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

1 Name of legal owner of facility:

Georgia Power

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

3 Address of _X__ legal owner or ____ operator:

241 Ralph McGill Blvd NE, Bin 10221

Atlanta, GA 30308

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

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

Bowen

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

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

703

5 Complete street address of facility (physical location):

317 Covered Bridge Road

Cartersville, Georgia 30120

6 Provide mailing address if different:

241 Ralph McGill Blvd NE, Bin 10221

Atlanta, GA 30308

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

Sarah Markham, Engineer II

8 Contact(s) telephone number(s):

(205) 257-6780

and e-mail address(es):

sasander@southernco.com

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

____ Yes _X__ No ____ Don't know

Page 1 of 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

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

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

___ other (specify in question 14 below)

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

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

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

_X__ other (specify in question 14 below)

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

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

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

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

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

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

 that recycle materials) (%_____)

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

____ petroleum coke (% _____)

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

_X__ distillate (% _100____)

____ other (specify __________) (% _____)

____ residual or bunker C (% _____)

Page 2 of 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

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

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

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

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

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

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

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

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

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

material? ____ Yes ____ No

Explain:

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

1

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

2

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

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

3

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

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

purposes").

4

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

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

5

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

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

Yes

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

Synfuel Yes None in 2009 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

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

located at this facility.

SEE NOTES BELOW for explanations of responses. Boiler ID

6

coal rank or type of oil)

Original design fuel (i.e., 

Design heat input, 

(MMBtu/hr)

7

Present maximum heat 

input, (MMBtu/hr)

8

MWe Gross capacity

summer

MWe Net Capacity

summer

Original design gross 

efficiency (%, HHV)

Present operating gross 

efficiency (%, HHV)

Design steam pressure 

(psig)

Operating steam pressure 

(psig)

Design steam temperature 

(

oF)

temperature (

Operating steam 

oF)

Design steam reheat 

temperature (

oF)

9

Operating steam reheat 

temperature (

oF)10

Fuel11

Hours/year operated12

Average annual capacity 

factor for the past 3 years

Applicable NSPS

Estimated year of 

retirement13

1 bituminous 

coal

CBI CBI 740 693 89.1 88.9 3500 3500 1000 1000 1000 1000 bituminous coal (100%), distillate 

oil (100%)

CBI CBI Not 

applicable

None 

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 

applicable

None 

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 

applicable

None 

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 

applicable

None 

planned

6

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

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

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

7

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

8

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

9

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

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

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

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

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

NOTES: Original Design Fuel

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

Design Heat Input

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

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

located at this facility.

SEE NOTES BELOW for explanations of responses. Boiler ID

6

coal rank or type of oil)

Original design fuel (i.e., 

Design heat input, 

(MMBtu/hr)

7

Present maximum heat 

input, (MMBtu/hr)

8

MWe Gross capacity

summer

MWe Net Capacity

summer

Original design gross 

efficiency (%, HHV)

Present operating gross 

efficiency (%, HHV)

Design steam pressure 

(psig)

Operating steam pressure 

(psig)

Design steam temperature 

(

oF)

temperature (

Operating steam 

oF)

Design steam reheat 

temperature (

oF)

9

Operating steam reheat 

temperature (

oF)10

Fuel11

Hours/year operated12

Average annual capacity 

factor for the past 3 years

Applicable NSPS

Estimated year of 

retirement13

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

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

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

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

NOTES: SO3/NH3 flue gas conditioning 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

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

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

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

NOTES: SO3/NH3 flue gas conditioning 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)

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

Page 7 of 121 part I, 16
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

etc.).

Name Telephone Address

1 Not applicable Not applicable Not applicable Not applicable

2 Not applicable Not applicable Not applicable Not applicable

3 Not applicable Not applicable Not applicable Not applicable

4 Not applicable Not applicable Not applicable Not applicable

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

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

demonstrate the technology's HAP removal performance.

