 7,500 3, 4 Georgia/USA N/A N/A Truck 7,504 3, 4 Georgia/USA N/A N/A Truck 7,200 1, 2 Georgia/USA N/A N/A Truck 14,849 3, 4 Georgia/USA N/A N/A Truck 7,419 3, 4 Georgia/USA N/A N/A Truck 7,425 1, 2 Georgia/USA N/A N/A Truck 22,307 1, 2 Georgia/USA N/A N/A Truck 7,447 3, 4 Georgia/USA N/A N/A Truck 7,416 1, 2 Georgia/USA N/A N/A Truck 22,506 3, 4 Georgia/USA N/A N/A Truck 

### FUEL OIL SHIPMENTS Amount received, gallons40 

### ID # of boiler(s)

firing fuel41 

### Fuel source Fuel shipment method

Page 76 of 121 part II, 2 (oil)

### GEORGIA POWER - PLANT BOWEN

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 7,447 3, 4 Georgia/USA N/A N/A Truck 7,449 3, 4 Georgia/USA N/A N/A Truck 7,458 3, 4 Georgia/USA N/A N/A Truck 37,319 3, 4 Georgia/USA N/A N/A Truck 14,924 1, 2 Georgia/USA N/A N/A Truck 14,911 3, 4 Georgia/USA N/A N/A Truck 22,370 1, 2 Georgia/USA N/A N/A Truck 22,495 3, 4 Georgia/USA N/A N/A Truck 7,503 3, 4 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 77 of 121 part II, 2 (oil)

### GEORGIA POWER - PLANT BOWEN 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 BerylliumCadmiumChromium 

### Cobalt Lead Manganese

### Selenium

09-502 11,491 0.61 10.42 13,446 0.071 1166 100 14.1 1.4 6.5 3.3 <0.02 14.9 8.0 7.1 38.9 2.4KY Pike Elkhorn 1, 2

09-200 11,077 1.09 14.99 12,649 0.121 1436 96 20.1 1.5 28.5 2.9 0.12 21.4 12.8 12.7 32.3 3.3WV Boone Cedar Grove, Winifrede

09-202 11,000 1.06 13.3 12,745 0.118 893 98 14.9 1.4 10.1 3.6 0.07 19.0 9.6 12.4 16.4 3.7KY Magoffin, FloydFireclay, Hazard 5, Amburgey, Peach Orchard

09-206 11,001 1.58 12.5 13,153 0.117 1252 87 16.0 1.8 23.0 3.4 0.14 17.4 7.6 11.5 32.9 2.0KY Harlan, Leslie Hazard 4, Hazard 4R, Hazard 8, Hazard 7

09-207 11,309 1.32 13.23 12,872 0.089 588 97 14.3 1.2 9.1 2.3 0.03 21.0 8.1 9.2 15.1 3.8KY Perry, BreathittHazard #8, Hazard #7

09-208 22,300 1.01 10.53 13,482 0.056 1301 71 12.3 1.1 6.8 2.5 0.04 14.6 6.9 8.8 31.4 2.8KY Perry, LetcherHazard 4, Hazard 4R, Hazard 8, Hazard 7

09-402 10,489 1.17 10.92 13,275 ND 289 94 17.1 <1 11.0 1.8 0.06 16.1 8.9 7.1 72.1 2.2KY Harlan Upper Harlan, Harlan, Darby, Hazard #8, Hazard #9, Hazard #4 rider

09-403 10,714 1.02 7.97 13,786 ND 205 66 12.6 <1 8.8 2.1 0.06 10.5 6.9 6.7 17.7 2.3KY Harlan Harlan, Creech, Kellioki, Darby, Splint

09-204 11,063 1.21 13.29 12,719 0.142 724 132 17.7 1.2 18.4 2.6 0.09 18.7 8.6 7.5 21.2 3.6KY Harlan, Leslie Hazard 7, 8, 9, 10

09-404 11,324 0.96 10.64 13,265 ND 95 64 12.0 1.2 7.2 2.0 0.05 16.7 7.0 8.4 21.8 2.8KY Harlan Highsplint, Winifrede, Low splint, Lower Harlan, D seam, Kellioki, Imbodden, Owl 

### Coal Seam Nickel, ppm Other trace metal HAP, ppm45 

### State/ Country County Chlorine, ppm Fluorine,

ppm Total amount of fuel represented by sample, tons 

### Sample ID # Total Sulfur, % Ash

Content, % Heating Value, Btu/lb Mercury,

ppm

Page 78 of 121 part II, 3

### GEORGIA POWER - PLANT BOWEN 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 BerylliumCadmiumChromium 

### Cobalt Lead Manganese

### Selenium Coal Seam Nickel, ppm Other trace metal HAP, ppm45 

### State/ Country County Chlorine, ppm Fluorine,

ppm Total amount of fuel represented by sample, tons 

### Sample ID # Total Sulfur, % Ash

Content, % Heating Value, Btu/lb Mercury,

ppm

09-405 11,312 0.95 10.46 13,351 ND 1701 59 24.8 1.8 11.2 4.1 0.06 31.2 13.7 14.9 24.8 6.6KY Perry Elkhorn #3, Elkhorn #2, Hazard #8, Hazard #7

09-406 11,090 0.85 11.16 13,267 ND 1278 52 12.8 <1 6.8 2.7 ND 14.7 7.4 6.2 12.5 3.2KY Perry Hazard #4, Amburgey, Hazard #8

09-407 10,438 1.82 9.83 12,383 0.072 115 79 11.3 <1 16.6 1.6 0.10 16.7 4.8 8.9 50.9 2.9KY Bell Garmeda Seam, Buckeye Springs Seam, Stray Seam

09-408 10,889 1.17 13.54 12,597 0.086 437 78 13.7 1.0 8.8 2.3 ND 20.8 9.3 8.9 8.8 4.9KY Perry, BreathittHazard 5A, Hazard #7, Hazard #8, Hazard #9

09-209 11,230 1.51 8.93 13,727 0.081 1619 62 14.9 1.2 11.6 2.7 0.08 11.9 7.8 7.1 20.7 3.4KY Pike Elkhorn #3, Millard

09-210 11,300 0.68 13.84 12,930 0.050 805 62 16.3 <1 2.8 2.7 ND 21.9 10.4 8.3 13.3 5.4WV Logan Coalburg, Stockton 09-212 10,500 1.21 11.94 13,091 0.081 1113 74 11.7 <1 8.8 2.3 ND 15.9 7.3 8.2 34.0 3.8KY Knott Elkhorn #3,

09-213 11,490 1.47 13.03 12,851 0.128 734 59 16.1 <1 14.0 3.0 0.05 17.7 10.5 8.5 15.8 3.5KY Perry Hazard #7 and Hazard #8

09-416 10,152 1.17 9.91 13,419 0.089 154 57 15.5 1.6 7.9 2.8 <0.02 15.6 8.0 9.7 19.9 2.1KY Harlan Harlan, Creech, Kellioki, Darby, Splint
09-518 11,028 1.46 11.57 13,289 ND 1162 100 11.5 1.3 22.9 2.9 0.11 12.3 6.7 6.7 35.0 2.2KY Pike Elkhorn 1, 2, 3

09-222 11,142 0.89 8.72 13,685 ND ND 59 10.3 1.0 3.8 3.1 0.02 11.6 6.1 7.8 17.5 2.3kY Perry, LetcherHazard 4, Hazard 4R, Hazard 8, Hazard 7

09-420 11,327 1.33 12.34 12,926 0.100 637 93 14.5 1.1 10.4 2.6 ND 20.6 8.9 7.6 16.6 3.6KY Perry Hazard 5A, Hazard#7, Hazard #8, Hazard #9



### Page 79 of 121 part II, 3

### GEORGIA POWER - PLANT BOWEN 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 BerylliumCadmiumChromium 

### Cobalt Lead Manganese

### Selenium Coal Seam Nickel, ppm Other trace metal HAP, ppm45 

### State/ Country County Chlorine, ppm Fluorine,

ppm Total amount of fuel represented by sample, tons 

### Sample ID # Total Sulfur, % Ash

Content, % Heating Value, Btu/lb Mercury,

ppm

09-421 12,722 1.09 8.42 13,760 ND 1956 77 13.1 1.2 5.8 1.8 ND 15.6 7.2 7.3 14.2 3.3KY Perry Elkhorn #3, Elkhorn #2, Hazard #8, Hazard #7

09-422 12,662 0.77 10.97 13,368 ND 1373 79 13.0 <1 6.2 2.4 ND 16.2 7.8 6.3 12.4 3.2KY Perry Hazard #4, Amburgey, Hazard #8

09-418 12,392 1.12 11.36 13,390 ND 111 89 13.9 1.3 9.7 2.1 <0.02 17.3 8.0 8.8 26.4 2.4KY Harlan Highsplint, Winifrede, Low splint, Lower Harlan, D seam, Kellioki, Imbodden, Owl

09-419 9,865 1.33 9.59 13,450 0.080 102 149 18.2 1.3 18.7 1.8 0.12 17.6 7.5 8.3 43.6 2.7KY Bell Garmeda Seam, Buckeye Springs Seam, Stray Seam

09-414 12,988 1.03 11.72 13,156 0.086 877 98 11.8 <1 14.2 2.0 0.03 18.3 7.0 8.3 27.9 3.7KY Bell Hance, Hazard 8, Kellioki, Darby

09-413 11,400 1.38 14.07 12,758 0.126 483 142 20.1 1.4 13.8 1.8 0.09 19.6 8.5 9.8 41.8 2.8KY Harlan Upper Harlan, Harlan, Darby, Hazard #8, Hazard #9, Hazard #4 rider

09-417 11,123 1.15 10.57 13,283 0.116 1085 134 19.7 1.3 21.3 2.5 0.11 14.9 9.6 7.3 73.8 3.5KY Bell Hazard #8, Hazard #9, Hazard #10

09-415 10,500 0.91 10.48 13,340 ND 127 88 13.2 1.2 10.2 1.9 0.68 12.6 7.6 7.4 30.4 2.3KY Harlan Harlan, Creech, Kellioki, Darby, Splint

09-409 10,800 0.89 13.05 12,741 ND 567 111 13.1 <1 5.4 2.6 ND 22.8 8.1 10.5 13.8 5.2KY Perry and Breathitt Hazard 5A,

Hazard #7, Hazard #8, Hazard #9



### Page 80 of 121 part II, 3

### GEORGIA POWER - PLANT BOWEN 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 BerylliumCadmiumChromium 

### Cobalt Lead Manganese

### Selenium Coal Seam Nickel, ppm Other trace metal HAP, ppm45 

### State/ Country County Chlorine, ppm Fluorine,

ppm Total amount of fuel represented by sample, tons 

### Sample ID # Total Sulfur, % Ash

Content, % Heating Value, Btu/lb Mercury,

ppm

09-410 11,251 1.02 12.56 12,742 0.080 948 120 14.1 1.0 9.6 2.1 0.04 15.6 7.3 8.1 17.4 3.7KY Bell Hazard 5A, Hazard 8, Hazard 9, Hazard 10