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

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

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

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

Page 8 of 121 part I, 17
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

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

Boiler ID22

Demonstration 

activity actual startup date

Demonstration 

activity projected 

start-up date

Demonstration 

activity end-date or 

projected end-date

Type of control (e.g., 

sorbent and type; 

chemical additive23)

Desired HAP 

emission reduction 

(%) or emission rate

Coal rank(s) in use

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

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

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

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

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

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

23 If additive is used, please indicate injection point.

Page 9 of 121 part I, 18
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

Name Telephone Address

1 Not applicable Not applicable Not applicable Not applicable

2 Not applicable Not applicable Not applicable Not applicable

3 Not applicable Not applicable Not applicable Not applicable

4 Not applicable Not applicable Not applicable Not applicable

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

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

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

Company (vendor) contact information

Boiler ID24 Company (vendor) name

Page 10 of 121 part I, 19
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

"inlet" and "outlet" are).

Boiler 

ID25 Actual start-up date Expected or projected 

start-up date

Type of control (e.g., 

sorbent and type; 

chemical additive)26

Guaranteed HAP 

emission reduction 

(%) or emission rate

Sorbent or additive 

feed rate on which 

guarantee is based

Coal rank(s) upon 

which guarantee is 

based

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

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

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

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

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

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

26 If additive is used, please indicate injection point.

Page 11 of 121 part I, 20
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

PM28 PM10

(29) PM2.5(30) SO2

HCl 

and/or HF HCN

Metal 

HAP31 Hg CO

Other 

organics 

(specify)

Other pollutant (specify)

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

stack test using Method 5 or 17; test required 

once every permit cycle on scrubber stack, once 

every 5 years or operating 8760 hours, 

whichever first, on bypass stack)

Not 

applicable

Not 

applicable

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

analysis of coal sample acquired for each 

operating day and supplier certification 

statement for No. 2 oil)

5% of potential combustion concentration (95% 

removal by FGD), effective Jan 1, 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 

applicable

NOx: 0.07 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

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 

applicable

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

analysis of coal sample acquired for each 

operating day and supplier certification 

statement for No. 2 oil)

5% of potential combustion concentration (95% 

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

rule, Title V permit revision not complete; based 

on 30-day rolling average, monitored by CEMS 

at inlet to scrubber and at scrubber stack during 

scrubber operations, excluding startup, 

shutdown, malfunction, and other exemptions)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

NOx: 0.07 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

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 

applicable

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

analysis of coal sample acquired for each 

operating day and supplier certification 

statement for No. 2 oil)

5% of potential combustion concentration (95% 

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

rule, Title V permit revision not complete; based 

on 30-day rolling average, monitored by CEMS 

at inlet to scrubber and at scrubber stack during 

scrubber operations, excluding startup, 

shutdown, malfunction, and other exemptions)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

NOx: 0.07 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

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

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

PM28 PM10

(29) PM2.5(30) SO2

HCl 

and/or HF HCN

Metal 

HAP31 Hg CO

Other 

organics 

(specify)

Other pollutant (specify)

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 

applicable

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

analysis of coal sample acquired for each 

operating day and supplier certification 

statement for No. 2 oil)

5% of potential combustion concentration (95% 

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

rule, Title V permit revision not complete; based 

on 30-day rolling average, monitored by CEMS 

at inlet to scrubber and at scrubber stack during 

scrubber operations, excluding startup, 

shutdown, malfunction, and other exemptions)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

NOx: 0.07 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

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

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

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

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

Scrubbers (FGD): Values shown for the 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 

applicable

Not 

applicable

FGD: 98% instantaneous removal efficiency to 

meet a 95% 30-day rolling average removal 

efficiency (SEE NOTES)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Low NOx Burners: 0.45 lb/MMBtu (expired in 

1994)

2 ESP rebuild: 98.7 % collection efficiency 

filterable (expired in 1998)

Not 

applicable

Not 

applicable

FGD: 98% instantaneous removal efficiency to 

meet a 95% 30-day rolling average removal 

efficiency (SEE NOTES)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Low NOx Burners: 0.45 lb/MMBtu (expired in 

1992)

3 ESP rebuild: 99.0 % collection efficiency 

filterable (expired in 1993)

Not 

applicable

Not 

applicable

FGD: 98% instantaneous removal efficiency to 

meet a 95% 30-day rolling average removal 

efficiency (SEE NOTES)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Low NOx Burners: 0.45 lb/MMBtu (expired in 

1993)

4 ESP rebuild: 99.0 % collection efficiency 

filterable (expired in 1998)

Not 

applicable

Not 

applicable

FGD: 98% instantaneous removal efficiency to 

meet a 95% 30-day rolling average removal 

efficiency (SEE NOTES)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Low NOx Burners: 0.45 lb/MMBtu (expired in 

1993)

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

Please elaborate.

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

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

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

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

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

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

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

Boiler ID32

Page 14 of 121 part I, 22-23
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

PM36 PM10 PM2.5 SO2

HCl 

and/or HF HCN

Metal 

HAP37 Hg CO

Other 

organics 

(specify)

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

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

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

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

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

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

quarterly.

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

within 60 days of completion of the testing.

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

Not 

applicable

Not 

applicable

Coal sulfur content monitored through daily coal sampling; 

fuel oil sulfur content monitored through vendor 

certification; exceedances of 3% limit reported quarterly; 

records retained for 5 years.

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 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

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

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

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

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

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

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

quarterly.

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

within 60 days of completion of the testing.

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

Not 

applicable

Not 

applicable

Coal sulfur content monitored through daily coal sampling; 

fuel oil sulfur content monitored through vendor 

certification; exceedances of 3% limit reported quarterly; 

records retained for 5 years.

SO2 removal by the scrubber will be monitored by inlet and 

stack SO2 CEMS operated, maintained, and certified using 40 

CFR Part 75 procedures. Data from these monitors will 

provide the SO2 removal percentage on a 30-day rolling 

average, excluding startup, shutdown, and malfunction. 

Exceedances of the 5% limit will be reported quarterly; 

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

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

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 

applicable

Not 

applicable

Coal sulfur content monitored through daily coal sampling; 

fuel oil sulfur content monitored through vendor 

certification; exceedances of 3% limit reported quarterly; 

records retained for 5 years.

SO2 removal by the scrubber will be monitored by inlet and 

stack SO2 CEMS operated, maintained, and certified using 40 

CFR Part 75 procedures. Data from these monitors will 

provide the SO2 removal percentage on a 30-day rolling 

average, excluding startup, shutdown, and malfunction. 

Exceedances of the 5% limit will be reported quarterly; 

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

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

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

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

PM36 PM10 PM2.5 SO2

HCl 

and/or HF HCN

Metal 

HAP37 Hg CO

Other 

organics 

(specify)

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 

applicable

Not 

applicable

Coal sulfur content monitored through daily coal sampling; 

fuel oil sulfur content monitored through vendor 

certification; exceedances of 3% limit reported quarterly; 

records retained for 5 years.

SO2 removal by the scrubber will be monitored by inlet and 

stack SO2 CEMS operated, maintained, and certified using 40 

CFR Part 75 procedures. Data from these monitors will 

provide the SO2 removal percentage on a 30-day rolling 

average, excluding startup, shutdown, and malfunction. 

Exceedances of the 5% limit will be reported quarterly; 

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

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

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

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

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

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

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

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

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

Page 16 of 121 part I, 24
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

Facility Name/Unit No.: Not applicable

Retrofit to existing boiler? Not applicable

Installation on a new boiler? Not applicable

Total Capital Investment: $ -

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

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

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

No.

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

Page 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

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

Bowen

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

703

39 The 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

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

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

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

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

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

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

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

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 HARLAN TRAIN 1.32 11.87 12,916

9,893 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.7 11.78 13,125

10,219 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.2 12.24 13,096

10,101 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.2 9.67 13,524

10,118 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.07 7.95 13,706

9,913 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 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

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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 #3 TRAIN 1.33 7.86 13,891

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

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

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

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

8,673 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3 TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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 #3 TRAIN 0.93 11.74 13,299

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

10,618 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3 TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

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

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

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

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

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

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

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

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

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

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

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

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

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

10,220 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3 TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

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

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

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

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

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

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

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

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

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

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

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

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

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

10,369 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3 TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

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

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

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

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

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

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

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

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

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

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

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

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

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

10,431 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3 TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

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

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

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

10,039 1, 2, 3, 4 KY PIKE ELKHORN #2, ELKHORN #3 TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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 HARLAN TRAIN 1.46 11.69 13,227