09-215 12,828 1.08 13.52 12,861 ND 1795 94 18.6 1.0 13.5 2.4 ND 19.1 10.6 9.2 42.8 2.7WV Boone Cedar Grove, Winifrede

09-218 11,336 1.44 7.97 13,885 0.077 ND 54 13.4 1.2 11.1 2.5 0.12 11.7 7.0 6.9 20.9 3.4KY Pike Elkhorn #3, Millard

09-219 12,557 1.36 10.85 13,128 0.088 935 78 13.5 1.0 7.3 3.6 ND 17.4 8.4 8.1 13.2 3.5KY Magoffin, FloydFireclay, Hazard 5, Amburgey, Peach Orchard,

09-220 12,700 0.64 13.86 12,956 ND 936 88 15.3 <1 2.8 1.9 ND 20.3 8.9 8.0 17.1 4.6WV Logan Coalburg, Stockton
09-522 11,024 1.45 10.85 13,417 0.073 977 97 12.9 ND 22.5 2.4 0.05 13.0 6.6 6.7 28.6 2.6KY Pike Elkhorn 1, 2, 3

09-223 11,000 0.96 13.15 12,980 0.106 908 74 13.2 <1 6.0 2.4 ND 17.2 8.2 8.8 14.8 4.4WV Kanawha, Boone 5-block, 6-

block,Stockton

09-224 11,255 0.89 10.78 13,329 ND 1324 71 10.3 1.0 3.8 3.1 0.02 11.6 6.1 7.8 17.5 2.3KY Perry Amburgy, Hazard 8, Hazard 7, Hazard 5A

09-225 10,998 1.47 8.13 13,831 ND 1669 56 14.2 1.3 11.2 2.2 0.06 12.3 7.7 6.2 20.8 3.4KY Pike Elkhorn #3, Millard

09-227 12,943 0.54 14.19 12,896 ND 816 95 21.8 <1 2.4 1.5 ND 26.2 10.3 8.7 15.5 5.2WV Logan Coalburg, Stockton

09-228 12,802 1.09 11.63 13,143 ND 1563 86 22.4 1.2 11.6 3.2 ND 18.1 11.8 10.3 30.2 3.2WV Boone Cedar Grove, Winifrede

09-444 11,080 0.8 12.88 12,797 0.039 743 80 16.5 1.0 5.9 2.5 <0.02 26.4 9.1 12.5 13.6 5.1KY Perry and Breathitt Hazard 5A,

Hazard #7, Hazard #8, Hazard #9, Hazard #10

09-230 12,669 1.14 13.47 12,614 ND 925 85 23.0 <1 9.2 4.9 0.06 26.4 12.1 17.4 28.8 3.7KY Magoffin, FloydFireclay, Hazard 5, Amburgey, Peach Orchard,



### Page 81 of 121 part II, 3

### GEORGIA POWER - PLANT BOWEN 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 BerylliumCadmiumChromium 

### Cobalt Lead Manganese

### Selenium Coal Seam Nickel, ppm Other trace metal HAP, ppm45 

### State/ Country County Chlorine, ppm Fluorine,

ppm Total amount of fuel represented by sample, tons 

### Sample ID # Total Sulfur, % Ash

Content, % Heating Value, Btu/lb Mercury,

ppm

09-423 11,403 1.34 11.99 13,000 0.071 609 87 16.0 <1 11.6 2.9 0.05 21.1 10.7 10.8 18.5 3.7KY Perry Hazard 5A, Hazard#7, Hazard #8, Hazard #9

09-424 11,170 1.06 10.8 13,433 ND 111 84 18.0 1.0 6.7 2.5 0.07 19.6 10.5 12.0 30.3 2.5KY Harlan Highsplint, Winifrede, Low splint, Lower Harlan, D seam, Kellioki, Imbodden, Owl

09-425 12,987 0.98 10.97 13,150 ND 679 104 16.7 <1 16.1 2.8 0.51 20.2 10.5 11.7 33.4 3.4KY Bell Hance, Hazard 8, Kellioki, Darby

09-426 10,500 1.23 9.28 13,568 ND 159 77 19.4 1.6 13.6 3.0 0.09 15.5 10.7 10.8 33.8 2.3KY Harlan Harlan, Creech, Kellioki, Darby, Splint

09-427 12,932 1.33 11.18 13,192 0.095 276 112 18.3 1.0 15.5 2.1 0.12 20.3 8.5 10.8 51.4 2.3KY Harlan Upper Harlan, Harlan, Darby, Hazard #8, Hazard #9, Hazard #4 rider

09-428 12,530 1.07 9.48 13,464 ND 142 73 18.0 1.6 7.2 3.7 0.12 15.8 9.7 10.2 21.5 2.1KY Harlan Harlan, Creech, Kellioki, Darby, Splint

09-232 11,088 1.52 13.46 12,669 0.074 840 73 53.8 2.2 9.4 6.8 0.22 31.4 26.8 19.0 35.0 3.3KY Perry Hazard #7 and Hazard #8

09-431 11,142 0.95 9.05 13,600 0.106 918 107 23.5 1.0 13.3 3.0 0.13 16.8 12.1 6.6 14.1 3.9KY Bell Hazard #8, Hazard #9, Hazard #10, Hazard #4

09-432 12,905 1.24 10.22 13,490 ND 1262 66 12.4 <1 9.4 2.4 0.04 15.4 7.0 10.3 23.0 2.4KY Perry Hazard #4, Alma, Hazard #8, Hazard #9, Hazard #10



### Page 82 of 121 part II, 3

### GEORGIA POWER - PLANT BOWEN 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 BerylliumCadmiumChromium 

### Cobalt Lead Manganese

### Selenium Coal Seam Nickel, ppm Other trace metal HAP, ppm45 

### State/ Country County Chlorine, ppm Fluorine,

ppm Total amount of fuel represented by sample, tons 

### Sample ID # Total Sulfur, % Ash

Content, % Heating Value, Btu/lb Mercury,

ppm

09-433 12,680 1.06 8.34 13,737 ND 1999 59 13.8 1.0 7.0 2.1 0.04 13.4 7.4 8.3 16.9 3.0KY Perry Elkhorn #3, Elkhorn #2, Hazard #8, Hazard #7

09-434 10,800 1.01 12.87 12,856 ND 506 101 10.6 <1 7.7 1.8 ND 23.3 7.0 10.4 11.1 3.6KY Perry and Breathitt Hazard 5A,

Hazard #7, Hazard #8, Hazard #9, Hazard #10

09-435 12,885 1.38 8.52 13,711 0.060 109 120 11.5 <1 14.2 1.4 0.11 14.3 5.6 7.1 0.1 2.8KY Bell Garmeda Seam, Buckeye Springs Seam, Stray Seam

09-236 12,904 1.02 12.06 13,024 0.092 697 74 14.1 <1 8.4 2.3 0.03 20.1 7.1 8.3 10.8 4.0WV Boone 5-block, Stockton

09-237 11,038 1.02 10.17 13,539 ND 1333 67 14.1 1.0 7.1 2.8 ND 16.7 9.3 7.5 13.6 3.3KY Perry Amburgy, Hazard 8, Hazard 7, Hazard 5A

09-438 11,445 1.49 10.97 13,302 0.117 927 94 21.4 1.2 10.6 3.3 0.10 18.7 10.7 7.4 10.8 4.0KY Bell Hazard #8, Hazard #9, Hazard #10, Hazard #4

09-439 12,998 1.02 10.85 13,287 ND 683 90 12.8 <1 8.8 1.8 0.04 14.6 7.9 7.4 29.8 3.4KY Bell Hance, Hazard 8, Kellioki, Darby

09-440 12,924 1.69 10.25 13,386 0.098 380 96 17.4 1.2 17.4 1.7 0.10 16.7 7.0 8.2 40.8 2.5KY Harlan Upper Harlan, Harlan, Darby, Hazard #8, Hazard #9, Hazard #4 rider

09-441 11,536 1.58 11.78 13,077 0.092 697 74 14.1 <1 8.4 2.3 0.03 20.1 7.1 8.3 10.8 4.0KY Perry Hazard 5A, Hazard#7, Hazard #8, Hazard #9

09-240 12,908 1.01 9.46 13,576 ND 1501 133 11.7 1.0 5.7 2.5 0.05 14.0 7.0 8.2 19.5 2.5KY Perry, LetcherHazard 4, Hazard 5A, Alma

09-242 12,812 1.09 11.84 13,277 0.091 1735 96 13.0 <1 17.0 2.7 0.04 16.5 7.5 8.6 35.8 3.4WV Boone Cedar Grove, Winifrede



### Page 83 of 121 part II, 3

### GEORGIA POWER - PLANT BOWEN 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 BerylliumCadmiumChromium 

### Cobalt Lead Manganese

### Selenium Coal Seam Nickel, ppm Other trace metal HAP, ppm45 

### State/ Country County Chlorine, ppm Fluorine,

ppm Total amount of fuel represented by sample, tons 

### Sample ID # Total Sulfur, % Ash

Content, % Heating Value, Btu/lb Mercury,

ppm

09-442 12,855 1.44 9.79 13,612 0.058 1437 79 13.7 1.7 21.0 3.6 0.14 14.1 7.2 10.4 29.1 1.9KY Harlan, Bell Hazard #4, Hazard #4 rider, Hazard #7, Hazard #8, Hazard #9

09-443 12,664 0.9 10.3 13,598 ND 105 60 12.4 1.0 4.7 2.1 0.03 16.7 7.9 9.1 23.4 2.8KY Harlan Highsplint, Winifrede, Low splint, Lower Harlan, D seam, Kellioki, Imbodden, Owl

09-445 12,890 1.53 8.45 13,778 0.076 61 56 11.1 <1 12.5 1.4 0.08 14.3 5.8 7.6 37.5 2.8KY Bell Garmeda Seam, Buckeye Springs Seam, Stray Seam 09-533 11,033 1.52 13.61 12,982 0.066 1038 102 12.9 1.4 27.7 3.6 0.08 16.7 8.5 8.1 27.2 2.3KY Pike Elkhorn 1, 2, 3

09-243 12,650 1.1 13.35 12,755 0.096 867 96 15.0 1.2 9.5 2.9 ND 18.8 8.9 9.2 16.9 3.9KY Magoffin, PerryFireclay, Hazard 5, Amburgey, Peach Orchard, Hazard 7, Hazard 8

09-446 10,953 0.67 9.12 13,438 ND 329 71 15.6 <1 5.2 1.6 ND 13.0 8.2 4.9 24.9 3.1KY Harlan Harlan, Kellioki, Creech, Darby, Imbodden