9,997 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.26 11.53 12,953

10,305 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.3 11.54 13,119

10,039 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.35 11.13 13,243

10,121 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.33 13.44 12,840

10,537 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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 HARLAN TRAIN 1.16 11.07 13,292

10,182 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.21 12.59 12,919

10,123 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.23 12.12 13,016

9,624 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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 HARLAN TRAIN 1.18 12.19 13,048

10,122 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.11 12.06 13,088

9,029 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.14 12.19 13,098

10,324 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.12 11.04 13,332

10,042 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.17 12.13 13,040

9,961 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.17 13.63 12,812

10,423 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.13 11.43 13,260

10,142 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.18 11.38 13,184

10,696 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.26 11.85 13,122

10,399 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.19 11.52 13,168

12,116 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.16 11.44 13,259

10,792 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.31 11.82 13,137

10,396 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.12 11.18 13,213

10,547 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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 HARLAN TRAIN 1.34 12.99 12,930

12,144 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.24 12.38 13,021

10,746 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.29 12.17 13,079

10,705 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.4 13.68 12,857

12,215 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.44 12.84 12,974

12,106 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.27 12.19 12,944

12,115 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.25 11.34 13,176

12,107 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.12 8.18 13,712

12,191 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.21 12.1 13,030

12,119 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.35 12.4 13,079

12,155 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.35 11.67 13,224

12,270 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.31 10.41 13,365

12,080 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.16 11.7 13,161

12,336 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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 HARLAN TRAIN 1.25 11.28 13,277

12,188 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.28 12.73 13,101

12,304 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.24 11.3 13,354

12,222 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.16 10.73 13,410

12,346 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.26 9.88 13,471

12,226 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.43 10.34 13,400

11,761 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.34 10.83 13,286

12,233 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.35 11.12 13,299

12,245 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.28 10.83 13,325

12,175 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.44 9.86 13,437

10,807 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.36 8.96 13,631

12,250 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.49 9.79 13,468

10,684 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.39 8.97 13,582

12,225 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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 HARLAN TRAIN 1.44 9.84 13,426

12,034 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.57 8.52 13,651

11,861 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.49 10.01 13,393

12,123 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.47 8.95 13,579

12,060 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.41 9.47 13,500

11,932 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.2 8.33 13,663

12,037 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.43 11.83 13,076

11,915 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.34 10.27 13,344

10,163 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.51 10.56 13,448

11,639 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.64 10.37 13,356

11,688 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.4 10.07 13,358

11,854 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 1.48 9.6 13,464

11,889 1, 2, 3, 4 KY HARLAN

CREECH, DARBY, LOWER 

HARLAN, UPPER HARLAN TRAIN 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

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

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

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

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

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

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

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

Vendor Analyses

Amount received, dry Fuel source

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

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

amount fired.

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

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

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

42 If known.

43 If known.

Page 75 of 121 part II, 2 (coal)
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

State/Country County42 Coal seam43

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

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

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

State/Country County42 Coal seam43

FUEL OIL SHIPMENTS

Amount received, 

gallons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

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

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

amount fired.

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

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

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

42 If known.

43 If known.

Page 77 of 121 part II, 2 (oil)
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

09-502 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 2.4 KY 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 3.3 WV 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 3.7 KY Magoffin, Floyd

Fireclay, 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 2.0 KY 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 3.8 KY Perry, Breathitt

Hazard #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 2.8 KY Perry, Letcher

Hazard 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 2.2 KY 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 2.3 KY 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 3.6 KY 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 2.8 KY 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

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

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 6.6 KY 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 3.2 KY 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 2.9 KY 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 4.9 KY Perry, Breathitt

Hazard 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 3.4 KY 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 5.4 WV 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 3.8 KY 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 3.5 KY 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 2.1 KY 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 2.2 KY 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 2.3 kY Perry, Letcher

Hazard 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 3.6 KY 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

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

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 3.3 KY 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 3.2 KY 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 2.4 KY 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 2.7 KY 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 3.7 KY 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 2.8 KY 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 3.5 KY 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 2.3 KY 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 5.2 KY

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

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

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 3.7 KY 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 2.7 WV 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 3.4 KY 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 3.5 KY Magoffin, Floyd

Fireclay, 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 4.6 WV 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 2.6 KY 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 4.4 WV

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 2.3 KY 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 3.4 KY 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 5.2 WV 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 3.2 WV 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 5.1 KY

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 3.7 KY Magoffin, Floyd

Fireclay, 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

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

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 3.7 KY 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 2.5 KY 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 3.4 KY 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 2.3 KY 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 2.3 KY 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 2.1 KY 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 3.3 KY 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 3.9 KY 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 2.4 KY 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

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

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 3.0 KY 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 3.6 KY

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 2.8 KY 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 4.0 WV 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 3.3 KY 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 4.0 KY 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 3.4 KY 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 2.5 KY 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 4.0 KY 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 2.5 KY Perry, Letcher

Hazard 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 3.4 WV 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

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

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 1.9 KY 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 2.8 KY 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 2.8 KY 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 2.3 KY 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 3.9 KY Magoffin, Perry

Fireclay, 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 3.1 KY 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 2.3 KY 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 3.5 KY 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 4.0 KY 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

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

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

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

__X__ permit requirements (for coal)

____ contractual obligations

____ standard operational procedures

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

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

____ Fuel supplier (name and address)

__X__ Other (name and address)

Georgia Power Environmental Lab

5131 Maner Road, Smyrna GA 30080

6 Name and address of laboratory performing analyses:

Georgia Power Environmental Lab (same as above)

Page 94 of 121 part II, 4-6
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

these data.

Total 

Moisture Volatiles Ash Fixed 

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

09-502 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 52.3 0.547 0.817 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 1.11 0.844 ND ND 2.3 54.4 0.274 0.587 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 48.4 0.494 0.938 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 52.5 0.214 0.524 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 52.8 0.512 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 51.4 0.474 0.889 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 50.4 0.449 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 8.57 0.996 1.03 ND ND 3.1 51.8 0.229 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 1.59 0.955 ND ND 2.68 53.7 0.422 0.878 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 1.8 0.862 ND 0.485 2.26 51.4 0.414 0.956 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 1.25 0.785 ND ND 2.23 56 0.37 0.633 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 3.07 0.895 ND 1.68 ND 44.6 0.203 0.636 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 1.14 0.588 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 43.8 0.545 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 3.38 0.646 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 50.7 0.457 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 1.06 0.872 ND ND 2.22 56.9 0.236 0.427 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 20.7 28.94 7.36 1.28 0.98 0.032 0.28 2.68 55.02 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 53.9 0.478 0.974 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 1.34 0.819 ND ND 1.93 49.7 0.564 0.835 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 1.48 0.916 ND ND 2.08 50.5 0.216 0.803 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 2.47 0.919 ND 0.685 1.99 47.3 0.628 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 1.23 0.903 ND ND 2.11 54 0.391 0.639 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 49.3 0.532 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 0.29 0.809 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 1.49 0.949 ND 0.418 2.07 51.6 0.303 0.784 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 48.3 0.206 0.682 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 53.8 0.494 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 1.19 0.621 ND 0.471 1.72 55.4 0.177 0.432 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 1.74 0.972 ND 0.544 2.65 57 0.248 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 57.4 0.326 0.628 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 47.5 0.559 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 1.33 0.739 ND ND 2.14 55.3 0.249 0.806 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 3.48 0.683 0.933 ND ND 2.8 62 0.273 ND 1.42

Sample 

ID #

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

Page 95 of 121 part II, 7
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

these data.