09-447 11,310 0.91 9.67 13,446 ND 223 70 15.1 1.3 9.0 2.7 0.03 15.3 8.5 8.1 31.6 2.3KY Harlan Harlan, Creech, Kellioki, Darby, Splint

09-448 11,207 0.91 8.24 13,773 ND 1815 64 13.0 1.0 10.3 2.2 0.02 13.1 7.8 7.6 16.3 3.5KY Perry Elkhorn #3, Elkhorn #2, Hazard #8, Hazard #7

09-238 11,588 1.76 12.44 12,916 0.089 590 81 14.9 1.0 10.3 2.7 ND 19.3 9.2 9.4 15.2 4.0KY Perry Hazard #7, Hazard #8, Hazard #9, Hazard 5A, Hazard #4



### Page 84 of 121 part II, 3

### GEORGIA POWER - PLANT BOWEN 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 BerylliumCadmiumChromium 

### Cobalt Lead Manganese

### Selenium Coal Seam Nickel, ppm Other trace metal HAP, ppm45 

### State/ Country County Chlorine, ppm Fluorine,

ppm Total amount of fuel represented by sample, tons 

### Sample ID # Total Sulfur, % Ash

Content, % Heating Value, Btu/lb Mercury,

ppm

44

### To the extent that a vendor provides these data or that a facility is required by State or local agency to analyze its fuel for HAP constituents (e.g., Cl, F), and any metallic HAP (e.g., Hg, Pb, As, Se, etc.), EPA wishes the responding facility to provide those fuel analyses results. Otherwise, this 12-month fuel analysis requirement can be bypassed by the respondent.
45

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



### Page 85 of 121 part II, 3

### Train

Train

Train

Train

Train

Train

Train

Train

Train

Train 

### Fuel Shipment Method

Page 86 of 121 part II, 3

### Fuel Shipment Method

Train

Train

Train

Train

Train

Train Train

Train

Train Train

Train

Train



### Page 87 of 121 part II, 3

### Fuel Shipment Method

Train

Train

Train

Train

Train

Train

Train

Train

Train



### Page 88 of 121 part II, 3

### Fuel Shipment Method

Train

Train

Train

Train

Train Train

Train

Train

Train

Train

Train

Train

Train



### Page 89 of 121 part II, 3

### Fuel Shipment Method

Train

Train

Train

Train

Train

Train

Train

Train

Train



### Page 90 of 121 part II, 3

### Fuel Shipment Method

Train

Train

Train

Train

Train

Train

Train

Train

Train

Train

Train



### Page 91 of 121 part II, 3

### Fuel Shipment Method

Train

Train

Train Train

Train

Train

Train

Train

Train



### Page 92 of 121 part II, 3

### Fuel Shipment Method

Page 93 of 121 part II, 3

### GEORGIA POWER - PLANT BOWEN

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 94 of 121 part II, 4-6

### GEORGIA POWER - PLANT BOWEN

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

Moisture

### Volatiles Ash Fixed Carbon Carbon Hydrogen

### Nitrogen Total Sulfur Oxygen Barium Copper Magnesium

### SodiumVanadium 

### Zinc Al2O3Fe2O3

### CaO MgOMnO2P2O5 K2O SiO2Na2OSO3 TiO2
09-502 8.68 31.06 10.42 58.53 76.33 4.59 1.36 0.61 6.69 246 18.2 0.093 0.037 27.7 11.2 27.8 6.19 1.2 1.44 ND ND 3.71 52.30.5470.817 1.25 09-200 6.02 32.43 14.99 52.59 73.86 4.6 1.37 1.09 4.09 143 25.4 0.098 0.031 37.6 25.9 25.3 7.82 1.03 1.14 ND ND 

### 2.97 57.8 0.34 0.64 1.65 09-202 7.2 35.77 13.3 50.93 74.22 4.74 1.43 1.06 5.24 133 25.7 0.062 0.019 38.7 16.8 27.7 6.22 1.110.844 ND ND 

### 2.3 54.40.2740.587 1.8 09-206 6.27 36.41 12.5 51.09 74.39 4.94 1.59 1.58 5 132 25.4 0.083 0.041 42.5 32.7 24.7 12.4 1.66 1.04 ND ND 

### 2.35 48.40.4940.938 1.36 09-207 5.78 35.9 13.23 50.88 72.61 4.76 1.45 1.32 6.64 163 20.4 0.063 0.016 37.5 13.1 28.9 7.92 1.14 0.75 ND ND 

### 2.13 52.50.2140.524 1.4 09-208 6.52 36.53 10.53 52.94 76.33 4.92 1.65 1.01 5.56 112 19.3 0.073 0.032 28.2 19.2 26.3 8.31 1.78 1.13 ND ND 

### 2.61 52.80.512 1.32 1.34 09-402 6.11 35.24 10.92 53.84 75.59 4.8 1.79 1.17 5.73 142 20.1 0.084 0.037 40.3 27.1 22.2 12.6 1.75 1.11 ND

### 0.633 2.72 51.40.4740.889 1.21 09-403 7.84 36.22 7.97 55.81 78.63 4.98 1.63 1.02 5.78 102 18.7 0.059 0.024 29.2 16.0 25.6 11.2 2.05 1.11 ND ND 

### 2.69 50.40.449 1.3 1.25 09-204 7.33 34.42 13.29 52.3 73.32 4.68 1.42 1.21 6.08 113 21.2 0.086 0.020 37.1 18.0 27.6 8.570.996 1.03 ND ND 

### 3.1 51.80.229 ND 

### 1.21 09-404 6.37 34.25 10.64 55.11 77.44 4.83 1.51 0.96 4.6 122 20.9 0.071 0.034 33.5 15.7 27.4 7.05 1.590.955 ND ND 

### 2.68 53.70.4220.878 1.43 09-405 7.99 35.92 10.46 53.62 77.9 4.93 1.61 0.95 4.16 224 37.1 0.118 0.057 63.3 25.3 28.1 6.4 1.80.862 ND

### 0.485 2.26 51.40.4140.956 1.39 09-406 4.82 34.97 11.16 53.88 76.49 4.79 1.56 0.85 5.15 112 17.4 0.055 0.028 26.1 9.6 26.3 5.4 1.250.785 ND ND 

### 2.23 56 0.370.633 1.45 09-407 6.02 36.85 9.83 53.32 75.27 4.88 1.77 1.82 6.43 102 20.6 0.069 0.016 46.6 20.6 24.6 16.7 3.070.895 ND 

### 1.68 ND 

### 44.60.2030.636 1.34 09-408 7.46 34.97 13.54 51.5 71.21 4.61 1.43 1.17 8.04 133 19.6 0.049 0.011 32.9 11.1 26.4 6.26 1.140.588 ND ND 

### 1.8 58.2 ND ND 

### 1.57 09-209 6.45 37.34 8.93 53.73 76.98 5.08 1.24 1.51 6.26 143 23.5 0.057 0.030 33.3 17.1 25.3 14.4 2.6 1.09 ND ND 

### 2.32 43.80.545 2.03 1.31 09-210 6.53 31.74 13.84 54.43 71.68 4.85 1.38 0.68 7.59 60 19.0 0.067 0.019 35.9 12.0 27.6 3.380.646 0.85 ND ND 

### 2.55 61.2 0.24 ND 

### 1.59 09-212 6.87 35.73 11.94 52.33 73.75 4.84 1.28 1.21 6.99 204 20.1 0.079 0.029 30.1 13.1 27.3 10.1 2.63 1.17 ND ND 

### 2.83 50.70.457 1.86 1.51 09-213 6.71 35.82 13.03 51.16 72.13 4.81 1.39 1.47 7.18 133 18.8 0.063 0.016 31.6 14.2 27.1 10.5 1.060.872 ND ND 

### 2.22 56.90.2360.427 1.37 09-416 6.4 35.15 9.91 54.94 76.35 5.06 1.61 1.17 5.9 90 22.8 0.058 0.029 40.7 20.728.94 7.36 1.28 0.980.032 0.28 2.6855.02 0.39 1.48 1.36 09-518 5.64 32.3 11.57 56.12 77.19 4.73 1.38 1.46 3.67 418 19.0 0.100 0.037 24.5 13.6 23.6 11.9 1.31 1.33 ND ND 

### 3.43 53.90.4780.974 1.04 09-222 6.43 36.45 8.72 54.83 74.25 4.95 1.82 0.89 9.37 92 17.0 0.045 0.035 26.1 14.9 27.2 6.94 1.340.819 ND ND 

### 1.93 49.70.5640.835 1.37 09-420 7.31 36.44 12.34 51.22 69.95 4.65 1.47 1.33 10.26 154 18.1 0.063 0.016 34.5 16.5 25.1 9.16 1.480.916 ND ND 

### 2.08 50.50.2160.803 1.36 09-421 6.84 36.29 8.42 55.29 75.08 4.91 1.68 1.09 8.82 112 18.9 0.046 0.030 32.8 12.0 28.5 8.31 2.470.919 ND

### 0.685 1.99 47.30.628 1.79 1.59 09-422 4.89 35.09 10.97 53.94 73.33 4.8 1.57 0.77 8.56 102 15.3 0.056 0.024 26.1 9.5 27.4 5.1 1.230.903 ND ND 

### 2.11 540.3910.639 1.52 09-418 5.99 34.06 11.36 54.58 75.53 4.88 1.48 1.12 5.63 102 20.7 0.075 0.037 35.9 16.4 26.4 8.43 1.58 1.02 ND ND 

### 2.53 49.30.532 1.15 1.52 09-419 6.23 36.36 9.59 54.05 74.33 4.91 1.81 1.33 8.04 82 20.6 0.069 0.015 43.3 26.4 25.7 13.9 2.52 1.18 ND 

### 1.26 2.39 45.3 0.290.809 1.37 09-414 5.87 34.56 11.72 53.72 73.05 4.72 1.63 1.03 7.84 154 20.0 0.068 0.023 29.8 12.0 25.2 7.89 1.490.949 ND

### 0.418 2.07 51.60.3030.784 1.72 09-413 6.08 33.54 14.07 52.4 71.15 4.65 1.53 1.38 7.23 153 25.5 0.117 0.029 46.4 29.4 27.8 10.4 1.88 1.39 ND

### 0.434 3.08 54.3 0.35 1.1 1.27 09-417 6.43 35.23 10.57 54.19 74.52 4.83 1.48 1.15 7.44 113 17.5 0.073 0.010 30.4 21.5 27.4 16.3 2.1 1.21 ND

### 0.895 2.75 48.30.2060.682 1.19 09-415 8.61 34.91 10.48 54.61 73.16 4.79 1.48 0.91 9.19 123 19.3 0.089 0.033 30.7 16.0 25.2 8.3 1.56 1.42 ND ND 

### 3.19 53.80.494 1.07 1.15 09-409 8.39 34.31 13.05 52.46 70.77 4.53 1.48 0.89 9.28 143 21.4 0.052 0.013 32.4 9.4 27.5 4.26 1.190.621 ND

### 0.471 1.72 55.40.1770.432 1.89 09-410 8.08 34.19 12.56 53.24 73.61 4.63 1.54 1.02 6.63 155 19.2 0.078 0.019 29.4 14.3 27.4 2.4 1.740.972 ND

### 0.544 2.65 570.248 1.19 1.34 09-215 5.28 33.02 13.52 53.46 73.11 4.59 1.37 1.08 6.32 163 17.6 0.092 0.025 29.1 17.1 26.4 8.07 1.15 1.07 ND ND 

### 2.85 57.40.3260.628 1.51 09-218 6.69 36.94 7.97 55.1 77.68 5.02 1.53 1.44 6.36 112 23.8 0.053 0.030 30.7 14.4 26.2 12.7 2.48 1.04 ND ND 

### 2.47 47.50.559 2.06 1.14 09-219 7.23 37.04 10.85 52.09 77.23 5.01 1.51 1.36 4.03 92 18.7 0.052 0.016 32.2 14.4 28 8.09 1.330.739 ND ND 

### 2.14 55.30.2490.806 1.33 09-220 5.95 31.47 13.86 54.67 72.91 4.57 1.37 0.64 6.66 92 15.7 0.074 0.022 33.3 14.7 29.6 3.480.6830.933 ND ND 

### 2.8 620.273 ND 

### 1.42 Sample ID # Proximate Analyses, % by wt Ultimate Analyses, % by wt Ash Mineralogy, % by wt Other Trace Metals, ppm, dry basis

Page 95 of 121 part II, 7

### GEORGIA POWER - PLANT BOWEN

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

Moisture

### Volatiles Ash Fixed Carbon Carbon Hydrogen

### Nitrogen Total Sulfur Oxygen Barium Copper Magnesium

### SodiumVanadium 

### Zinc Al2O3Fe2O3

### CaO MgOMnO2P2O5 K2O SiO2Na2OSO3 TiO2 Sample ID # Proximate Analyses, % by wt Ultimate Analyses, % by wt Ash Mineralogy, % by wt Other Trace Metals, ppm, dry basis

09-522 5.96 33.04 10.85 56.11 74.48 4.7 1.44 1.45 7.09 310 18.1 0.080 0.030 24.9 14.1 25.5 12.1 1.29 1.28 ND ND 

### 3.29 49.10.4690.908 1.18 09-223 5.01 32.06 13.15 54.78 72.79 4.57 1.48 0.96 7.04 81 20.9 0.052 0.016 27.5 10.0 26.8 5.02 0.820.625 ND ND 

### 2.31 58.10.2140.624 1.69 09-224 5.12 35.23 10.78 53.99 74.91 4.9 1.74 0.89 6.77 92 17.0 0.045 0.035 26.1 14.9 28.3 6.71 1.620.962 ND ND 

### 2.09 61.7 0.49 1.13 1.42 09-225 5.15 37.79 8.13 54.09 77.75 5.12 1.77 1.47 5.76 122 22.8 0.054 0.031 31.1 16.2 24.8 15.1 2.84 1.07 ND ND 

### 2.24 490.585 2.34 1.13 09-227 7.08 31.39 14.19 54.22 71.4 4.58 1.34 0.54 7.95 92 16.9 0.067 0.022 39.3 13.1 30.4 2.7 0.860.859 ND ND 

### 2.39 57.2 0.290.409 1.55 09-228 5.61 34.09 11.63 54.27 68.53 4.49 1.46 1.09 12.8 184 25.7 0.067 0.028 31.9 15.9 25.9 7.45 1.32 0.97 ND ND 

### 2.47 53.20.3410.833 1.45 09-444 7.05 33.46 12.88 53.66 72.72 4.83 1.54 0.8 7.23 160 24.7 0.048 0.018 39.1 9.126.38 3.61 1.04 0.610.017 0.38 1.8462.66 0.19 0.87 2.22 09-230 7.44 36.27 13.47 50.26 70.09 4.51 1.55 1.14 9.24 144 34.4 0.069 0.022 51.8 26.1 29.2 6.1 1.120.913 ND ND 

### 2.36 53.90.2560.935 1.37 09-423 6.5 35.5 11.99 52.51 72.73 4.6 1.55 1.34 7.78 143 24.2 0.055 0.014 38.3 15.3 29.7 7.94 1.240.773 ND ND 

### 1.99 55.40.2110.884 1.53 09-424 6.46 34.53 10.8 54.66 75.06 4.72 1.6 1.06 6.76 81 27.0 0.062 0.030 40.6 17.6 28.3 5.86 1.560.979 ND ND 

### 2.37 540.453 1.28 1.54 09-425 8.19 33.07 10.97 55.95 73.2 4.46 1.74 0.98 8.64 92 28.8 0.064 0.032 37.1 19.0 26.1 7.55 1.570.987 ND

### 0.489 2.37 55.30.302 1.1 1.52 09-426 7.44 34.5 9.28 56.21 75.38 4.81 1.5 1.23 7.81 143 28.2 0.077 0.027 42.9 23.8 23.4 11.9 1.55 1.25 ND ND 

### 2.7 52.40.599 1.38 1.17 09-427 5.66 33.3 11.18 55.52 73.4 4.64 1.61 1.33 7.85 245 27.6 0.070 0.031 46.8 29.4 26.5 13.2 1.7 1.35 ND

### 0.529 2.86 49.20.462 1.26 1.27 09-428 6.51 36.36 9.48 54.17 74.68 4.87 1.57 1.07 8.33 61 28.6 0.042 0.014 44.3 23.0 27.5 7.37 1.260.875 ND ND 

### 2.17 540.4180.979 1.38 09-232 7.84 35.24 13.46 51.3 70.05 4.53 1.41 1.52 9.03 164 60.9 0.121 0.031 92.2 46.1 27 10.20.9670.749 ND ND 

### 1.74 560.2220.717 1.55 09-431 6.62 35.08 9.05 55.87 75.57 4.73 1.51 0.95 8.18 92 21.1 0.047 0.021 32.9 16.3 28.2 9.7 1.85 1.02 ND 

### 1.1 2.35 49.7 0.20.692 1.41 09-432 6.09 35 10.22 54.78 75.13 4.76 1.61 1.24 7.05 92 19.9 0.052 0.036 30.3 17.3 24.4 8.4 1.270.791 ND ND 

### 1.98 52.80.4690.888 1.47 09-433 6.62 35.69 8.34 55.97 76.07 4.84 1.6 1.06 8.09 92 21.5 0.046 0.032 30.8 13.1 28.1 7.94 2.270.929 ND ND 

### 2.08 50.80.564 1.93 1.46 09-434 6.23 33.69 12.87 53.44 71.73 4.46 1.46 1.01 8.46 102 20.1 0.044 0.013 34.0 8.7 25.4 4.28 1.170.531 ND

### 0.526 1.43 55.2 0.16 ND 

### 1.88 09-435 4.86 35.82 8.52 55.65 76.05 4.94 1.87 1.38 7.23 193 18.6 0.058 0.016 37.1 16.9 26 13.8 2.7 1.03 ND 

### 1.35 2.15 44.50.314 1.28 1.28 09-236 7.1 34.32 12.06 53.62 72.31 4.59 1.41 1.02 8.61 103 17.2 0.054 0.012 32.6 12.2 29.1 4.040.8110.596 ND ND 

### 1.55 540.183 ND 

### 1.76 09-237 5.52 34.93 10.17 54.89 74.91 4.79 1.59 1.02 7.52 81 18.4 0.053 0.024 30.3 19.6 30.7 4.89 1.220.825 ND ND 

### 1.77 54.70.3470.911 1.4 09-438 6.71 34.77 10.97 54.26 73.52 4.74 1.46 1.49 7.82 133 20.4 0.062 0.011 40.2 18.3 31.7 8.48 1.40.986 ND

### 0.768 2.54 49.70.197 0.65 1.48 09-439 8.91 34.1 10.85 55.04 74.02 4.67 1.58 1.02 7.86 215 17.8 0.070 0.026 24.8 12.5 29.9 8.05 1.62 1.21 ND ND 

### 2.65 53.40.346 1.23 1.49 09-440 5.54 35.82 10.25 53.93 74.09 4.83 1.69 1.69 7.44 184 19.5 0.071 0.030 37.8 29.6 28.7 14.7 1.74 1.15 ND

### 0.551 2.5 44.30.431 1.45 1.13 09-441 7.66 36.36 11.78 51.85 72.24 4.72 1.44 1.58 8.25 103 17.2 0.054 0.012 32.6 12.2 30.1 9.25 10.763 ND ND 

### 1.97 53.70.2290.528 1.63 09-240 7.39 35.3 9.46 55.23 75.99 4.79 1.72 1.01 7.04 92 16.2 0.051 0.032 26.4 15.8 25.5 7.8 1.540.916 ND ND 

### 2.23 54.70.5320.795 1.51 09-242 5.16 33.72 11.84 54.45 74.21 4.65 1.46 1.09 6.75 174 20.7 0.079 0.026 25.8 13.6 27.8 9.11 1.39 1.07 ND ND 

### 2.81 49.30.3380.717 1.45 09-442 6.98 36.33 9.79 53.88 75.62 4.89 1.71 1.44 6.55 92 22.8 0.052 0.035 36.1 30.4 24.5 10.5 1.730.902 ND ND 

### 2.2 57.80.5530.979 1.53 09-443 6.03 34.1 10.3 55.59 76.39 4.73 1.53 0.9 6.14 81 19.5 0.064 0.033 32.1 14.7 25.8 6 1.920.922 ND ND 

### 2.28 55.10.463 1.3 1.54 09-445 4.07 36.77 8.45 54.77 76.74 4.91 1.83 1.53 6.55 193 18.2 0.058 0.016 39.9 16.8 24.5 14.5 3.11 1.02 ND 

### 1.45 2.08 46.90.3080.971 1.35 09-533 5.66 32.64 13.61 53.76 72.84 4.6 1.31 1.52 6.12 478 18.9 0.098 0.037 29.4 15.0 25 11.9 1.36 1.21 ND ND 

### 3.49 52.10.466 1.03 1.28 09-243 7.6 35.37 13.35 51.27 70.42 4.63 1.52 1.1 8.98 144 22.1 0.077 0.022 35.5 16.5 28.1 6.72 1.25 0.95 ND ND 

### 2.62 56.7 0.280.593 1.38 09-446 8.98 34.77 9.12 56.11 75.78 4.72 1.49 0.67 8.22 154 14.8 0.066 0.016 22.3 22.3 28.8 6.86 2.13 1.27 ND ND 

### 2.88 56.40.2860.907 1.33 09-447 8.22 35.99 9.67 54.33 74.45 4.77 1.73 0.91 8.48 113 21.2 0.068 0.034 35.8 22.2 27.1 7.87 2.12 1.11 ND ND 