Total 

Moisture Volatiles Ash Fixed 

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

Sample 

ID #

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

09-522 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 49.1 0.469 0.908 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 0.82 0.625 ND ND 2.31 58.1 0.214 0.624 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 1.62 0.962 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 49 0.585 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 0.86 0.859 ND ND 2.39 57.2 0.29 0.409 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 53.2 0.341 0.833 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 9.1 26.38 3.61 1.04 0.61 0.017 0.38 1.84 62.66 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 1.12 0.913 ND ND 2.36 53.9 0.256 0.935 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 1.24 0.773 ND ND 1.99 55.4 0.211 0.884 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 1.56 0.979 ND ND 2.37 54 0.453 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 1.57 0.987 ND 0.489 2.37 55.3 0.302 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 52.4 0.599 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 49.2 0.462 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 1.26 0.875 ND ND 2.17 54 0.418 0.979 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 10.2 0.967 0.749 ND ND 1.74 56 0.222 0.717 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 0.2 0.692 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 1.27 0.791 ND ND 1.98 52.8 0.469 0.888 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 2.27 0.929 ND ND 2.08 50.8 0.564 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 1.17 0.531 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 44.5 0.314 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 4.04 0.811 0.596 ND ND 1.55 54 0.183 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 1.22 0.825 ND ND 1.77 54.7 0.347 0.911 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 1.4 0.986 ND 0.768 2.54 49.7 0.197 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 53.4 0.346 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 44.3 0.431 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 1 0.763 ND ND 1.97 53.7 0.229 0.528 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 1.54 0.916 ND ND 2.23 54.7 0.532 0.795 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 49.3 0.338 0.717 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 1.73 0.902 ND ND 2.2 57.8 0.553 0.979 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 1.92 0.922 ND ND 2.28 55.1 0.463 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 46.9 0.308 0.971 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 52.1 0.466 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 0.28 0.593 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 56.4 0.286 0.907 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 53.8 0.508 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 2.32 0.798 ND 0.435 1.81 53.3 0.576 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 1.02 0.753 ND ND 1.88 52.4 0.205 0.466 1.5

Page 96 of 121 part II, 7
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

8a What emission test report(s), parametric monitoring data, and other data or monitoring are available for the boilers noted in Part I,

question 15, for tests conducted since January 1, 2005. Please consider reports prepared for all testing and monitoring programs, for

all pollutants, including (but not limited to) those required under Title V, compliance with State or local requirements, fulfillment of

contractual obligations, U.S. Department of Energy (DOE) programs, etc. (NOTE: EPA is not requesting copies of the test reports or data

at this time; however we may request actual copies in the future.) Use additional pages as necessary.

Report 1 Unit 1 Particulate Emissions Test (February 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 10 Unit 2 Particulate Emissions Test (March 19, 2008)

Report 11 Unit 4 Particulate Emissions Test, FGD Stack (November 13, 2008)

Report 12 Unit 2 Particulate Emissions Test, FGD Stack (May 29, 2009)

Report 13 Unit 1 Boiler O2 Verification (August 23, 2007 to August 28, 2007)

Report 14 Unit 2 Boiler Diagnostic (April 3, 2007 to April 5, 2007)

Report 15 Unit 3 Boiler Optimization (February 1, 2007 to February 8, 2007)

Report 16 Unit 4 Air Preheater Guarantee (March 9, 2006)

Report 17 Unit 3 Scrubber Mercury testing (May 5, 2008 to May 10, 2008)

Report 18 Unit 3 SO3 testing (May 2008)

Report 19 Unit 4 SO3 testing (November - December 2009)

Report 20 Unit 2 Lime Injection into ESP (September 2005)

Report 21 Unit 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

8b Please indicate the date(s) and types (e.g., stack, fuel, parametric, etc.) of the test(s) and the constituents (including criteria and hazardous

air pollutants) sampled for:

Report 1 Date: 2/16/2006 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

8c Do any of these test reports reflect testing at a location upstream of any emission control devices?

Yes _X___ No ____ If yes, please note which reports and provide a detailed description of the location of the emissions sampling point(s).

Although 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

8d Were any of these test reports conducted when use of other material(s) or non-fossil fuels were fired in the boiler?

Yes ____ No _X___ If yes, please not which reports and identify the other material(s) or non-fossil fuels used.

8e Do any of these test reports reflect testing during periods of startup, shutdown, and malfunction?

Yes ____ No _X___ If yes, please note which reports.

8f Did the unit's control configuration differ from that shown in Part I, question 16, at the time of these test results?

Yes _X___ No ____ If yes, please list the unit's complete control configuration at time of testing in a similar format to Part I, question 16.