### 2.49 53.80.508 1.25 1.24 09-448 6.88 35.96 8.24 55.8 76.49 4.88 1.61 0.91 7.87 92 19.7 0.040 0.030 28.3 10.4 28.6 6.94 2.320.798 ND

### 0.435 1.81 53.30.576 1.56 1.59 09-238 7.14 35.53 12.44 52.03 71.15 4.63 1.37 1.76 8.65 92 20.1 0.054 0.016 32.6 14.0 30 8.46 1.020.753 ND ND 

### 1.88 52.40.2050.466 1.5

Page 96 of 121 part II, 7

### GEORGIA POWER - PLANT BOWEN

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 16, 2006) Report 2 Unit 2 Particulate Emissions Test (February 16, 2006) Report 3 Unit 3 Particulate Emissions Test (February 15, 2006) Report 4 Unit 4 Particulate Emissions Test (February 15, 2006) Report 5 Unit 3 Particulate Emissions Test (October 30, 2007) Report 6 Unit 4 Particulate Emissions Test (October 30, 2007) Report 7 Unit 3 Particulate Emissions Test, FGD Stack (March 10, 2008) Report 8 Unit 3 CAM Testing, FGD Stack (March 13, 2008) Report 9 Unit 1 Particulate Emissions Test (March 19, 2008) Report 10Unit 2 Particulate Emissions Test (March 19, 2008) Report 11Unit 4 Particulate Emissions Test, FGD Stack (November 13, 2008) Report 12Unit 2 Particulate Emissions Test, FGD Stack (May 29, 2009) Report 13Unit 1 Boiler O2 Verification (August 23, 2007 to August 28, 2007) Report 14Unit 2 Boiler Diagnostic (April 3, 2007 to April 5, 2007) Report 15Unit 3 Boiler Optimization (February 1, 2007 to February 8, 2007) Report 16Unit 4 Air Preheater Guarantee (March 9, 2006) Report 17Unit 3 Scrubber Mercury testing (May 5, 2008 to May 10, 2008) Report 18Unit 3 SO3 testing (May 2008) Report 19Unit 4 SO3 testing (November - December 2009) Report 20Unit 2 Lime Injection into ESP (September 2005) Report 21Unit 3 Trona Injection into ESP (February 2006)

Page 97 of 121 part II, 8

### GEORGIA POWER - PLANT BOWEN

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

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:2/16/2006 Type:stack Constituents:PM Report 2 Date:2/16/2006 Type:stack Constituents:PM Report 3 Date:2/15/2006 Type:stack Constituents:PM Report 4 Date:2/15/2006 Type:stack Constituents:PM Report 5 Date:10/30/2007 Type:stack Constituents:PM Report 6 Date:10/30/2007 Type:stack Constituents:PM Report 7 Date:3/10/2008 Type:stack Constituents:PM Report 8 Date:3/10/2008 Type:stack Constituents:PM Report 9 Date:3/19/2008 Type:stack Constituents:PM Report 10 Date:3/19/2008 Type:stack Constituents:PM Report 11 Date:11/13/2008 Type:stack Constituents:PM Report 12 Date:5/29/2009 Type:stack Constituents:PM Report 13 Date:8/23/2007-8/28/2007 Type:duct Constituents:CO Report 14 Date:4/3/2007-4/5/2007 Type:duct Constituents:CO Report 15 Date:2/1/2007-2/8/2007 Type:duct Constituents:CO Report 16 Date:3/9/2006 Type:duct Constituents:CO Report 17 Date:5/5/2008-5/10/2008 Type:duct/stack Constituents:Hg Report 18 Date:May 2008 Type:duct/stack Constituents:SO3 Report 19 Date:Nov - Dec 2009 Type:duct/stack Constituents:SO3 Report 20 Date:Sept 2005 Type:duct/stack Constituents:SO3 Report 21 Date:Feb 2006 Type:duct/stack Constituents:SO3

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 Reports 13, 14, 15 reflect testing at the economizer outlet (upstream of all post-combustion control devices), and Reports 16 reflects testing at both the economizer outlet and air preheater outlet (upstream of all post-combustion control devices), there are no control devices downstream designed to reduce CO. Report 17 reflects testing upstream of the scrubber, at the ESP outlets. Reports 18, 19 reflect testing upstream of the scrubber and lime injection systems, at the inlet duct. Reports 20, 21 reflect testing upstream of the ESP.

Page 98 of 121 part II, 8

### GEORGIA POWER - PLANT BOWEN

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

Page 99 of 121 part II, 8

### GEORGIA POWER - PLANT BOWEN

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

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, 5, 6, 9, 10, 13, 14, 15, 16, 21.

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 (ammonia)

2 tangentialfired (1) low-NOX concentric

firing system + separated overfire air (3) cold-side electrostatic precipitator (2) flue gas conditioning (ammonia)

3 tangentialfired (1) low-NOX concentric

firing system + separated overfire air (3) cold-side electrostatic precipitator (2) flue gas conditioning (ammonia)

4 tangentialfired (1) low-NOX concentric

firing system + separated overfire air (3) cold-side electrostatic precipitator (2) flue gas conditioning (ammonia)



### Page 100 of 121 part II, 8

### GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631 April 5, 2010
The control configuration shown below is representative of the conditions present during Report 20.

Boiler ID Type NOx control SO2 control PM control Other control 2 tangentialfired (1) low-NOX concentric

firing system + separated overfire air (2) SCR (4) cold-side electrostatic precipitator (3) flue gas conditioning (ammonia)



### The control configuration shown below is representative of the conditions present during Reports 7, 8, 11, 12, 17, 18, 19.

Boiler ID Type NOx control SO2 control PM control Other control 2 tangentialfired (1) low-NOX concentric

firing system + separated overfire air (2) SCR (5) wet flue gas desulfurization (FGD) (3) cold-side electrostatic precipitator (4) hydrated lime injection

3 tangentialfired (1) low-NOX concentric

firing system + separated overfire air (2) SCR (5) wet flue gas desulfurization (FGD) (3) cold-side electrostatic precipitator (4) hydrated lime injection

4 tangentialfired (1) low-NOX concentric

firing system + separated overfire air (2) SCR (5) wet flue gas desulfurization (FGD) (3) cold-side electrostatic precipitator (4) 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 17, 18, 19 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 101 of 121 part II, 8

### GEORGIA POWER - PLANT BOWEN

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 malfuncation 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 2 (scrubber stack): June 4, 2009 - December 31, 2009 Unit 3 (scrubber stack): January 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 102 of 121 part II, 9-11

### GEORGIA POWER - PLANT BOWEN

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 2/16/2006 See Attachment 1Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 2 2/16/2006 See Attachment 2Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 3 2/15/2006 See Attachment 3Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 4 2/15/2006 See Attachment 4Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 3 10/30/2007 See Attachment 5Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 4 10/30/2007 See Attachment 6Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 3 3/10/2008 See Attachment 7Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 3 3/13/2008 See Attachment 8Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 1 3/19/2008 See Attachment 9Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 2 3/19/2008 See Attachment 10Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 4 11/13/2008 See Attachment 11Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 2 5/29/2009 See Attachment 12Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable 1 8/23/2007-8/28/2007Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 13Not applicable 2 4/3/2007-4/5/2007 Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 14Not applicable 3 2/1/2007-2/8/2007 Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 15Not applicable 4 3/9/2006 Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 16Not applicable 3 5/5/2008-5/10/2008 Not applicable Not applicable Not applicable Not applicable See Attachment 17Not 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. 

### Boiler ID Emissions test results (indicate format of emission data)47,48



### Page 103 of 121 part II, 12

### GEORGIA POWER - PLANT BOWEN

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) Boiler ID Emissions test results (indicate format of emission data)47,48

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.



### Page 104 of 121 part II, 12

## ATTACHMENT 1 - Bowen Report 1 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 2/16/2006 2/16/2006 2/16/2006 Run Start Time 9:00 14:42 16:40 Run End Time 10:15 16:00 17:55 Meter Volume (dacf), Vm: 39.9 39.691 39.695 Sqrt Delta P ("wc): 1.43 1.42 1.42 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 29.28 29.28 29.28 Delta H ("wc): 1.3 1.3 1.3 Volume in Impingers (mls), VIc: 51.3 51.0 52.2 Static Pressure ("wc), Pg: -2.80 -2.60 -2.80 Stack Pressure ("Hg), Ps: 29.07 29.09 29.07 Stack Temperature (F), Ts: 302 311 311 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: 78 84 88 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): 12.0 11.8 12.1 Percent O2 (% dry volume): 7.3 7.5 7.3 Percent (N2 + CO) (% dry volume): 80.7 80.7 80.6 Particulate Collected (mg), Mn: 45.2 46.4 43.0

Molec. Wt. Dry

(lb/lb-mole), Md: 30.212 30.188 30.228 Volume Water (scf), Vwstd 2.415 2.401 2.457 Meter Volume (dscf), Vmstd: 38.013 37.381 37.141 Wet Fraction (v/v), Bws: 0.060 0.060 0.062 Molec. Wt. Wet (lb/lb-mole), Ms: 29.483 29.453 29.469 Stack Gas Sampled (acf), Vma: 60.049 59.750 59.511 Averages Stack Gas Velocity

(fps), Vs: 96.72 96.46 96.90 97 Volumetric Flowrate (dscfm), Qs: 1,803,371 1,777,444 1,781,220 1,787,345 Volumetric Flowrate (acfm), Qa: 2,848,756 2,841,076 2,854,042 2,847,958 Grainloading (gr/dscf), cs: 0.0184 0.0191 0.0179 0.02 Emission Rate (lb/hour), E: 283.82 291.71 272.70 282.7 Percent Isokinetic Sampling (%), I: 99.58 99.35 98.50 99.14
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 7199.30 6991.44 7110.87 7100.54 Emission Rate (lbs/mmBtu), E: 0.04 0.04 0.04 0.04 Allowable Rate (lb/mmBtu): 0.240 0.240 0.240 0.240 Average Unit Gross Load (MW) 739 739 739 739 

### Particulate Emission Results Summary

Bowen Unit 1

Page 105 of 121 Att. 1

## ATTACHMENT 2 - Bowen Report 2 Test Results

Performed Dy: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 2/16/2006 2/16/2006 2/16/2006 Run Start Time 9:00 14:42 16:40 Run End Time 10:15 16:00 17:55 Meter Volume (dacf), Vm: 38.963 39.158 39.35 Sqrt Delta P ("wc): 1.37 1.38 1.38 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 29.28 29.28 29.28 Delta H ("wc): 1.3 1.3 1.3 Volume in Impingers (mls), VIc: 53.1 52.8 52.4 Static Pressure ("wc), Pg: -2.50 -2.60 -2.70 Stack Pressure ("Hg), Ps: 29.10 29.09 29.08 Stack Temperature (F), Ts: 270 284 285 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 80 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): 12.5 12.2 12.3 Percent O2 (% dry volume): 7.2 7.4 7.4 Percent (N2 + CO) (% dry volume): 80.3 80.4 80.3 Particulate Collected (mg), Mn: 48.2 48.2 36.6

Molec. Wt. Dry

(lb/lb-mole), Md: 30.288 30.248 30.264 Volume Water (scf), Vwstd 2.499 2.485 2.466 Meter Volume (dscf), Vmstd: 37.746 37.435 37.285 Wet Fraction (v/v), Bws: 0.062 0.062 0.062 Molec. Wt. Wet (lb/lb-mole), Ms: 29.525 29.485 29.503 Stack Gas Sampled (acf), Vma: 57.198 57.833 57.694 Averages Stack Gas Velocity

(fps), Vs: 90.98 92.14 92.40 92 Volumetric Flowrate (dscfm), Qs: 1,768,226 1,756,588 1,758,762 1,761,192 Volumetric Flowrate (acfm), Qa: 2,679,473 2,713,725 2,721,424 2,704,874 Grainloading (gr/dscf), cs: 0.0197 0.0199 0.0151 0.02 Emission Rate (lb/hour), E: 298.54 299.04 228.24 275.3 Percent Isokinetic Sampling (%), I: 100.84 100.67 100.15 100.55
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 7110.90 6960.97 6969.59 7013.82 Emission Rate (lbs/mmBtu), E: 0.04 0.04 0.03 0.04 Allowable Rate (lb/mmBtu): 0.240 0.240 0.240 0.240 Average Unit Gross Load (MW) 736 736 736 736 

### Particulate Emission Results Summary

Bowen Unit 2

Page 106 of 121 Att. 2

## ATTACHMENT 3 - Bowen Report 3 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 2/15/2006 2/15/2006 2/15/2006 Run Start Time 8:00 9:50 11:30 Run End Time 9:20 11:05 12:45 Meter Volume (dacf), Vm: 40.784 41.074 41.864 Sqrt Delta P ("wc): 1.44 1.45 1.45 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 29.20 29.20 29.20 Delta H ("wc): 1.3 1.3 1.3 Volume in Impingers (mls), VIc: 52.1 52.3 52.2 Static Pressure ("wc), Pg: -3.30 -3.20 -3.30 Stack Pressure ("Hg), Ps: 28.96 28.96 28.96 Stack Temperature (F), Ts: 294 295 300 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: 87 91 91 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): 14.3 14.2 14.4 Percent O2 (% dry volume): 5.1 5.0 4.9 Percent (N2 + CO) (% dry volume): 80.6 80.8 80.7 Particulate Collected (mg), Mn: 63.2 66.4 70.8

Molec. Wt. Dry

(lb/lb-mole), Md: 30.492 30.472 30.500 Volume Water (scf), Vwstd 2.452 2.462 2.457 Meter Volume (dscf), Vmstd: 38.131 38.123 38.816 Wet Fraction (v/v), Bws: 0.060 0.061 0.060 Molec. Wt. Wet (lb/lb-mole), Ms: 29.737 29.715 29.756 Stack Gas Sampled (acf), Vma: 59.841 59.914 61.383 Averages Stack Gas Velocity

(fps), Vs: 97.06 97.20 97.88 97 Volumetric Flowrate (dscfm), Qs: 1,821,477 1,821,492 1,823,026 1,821,998 Volumetric Flowrate (acfm), Qa: 2,858,549 2,862,656 2,882,911 2,868,039 Grainloading (gr/dscf), cs: 0.0256 0.0269 0.0281 0.03 Emission Rate (lb/hour), E: 399.47 419.32 439.82 419.5 Percent Isokinetic Sampling (%), I: 99.45 99.43 101.15 100.01
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 8447.86 8501.40 8562.08 8503.78 Emission Rate (lbs/mmBtu), E: 0.05 0.05 0.05 0.05 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 909 909 909 909 

### Particulate Emission Results Summary

Bowen Unit 3

Page 107 of 121 Att. 3

## ATTACHMENT 4 - Bowen Report 4 Test Results

Performed Dy: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 2/15/2006 2/15/2006 2/15/2006 Run Start Time 8:00 9:50 11:30 Run End Time 9:20 11:05 12:45 Meter Volume (dacf), Vm: 41.3 42.495 41.248 Sqrt Delta P ("wc): 1.44 1.44 1.44 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 29.20 29.20 29.20 Delta H ("wc): 1.3 1.3 1.3 Volume in Impingers (mls), VIc: 53.1 53.9 54.0 Static Pressure ("wc), Pg: -3.20 -3.10 -3.20 Stack Pressure ("Hg), Ps: 28.96 28.97 28.96 Stack Temperature (F), Ts: 286 289 295 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: 82 85 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): 12.2 12.1 12.4 Percent O2 (% dry volume): 6.6 6.8 6.6 Percent (N2 + CO) (% dry volume): 81.2 81.1 81.0 Particulate Collected (mg), Mn: 48.7 48.7 56.7

Molec. Wt. Dry

(lb/lb-mole), Md: 30.216 30.208 30.248 Volume Water (scf), Vwstd 2.499 2.537 2.542 Meter Volume (dscf), Vmstd: 39.259 40.210 38.882 Wet Fraction (v/v), Bws: 0.060 0.059 0.061 Molec. Wt. Wet (lb/lb-mole), Ms: 29.485 29.483 29.496 Stack Gas Sampled (acf), Vma: 60.979 62.659 61.166 Averages Stack Gas Velocity

(fps), Vs: 96.42 96.98 97.33 97 Volumetric Flowrate (dscfm), Qs: 1,828,359 1,833,012 1,822,267 1,827,879 Volumetric Flowrate (acfm), Qa: 2,839,921 2,856,334 2,866,653 2,854,302 Grainloading (gr/dscf), cs: 0.0192 0.0187 0.0225 0.02 Emission Rate (lb/hour), E: 300.14 293.78 351.45 315.1 Percent Isokinetic Sampling (%), I: 101.43 103.63 100.80 101.95
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 7674.74 7586.66 7649.17 7636.86 Emission Rate (lbs/mmBtu), E: 0.04 0.04 0.05 0.04 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 933 932 933 933 

### Particulate Emission Results Summary

Bowen Unit 4

Page 108 of 121 Att. 4

## ATTACHMENT 5 - Bowen Report 5 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 10/30/2007 10/30/2007 10/30/2007 Run Start Time 10:40 12:50 14:45 Run End Time 11:56 14:05 15:55 Meter Volume (dacf), Vm: 44.788 46.036 46.386 Sqrt Delta P ("wc): 1.64 1.66 1.68 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 29.26 29.26 29.20 Delta H ("wc): 1.7 1.8 1.8 Volume in Impingers (mls), VIc: 50.4 54.1 54.7 Static Pressure ("wc), Pg: -4.10 -4.20 -4.20 Stack Pressure ("Hg), Ps: 28.96 28.95 28.89 Stack Temperature (F), Ts: 305 310 314 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: 90 92 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): 13.5 13.5 13.5 Percent O2 (% dry volume): 6.0 6.0 6.0 Percent (N2 + CO) (% dry volume): 80.5 80.5 80.5 Particulate Collected (mg), Mn: 54.9 61.1 62.0

Molec. Wt. Dry

(lb/lb-mole), Md: 30.400 30.400 30.400 Volume Water (scf), Vwstd 2.372 2.546 2.575 Meter Volume (dscf), Vmstd: 41.698 42.689 42.831 Wet Fraction (v/v), Bws: 0.054 0.056 0.057 Molec. Wt. Wet (lb/lb-mole), Ms: 29.733 29.702 29.697 Stack Gas Sampled (acf), Vma: 65.979 68.214 68.960 Averages Stack Gas Velocity

(fps), Vs: 110.84 112.50 114.28 113 Volumetric Flowrate (dscfm), Qs: 2,063,053 2,073,538 2,090,480 2,075,691 Volumetric Flowrate (acfm), Qa: 3,264,385 3,313,311 3,365,806 3,314,501 Grainloading (gr/dscf), cs: 0.0203 0.0221 0.0223 0.02 Emission Rate (lb/hour), E: 359.04 392.75 400.26 384.0 Percent Isokinetic Sampling (%), I: 95.75 97.53 97.06 96.78
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 9023.25 9069.10 9143.20 9078.52 Emission Rate (lbs/mmBtu), E: 0.04 0.04 0.04 0.04 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 909 909 909 909 

### Particulate Emission Results Summary

Bowen Unit 3

Page 109 of 121 Att. 5

## ATTACHMENT 6 - Bowen Report 6 Test Results

Performed Dy: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 10/30/2007 10/30/2007 10/30/2007 Run Start Time 10:40 12:50 14:45 Run End Time 11:56 14:05 15:55 Meter Volume (dacf), Vm: 44.606 45.307 45.286 Sqrt Delta P ("wc): 1.54 1.54 1.55 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 29.26 29.26 29.20 Delta H ("wc): 1.5 1.5 1.6 Volume in Impingers (mls), VIc: 58.0 58.2 56.1 Static Pressure ("wc), Pg: -4.20 -4.10 -4.00 Stack Pressure ("Hg), Ps: 28.95 28.96 28.91 Stack Temperature (F), Ts: 304 309 314 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: 89 89 90 Stack Diameter (inches): 300 300 300 Area Stack (sq. ft.), As: 490.87 490.87 490.87 Nozzle Diameter (inches), dp: 0.176 0.176 0.176 Area Nozzle (sq. ft.), An: 0.000169 0.000169 0.000169 Percent CO2 (% dry volume): 13.0 13.0 13.0 Percent O2 (% dry volume): 6.5 6.5 6.5 Percent (N2 + CO) (% dry volume): 80.5 80.5 80.5 Particulate Collected (mg), Mn: 51.9 51.9 57.9

Molec. Wt. Dry

(lb/lb-mole), Md: 30.340 30.340 30.340 Volume Water (scf), Vwstd 2.730 2.739 2.641 Meter Volume (dscf), Vmstd: 41.996 42.604 42.431 Wet Fraction (v/v), Bws: 0.061 0.060 0.059 Molec. Wt. Wet (lb/lb-mole), Ms: 29.587 29.594 29.617 Stack Gas Sampled (acf), Vma: 66.846 68.270 68.352 Averages Stack Gas Velocity

(fps), Vs: 104.57 104.95 105.65 105 Volumetric Flowrate (dscfm), Qs: 1,934,946 1,928,987 1,931,663 1,931,865 Volumetric Flowrate (acfm), Qa: 3,079,920 3,091,053 3,111,715 3,094,229 Grainloading (gr/dscf), cs: 0.0191 0.0188 0.0211 0.02 Emission Rate (lb/hour), E: 316.30 310.83 348.54 325.2 Percent Isokinetic Sampling (%), I: 105.17 107.02 106.44 106.21
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 8178.95 8153.76 8165.07 8165.93 Emission Rate (lbs/mmBtu), E: 0.04 0.04 0.04 0.04 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 932 932 932 932 