The control configuration shown below is representative of the conditions present during Reports 1, 2, 3, 4, 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

8g Do any of these test reports reflect testing at a location before a post combustion SO2 emission control device (e.g., FGD, SDA, Dry Scrubber)?

Yes _X___ No ____ If yes, please note which reports and, in addition to the detailed description of the location of the sampling point(s)

(question 8c above), include detail about how much, if any, bypass of unscrubbed flue gas was utilized at at the time of testing (including

percentage of total scrubber flue gas flow). Note by diagram where sampling ports were located in relation to the bypass ductwork.

Reports 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

9 What type of deviation reporting is required for violations of permit requirements?

Specified deviations are reported quarterly. Emissions exceeding a standard for 

a period of 4 hours or more are reported within 7 days. 

Other deviations are reported semiannually.

Note: Not all reported deviations are considered violations of permit requirements

10 Are deviation reports available for malfunctions or other periods of noncompliance with permit terms and conditions?

Yes _X__ No ____ If yes, please note which reports.

Deviation reports including periods of 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

11 Are continuous emissions monitoring system (CEMS) data available (e.g., mercury, continuous opacity monitoring systems) that are not

already being provided to the U.S. EPA, even if from short-term testing?

Yes _X__ No ____ If yes46, please note for which pollutants CEMS data are available and the period of time (both total period and calendar

period) for which the data are available. If CEM data are being provided to EPA, please note to which Office the data are being provided.

Mercury CEMS data are available for the following periods of time:

Unit 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.

46 Where units are monitored by CEMs (either following CAMR, State, or NIST QA/QC procedures), and where data are available, EPA requests

that this CEM data by submitted by the respondent. The respondent should also mark the periods of start up, shut down and malfunction events (SSM) 

in the data sets.

Page 102 of 121 part II, 9-11
GEORGIA POWER - PLANT BOWEN

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

NOTE: Net generation data not available in test reports. Other parameters may or may not be available depending on the test report.

Date of test PM49 SO2 HCl/HF/HCN Metal HAP50 Hg51 CO

Other organics 

(specify)

1 2/16/2006 See Attachment 1 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

2 2/16/2006 See Attachment 2 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

3 2/15/2006 See Attachment 3 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

4 2/15/2006 See Attachment 4 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

3 10/30/2007 See Attachment 5 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

4 10/30/2007 See Attachment 6 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

3 3/10/2008 See Attachment 7 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

3 3/13/2008 See Attachment 8 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

1 3/19/2008 See Attachment 9 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

2 3/19/2008 See Attachment 10 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

4 11/13/2008 See Attachment 11 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

2 5/29/2009 See Attachment 12 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

1 8/23/2007-8/28/2007 Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 13 Not applicable

2 4/3/2007-4/5/2007 Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 14 Not applicable

3 2/1/2007-2/8/2007 Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 15 Not applicable

4 3/9/2006 Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 16 Not applicable

3 5/5/2008-5/10/2008 Not applicable Not applicable Not applicable Not applicable See Attachment 17 Not applicable Not applicable

47 Provide emission test data for all tests conducted since January 1, 2005. Please indicate test data acquired both before and after

any control device. Use additional pages as necessary. EPA may, at some future date, request a copy of one or more emission test reports.

Data generated to fulfill both Federal and State requirements must be provided. Note that data generated pursuant to CAA Title V

must be maintained and available for 5 years. Also include averaging times and measurement units for all pollutants.

48 For each emissions test run the respondent should provide the following process information: Unit Load (MW), Net generation during run (MWh net),

Flue gas moisture content (%), Flue gas flow rate (dscfm or Nm3/hr), Flue gas oxygen content (%, dry), Flue gas carbon dioxide content (%, dry), Flue gas

temperature at sampling point (oF), Flue gas pressure at sampling point (atm), Standard temperature (oF), Standard pressure (atm).

49 If emission testing recorded the emissions of filterable and condensable PM, separately, please include those separate emission results. 

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

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

NOTE: Net generation data not available in test reports. Other parameters may or may not be available depending on the test report.

Date of test PM49 SO2 HCl/HF/HCN Metal HAP50 Hg51 CO

Other organics 

(specify)

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.

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

indicate emission level for all metal HAP for which an emission test has been conducted.