### Particulate Emission Results Summary

Bowen Unit 4

Page 110 of 121 Att. 6

## ATTACHMENT 7 - Bowen Report 7 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 3/10/2008 3/10/2008 3/10/2008 Run Start Time 9:55 13:00 16:00 Run End Time 12:15 15:15 18:15 Meter Volume (dacf), Vm: 89.955 68.88 69.619 Sqrt Delta P ("wc): 0.79 0.79 0.80 Sampling Time (min): 120 120 120 Barometric Pressure ("Hg), Pbar: 29.07 29.07 29.07 Delta H ("wc): 1.5 0.9 0.9 Volume in Impingers (mls), VIc: 241.1 188.7 188.5 Static Pressure ("wc), Pg: -1.20 -1.10 -1.30 Stack Pressure ("Hg), Ps: 28.98 28.99 28.97 Stack Temperature (F), Ts: 121 121 121 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: 81 83 85 Stack Diameter (inches): 408 408 408 Area Stack (sq. ft.), As: 907.92 907.92 907.92 Nozzle Diameter (inches), dp: 0.238 0.210 0.210 Area Nozzle (sq. ft.), An: 0.000308 0.000241 0.000241 Percent CO2 (% dry volume): 12.9 13.1 13.0 Percent O2 (% dry volume): 6.2 6.2 6.3 Percent (N2 + CO) (% dry volume): 80.9 80.7 80.7 Particulate Collected (mg), Mn: 96.9 111.6 100.9

Molec. Wt. Dry

(lb/lb-mole), Md: 30.317 30.340 30.332 Volume Water (scf), Vwstd 11.349 8.882 8.873 Meter Volume (dscf), Vmstd: 85.483 65.104 65.546 Wet Fraction (v/v), Bws: 0.117 0.120 0.119 Molec. Wt. Wet (lb/lb-mole), Ms: 28.874 28.859 28.862 Stack Gas Sampled (acf), Vma: 109.906 84.087 84.573 Averages Stack Gas Velocity

(fps), Vs: 47.52 47.57 47.68 48 Volumetric Flowrate (dscfm), Qs: 2,013,484 2,006,344 2,013,161 2,010,996 Volumetric Flowrate (acfm), Qa: 2,588,753 2,591,364 2,597,560 2,592,559 Grainloading (gr/dscf), cs: 0.0175 0.0265 0.0237 0.02 Emission Rate (lb/hour), E: 301.71 455.04 409.70 388.8 Percent Isokinetic Sampling (%), I: 104.48 102.14 102.49 103.03
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 8688.24 8637.80 8627.75 8651.26 Emission Rate (lbs/mmBtu), E: 0.03 0.05 0.05 0.04 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 911 911 912 911 

### Particulate Emission Results Summary Bowen Unit 3 FGD OUTLET

Page 111 of 121 Att. 7

## ATTACHMENT 8 - Bowen Report 8 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 3/13/2008 3/13/2008 3/13/2008 Run Start Time 7:15 9:10 10:50 Run End Time 8:25 10:25 12:00 Meter Volume (dacf), Vm: 35.101 35.34 35.475 Sqrt Delta P ("wc): 0.82 0.83 0.82 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 28.70 28.70 28.72 Delta H ("wc): 0.9 1.0 0.9 Volume in Impingers (mls), VIc: 94.5 95.1 94.3 Static Pressure ("wc), Pg: -0.94 -0.95 -0.98 Stack Pressure ("Hg), Ps: 28.63 28.63 28.65 Stack Temperature (F), Ts: 120 120 120 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 82 86 Stack Diameter (inches): 408 408 408 Area Stack (sq. ft.), As: 907.92 907.92 907.92 Nozzle Diameter (inches), dp: 0.210 0.210 0.210 Area Nozzle (sq. ft.), An: 0.000240 0.000240 0.000240 Percent CO2 (% dry volume): 12.6 12.5 12.5 Percent O2 (% dry volume): 6.3 6.5 6.4 Percent (N2 + CO) (% dry volume): 81.0 81.0 81.0 Particulate Collected (mg), Mn: 174.1 163.7 205.0

Molec. Wt. Dry

(lb/lb-mole), Md: 30.275 30.260 30.263 Volume Water (scf), Vwstd 4.448 4.476 4.439 Meter Volume (dscf), Vmstd: 32.810 33.002 32.933 Wet Fraction (v/v), Bws: 0.119 0.119 0.119 Molec. Wt. Wet (lb/lb-mole), Ms: 28.809 28.796 28.806 Stack Gas Sampled (acf), Vma: 42.777 43.049 42.906 Averages Stack Gas Velocity

(fps), Vs: 49.26 49.89 49.55 50 Volumetric Flowrate (dscfm), Qs: 2,058,349 2,083,356 2,071,731 2,071,145 Volumetric Flowrate (acfm), Qa: 2,683,593 2,717,595 2,699,101 2,700,096 Grainloading (gr/dscf), cs: 0.0819 0.0765 0.0961 0.08 Emission Rate (lb/hour), E: 1444.81 1366.67 1706.01 1505.8 Percent Isokinetic Sampling (%), I: 100.59 99.96 100.31 100.29
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 8801.27 8806.27 8797.68 8801.74 Emission Rate (lbs/mmBtu), E: 0.16 0.16 0.19 0.17 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 911 911 912 911 

### Particulate Emission Results Summary Bowen Unit 3 FGD OUTLET CAM

Page 112 of 121 Att. 8

## ATTACHMENT 9 - Bowen Report 9 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 3/19/2008 3/19/2008 3/19/2008 Run Start Time 10:10 12:40 14:10 Run End Time 11:30 13:50 15:25 Meter Volume (dacf), Vm: 38.254 38.665 38.544 Sqrt Delta P ("wc): 1.45 1.46 1.45 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 28.48 28.40 28.40 Delta H ("wc): 1.3 1.3 1.3 Volume in Impingers (mls), VIc: 52.9 52.4 53.7 Static Pressure ("wc), Pg: -3.30 -3.40 -3.50 Stack Pressure ("Hg), Ps: 28.24 28.15 28.14 Stack Temperature (F), Ts: 305 308 310 Meter Coefficient (no units), Y: 1.014 1.014 1.014 Pitot Coefficient (no units) Cp: 0.840 0.840 0.840 Meter OutletTemperature (F), Tm: 89 90 83 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): 10.8 10.7 10.9 Percent O2 (% dry volume): 8.0 8.0 7.9 Percent (N2 + CO) (% dry volume): 81.2 81.3 81.2 Particulate Collected (mg), Mn: 65.7 63.9 78.4

Molec. Wt. Dry

(lb/lb-mole), Md: 30.047 30.032 30.056 Volume Water (scf), Vwstd 2.490 2.452 2.528 Meter Volume (dscf), Vmstd: 35.606 35.835 35.539 Wet Fraction (v/v), Bws: 0.065 0.064 0.066 Molec. Wt. Wet (lb/lb-mole), Ms: 29.259 29.261 29.255 Stack Gas Sampled (acf), Vma: 58.447 59.161 59.033 Averages Stack Gas Velocity

(fps), Vs: 100.01 101.12 100.97 101 Volumetric Flowrate (dscfm), Qs: 1,794,370 1,803,992 1,790,244 1,796,202 Volumetric Flowrate (acfm), Qa: 2,945,433 2,978,221 2,973,712 2,965,789 Grainloading (gr/dscf), cs: 0.0284 0.0275 0.0341 0.03 Emission Rate (lb/hour), E: 437.56 425.44 522.66 461.9 Percent Isokinetic Sampling (%), I: 98.66 98.76 98.70 98.71
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 6812.22 6831.10 6814.07 6819.13 Emission Rate (lbs/mmBtu), E: 0.06 0.06 0.08 0.07 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 718 726 726 723 

### Particulate Emission Results Summary

Bowen Unit 1

Page 113 of 121 Att. 9

## ATTACHMENT 10 - Bowen Report 10 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 3/19/2008 3/19/2008 3/19/2008 Run Start Time 10:10 12:40 14:10 Run End Time 11:30 13:50 15:25 Meter Volume (dacf), Vm: 40.141 40.87 40.033 Sqrt Delta P ("wc): 1.46 1.48 1.46 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 28.48 28.40 28.40 Delta H ("wc): 1.2 1.2 1.2 Volume in Impingers (mls), VIc: 55.4 56.4 53.6 Static Pressure ("wc), Pg: -3.10 -3.00 -3.20 Stack Pressure ("Hg), Ps: 28.25 28.18 28.16 Stack Temperature (F), Ts: 308 309 307 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: 86 88 92 Stack Diameter (inches): 300 300 300 Area Stack (sq. ft.), As: 490.87 490.87 490.87 Nozzle Diameter (inches), dp: 0.172 0.172 0.172 Area Nozzle (sq. ft.), An: 0.000162 0.000162 0.000162 Percent CO2 (% dry volume): 11.4 11.5 11.4 Percent O2 (% dry volume): 7.3 7.4 7.4 Percent (N2 + CO) (% dry volume): 81.2 81.1 81.2 Particulate Collected (mg), Mn: 75.9 75.9 94.5

Molec. Wt. Dry

(lb/lb-mole), Md: 30.123 30.136 30.116 Volume Water (scf), Vwstd 2.594 2.655 2.523 Meter Volume (dscf), Vmstd: 36.949 37.407 36.394 Wet Fraction (v/v), Bws: 0.066 0.066 0.065 Molec. Wt. Wet (lb/lb-mole), Ms: 29.328 29.332 29.331 Stack Gas Sampled (acf), Vma: 60.880 61.986 60.076 Averages Stack Gas Velocity

(fps), Vs: 100.66 102.48 100.78 101 Volumetric Flowrate (dscfm), Qs: 1,799,367 1,821,446 1,798,168 1,806,327 Volumetric Flowrate (acfm), Qa: 2,964,727 3,018,216 2,968,235 2,983,726 Grainloading (gr/dscf), cs: 0.0317 0.0313 0.0401 0.03 Emission Rate (lb/hour), E: 488.85 488.79 617.51 531.7 Percent Isokinetic Sampling (%), I: 103.88 103.89 102.39 103.39
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 7165.71 7217.99 7108.15 7163.95 Emission Rate (lbs/mmBtu), E: 0.07 0.07 0.09 0.07 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 736 737 736 736 

### Particulate Emission Results Summary

Bowen Unit 2

Page 114 of 121 Att. 10

## ATTACHMENT 11 - Bowen Report 11 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 11/13/2008 11/13/2008 11/13/2008 Run Start Time 10:15 12:35 14:50 Run End Time 11:30 13:50 16:05 Meter Volume (dacf), Vm: 36.007 37.531 37.6 Sqrt Delta P ("wc): 0.83 0.85 0.85 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 29.00 29.00 29.00 Delta H ("wc): 1.0 1.0 1.0 Volume in Impingers (mls), VIc: 103.0 110.2 107.3 Static Pressure ("wc), Pg: -0.80 -0.85 -0.90 Stack Pressure ("Hg), Ps: 28.94 28.94 28.93 Stack Temperature (F), Ts: 120 120 120 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: 80 82 84 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: 0.000256 0.000256 0.000256 Percent CO2 (% dry volume): 11.5 11.4 11.6 Percent O2 (% dry volume): 8.1 8.2 8.1 Percent (N2 + CO) (% dry volume): 80.4 80.4 80.3 Particulate Collected (mg), Mn: 10.9 19.1 13.8