51 Please provide separate results for total Hg, elemental Hg, oxidized Hg, and particulate Hg, as available. If the emissions testing recorded

the amount of unburned carbon in fly ash (as reflected by the "Loss of Ignition" [L.O.I]) at the time of any Hg testing, please include these data.

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 8/23/2007 12:01 13:04 735 8 4.29 14.55

1bc Off AGC - composite test 8/23/2007 13:08 13:18 726 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 8/28/2007 12:06 13:09 736 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 1a Baseline 4/3/2007 7:19 8:22 738 6 4.5 14.39 742

Test 1b Reduced O2 (1) 4/3/2007 11:42 12:45 738 6 4.01 14.89 704

Test 1c Reduced O2 (2) 4/3/2007 14:00 15:03 738 9 3.63 14.99 700

Test 2a Slag Replication 1 4/4/2007 7:59 9:02 738 13 4.66 14.25 696

Test 2b Slag Replication 2 4/4/2007 10:17 11:41 738 7 4.15 14.72 695

Test 2c Slag Replication 3 4/4/2007 13:00 14:24 726 10 4.56 14.3 699

Test 2d Slag Repication 4 4/4/2007 15:15 16:42 727 5 4.53 14.34 703

Test 3a SCR Min Temp 4/5/2007 4:04 5:07 552 10 4.54 14.38 636

Test 3b Low 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 O2 

Avg. Econ. 

Gas 

Outlet 

CO2

Avg. Econ. 

Gas Outlet 

Temp

Military Military MW ppm % Dry % Dry Deg F

Test 1a Daily Baseline 2/1/2007 7:40 9:04 910 22 3.71 14.66 670

Test 1b Boiler Efficiency 2/1/2007 12:00 13:24 910 28 3.99 14.39 672

Test 2b 0.38 NOx vs. LOI 2/1/2007 17:10 18:04 910 62 3.4 14.77 672

Test 2c 0.42 Nox vs. LOI 2/1/2007 14:40 16:04 910 60 3.57 14.67 672

Test 3c +5 Tilt vs. Nox 2/1/2007 20:15 21:39 910 47 3.61 14.59 674

Test 4a Mid Load 2/7/2007 14:10 15:34 650 7 3.98 14.55 611

Test 5a Daily Baseline 2/6/2007 7:45 9:09 911 17 3.53 14.8 667

Test 5c1 Tuning Test 1 2/6/2007 10:15 11:39 912 10 4 14.34 671

Test 5c3 Tuning Test 2 2/6/2007 14:08 14:36 911 12 4.07 14.54 676

Test 5c4 Tuning Test 3 2/6/2007 16:10 16:38 911 21 3.77 14.76 675

Test 6a Daily Baseline 2/7/2007 7:30 8:54 910 14 3.69 14.77 673

Test 6c1 Tuning Test 1 2/7/2007 10:45 12:08 910 24 3.74 14.66 674

Test 7a2 Daily Baseline 2/8/2007 9:06 10:30 911 8 4.53 13.9 679

Test 7c Sofa Dmp Curve 2/8/2007 15:00 16:24 910 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 3 Full Load, O2 Bias -0.18% 3/9/2006 8:07 10:06 933 124 3.4 15.27 690

Test 4 Full Load, O2 Bias -0.18% 3/9/2006 12:04 13:49 933 127 3.37 15.21 691

Test 5 Full Load, O2 Bias +0.42% 3/9/2006 14:50 16:34 933 87 3.9 14.68 698

Title of 

Run

Description Date

Start 

Time

End 

Time

Test 

Load

Avg. AH 

Gas 

Outlet CO 

Avg. AH 

Gas 

Outlet O2 

Avg. AH 

Gas 

Outlet 

CO2

Avg. AH 

Gas Outlet 

Temp

Military Military MW ppm % Dry % Dry Deg F

Test 3 Full Load, O2 Bias @ 

+.42%

3/9/2006 14:50 933 98 4.66 14.34 297

Test 4 Full Load, O2 Bias -0.18% 3/9/2006 12:04 13:49 933 133 4.53 14.35 305

Test 5 Full Load, O2 Bias @ 

+.42%

3/9/2006 14:50 16:34 933 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