Molec. Wt. Dry

(lb/lb-mole), Md: 30.168 30.147 30.185 Volume Water (scf), Vwstd 4.848 5.187 5.051 Meter Volume (dscf), Vmstd: 34.114 35.429 35.366 Wet Fraction (v/v), Bws: 0.124 0.128 0.125 Molec. Wt. Wet (lb/lb-mole), Ms: 28.654 28.595 28.663 Stack Gas Sampled (acf), Vma: 44.259 46.125 45.904 Averages Stack Gas Velocity

(fps), Vs: 50.14 51.01 50.90 51 Volumetric Flowrate (dscfm), Qs: 2,105,087 2,134,576 2,136,168 2,125,277 Volumetric Flowrate (acfm), Qa: 2,731,152 2,778,965 2,772,658 2,760,925 Grainloading (gr/dscf), cs: 0.0049 0.0083 0.0060 0.01 Emission Rate (lb/hour), E: 89.05 151.83 110.30 117.1 Percent Isokinetic Sampling (%), I: 95.76 98.08 97.84 97.23
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 7930.05 7957.59 8026.23 7971.29 Emission Rate (lbs/mmBtu), E: 0.01 0.02 0.01 0.01 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 910 910 910 910 

### Particulate Emission Results Summary

Bowen Unit 4 FGD

Page 115 of 121 Att. 11

## ATTACHMENT 12 - Bowen Report 12 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida

Run 1 Run 2 Run 3 Test Date 5/29/2009 3/19/2008 3/19/2008 Run Start Time 7:30 9:20 10:50 Run End Time 8:45 10:35 12:05 Meter Volume (dacf), Vm: 37.461 38.179 38.365 Sqrt Delta P ("wc): 0.88 0.88 0.88 Sampling Time (min): 60 60 60 Barometric Pressure ("Hg), Pbar: 28.82 28.82 28.83 Delta H ("wc): 1.2 1.2 1.2 Volume in Impingers (mls), VIc: 106.3 108.8 109.7 Static Pressure ("wc), Pg: -0.71 -0.74 -0.74 Stack Pressure ("Hg), Ps: 28.77 28.77 28.78 Stack Temperature (F), Ts: 122 123 123 Meter Coefficient (no units), Y: 0.996 0.996 0.996 Pitot Coefficient (no units) Cp: 0.840 0.840 0.840 Meter OutletTemperature (F), Tm: 89 93 95 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): 12.1 12.2 12.2 Percent O2 (% dry volume): 6.9 6.8 6.9 Percent (N2 + CO) (% dry volume): 81.0 81.0 80.9 Particulate Collected (mg), Mn: 32.4 24.8 31.5

Molec. Wt. Dry

(lb/lb-mole), Md: 30.217 30.229 30.223 Volume Water (scf), Vwstd 5.004 5.121 5.164 Meter Volume (dscf), Vmstd: 34.661 35.062 35.116 Wet Fraction (v/v), Bws: 0.126 0.127 0.128 Molec. Wt. Wet (lb/lb-mole), Ms: 28.676 28.671 28.656 Stack Gas Sampled (acf), Vma: 45.493 46.163 46.257 Averages Stack Gas Velocity

(fps), Vs: 52.94 53.20 53.21 53 Volumetric Flowrate (dscfm), Qs: 2,197,401 2,201,113 2,200,338 2,199,617 Volumetric Flowrate (acfm), Qa: 2,884,116 2,897,990 2,898,450 2,893,519 Grainloading (gr/dscf), cs: 0.0144 0.0109 0.0138 0.01 Emission Rate (lb/hour), E: 271.75 205.58 260.80 246.0 Percent Isokinetic Sampling (%), I: 95.62 96.57 96.75 96.31
F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780 Heat Input (mmBtu/hour): 9030.33 9110.19 9042.40 9060.97 Emission Rate (lbs/mmBtu), E: 0.03 0.02 0.03 0.03 Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24 Average Unit Gross Load (MW) 755 755 755 755 

### Particulate Emission Results Summary

Bowen Unit 2

Page 116 of 121 Att. 12

## ATTACHMENT 13 - Bowen Report 13 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 Military Military

### MW ppm % Dry % Dry 1b Off AGC 8/23/200712:01 13:04735 8 4.29 14.55 1bc Off AGC - composite test8/23/200713:08 13:18726 9 4.11 11.82

1c Off AGC - Reduced O2 setpoint to 3.3% O2 8/24/2007 7:44 8:47 737 8 4 14.86

1cc Off AGC - Reduced O2 setpoint to 3.3% O2 (Composite Test) 8/24/2007 8:49 8:59 740 10 3.92 14.94

1d Off AGC 8/28/200712:06 13:09736 10 4.39 14.51

Boiler O2 Verification Test Results Summary

Bowen Unit 1

Page 117 of 121 Att. 13

## ATTACHMENT 14 - Bowen Report 14 Test Results

Title of Run Description Date Start Time End Time Test 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 Test 1aBaseline 4/3/2007 7:19 8:22 738 6 4.5 14.39 742 Test 1bReduced O2 (1) 4/3/200711:42 12:45738 6 4.01 14.89 704 Test 1cReduced O2 (2) 4/3/200714:00 15:03738 9 3.63 14.99 700 Test 2aSlag Replication 1 4/4/2007 7:59 9:02 738 13 4.66 14.25 696 Test 2bSlag Replication 2 4/4/200710:17 11:41738 7 4.15 14.72 695 Test 2cSlag Replication 3 4/4/200713:00 14:24726 10 4.56 14.3 699 Test 2dSlag Repication 4 4/4/2007 15:15 16:42 

### 727 5 4.53 14.34 703 Test 3aSCR Min Temp 4/5/2007 4:04 5:07 552 10 4.54 14.38 636 Test 3bLow Load 4/5/2007 6:02 7:05 428 10 4.17 14.75 583 Boiler Diagnostic Test Results Summary

Bowen Unit 2

Page 118 of 121 Att. 14

## ATTACHMENT 15 - Bowen Report 15 Test Results

Title of Run Description Date Start Time End Time Test Load Avg. Econ. Gas Outlet CO Avg.

Econ. Gas Outlet O2Avg. Econ.

Gas Outlet CO2 Avg. Econ. Gas Outlet Temp Military Military

### MW ppm % Dry % Dry Deg F Test 1aDaily Baseline 2/1/2007 7:40 9:04 910 22 3.71 14.66 670 Test 1bBoiler Efficiency 2/1/200712:00 13:24910 28 3.99 14.39 672 Test 2b0.38 NOx vs. LOI 2/1/200717:10 18:04910 62 3.4 14.77 672 Test 2c0.42 Nox vs. LOI 2/1/200714:40 16:04910 60 3.57 14.67 672 Test 3c+5 Tilt vs. Nox 2/1/200720:15 21:39910 47 3.61 14.59 674 Test 4aMid Load 2/7/200714:10 15:34650 7 3.98 14.55 611 Test 5aDaily Baseline 2/6/2007 7:45 9:09 911 17 3.53 14.8 667 Test 5c1Tuning Test 1 2/6/200710:15 11:39912 10 4 14.34 671 Test 5c3Tuning Test 2 2/6/200714:08 14:36911 12 4.07 14.54 676 Test 5c4Tuning Test 3 2/6/200716:10 16:38911 21 3.77 14.76 675 Test 6aDaily Baseline 2/7/2007 7:30 8:54 910 14 3.69 14.77 673 Test 6c1Tuning Test 1 2/7/200710:45 12:08910 24 3.74 14.66 674 Test 7a2Daily Baseline 2/8/2007 9:06 10:30911 8 4.53 13.9 679 Test 7cSofa Dmp Curve 2/8/200715:00 16:24910 7 4.61 13.72 682 Boiler OptimizationTest Results Summary

Bowen Unit 3

Page 119 of 121 Att. 15

## ATTACHMENT 16 - Bowen Report 16 Test Results

Title of Run Description Date Start Time End Time Test 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 Test 3Full Load, O2 Bias -0.18%3/9/2006 8:07 10:06933 124 3.4 15.27 690

Test 4Full Load, O2 Bias -0.18%3/9/200612:04 13:49933 127 3.37 15.21 691

Test 5Full Load, O2 Bias +0.42%3/9/200614:50 16:34933 87 3.9 14.68 698

Title of Run Description Date Start Time End Time Test LoadAvg. AH Gas Outlet COAvg. AH

Gas Outlet O2Avg. AH

Gas Outlet CO2 Avg. AH Gas Outlet Temp Military Military

### MW ppm % Dry % Dry Deg F Test 3Full Load, O2 Bias @ +.42% 3/9/200614:50 933 98 4.66 14.34 297

Test 4Full Load, O2 Bias -0.18%3/9/200612:04 13:49933 133 4.53 14.35 305

Test 5Full Load, O2 Bias @ +.42% 3/9/200614:50 16:34933 72 5.1 13.89 306

Air Preheater Guarantee Test Results Summary

Bowen Unit 4

Page 120 of 121 Att. 16

## ATTACHMENT 17 - Bowen Report 17 Test Results

Bowen Unit 3 Ontario Hydro Method Mercury Testing (ng/m^3)

Stack Date Hg (0) Hg (T) Hg (0) Hg (T) Hg (0) Hg (T) Hg(0)/Hg(T) 5/5/2008 Run #1 

### 240 8260 550 7850 240 360 67% 5/5/2008 Run #2 

### 690 8240 280 8340 310 510 61% 5/6/2008 Run #1 

### 720 9790 410 10490 370 560 

### 66% 5/6/2008 Run #2 

### 270 8760 310 8740 450 3380 

### 13% 5/7/2008 Run #1 

### 790 7800 410 7420 1530 2040 

### 75% 5/7/2008 Run #2 

### 230 8630 240 8980 200 280 

### 71% 5/8/2008 Run #1 

### 580 16450 580 17560 530 3050 17% 5/8/2008 Run #2 

### 320 9970 340 9830 530 3080 17% 5/9/2008 Run #1 

### 370 10340 660 11010 1590 2300 69% 5/9/2008 Run #2 

### 410 8590 500 9360 1240 1880 66% 5/10/2008 Run #1 

### 390 10690 380 11120 960 2290 42% 5/10/2008 Run #2 

### 330 8330 380 8040 860 1420 61% Upstream of FGD ESP (A) Outlet ESP (B) Outlet Stack

Page 121 of 121 Att. 17