GEORGIA POWER - Submittal for PLANT YATES

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):

Yates

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):

728

5 Complete street address of facility (physical location):

708 Dyer Road

Newnan, Georgia 30263

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 86 part I, 1-14
GEORGIA POWER - Submittal for PLANT YATES

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

April 5, 2010

PART I: GENERAL FACILITY INFORMATION

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

_X__ coal __X__ oil (including pet coke) _X__ 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) _X__ 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 86 part I, 1-14
GEORGIA POWER - Submittal for PLANT YATES

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

April 5, 2010

PART I: GENERAL FACILITY INFORMATION

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

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

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

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

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

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

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

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

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

material? ____ Yes ____ No

Explain:

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

1

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

2

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

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

3

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

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

purposes").

4

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

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

5

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

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

Other Material Permitted to burn

Sawdust

Biomass

Yes

Yes

Quantity/year

None in 2009

None in 2009

Actually burn

None in 2009

None in 2009

Yes None in 2009

None in 2009

Synfuel None in 2009

Used Oil Yes None in 2009

Page 3 of 86 part I, 1-14
GEORGIA POWER - PLANT YATES

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

Y1BR bituminous CBI CBI 107 97 88.5 Not 

available

1250 1250 950 950 Not 

applicable

Not 

applicable

bituminous coal (100%), distillate 

oil (100%), natural gas

CBI CBI Not 

applicable

None 

planned

Y2BR bituminous CBI CBI 105 98 88.5 Not 

available

1250 1250 950 950 Not 

applicable

Not 

applicable

bituminous coal (100%), distillate 

oil (100%), natural gas

CBI CBI Not 

applicable

None 

planned

Y3BR bituminous CBI CBI 105 98 88.5 Not 

available

1250 1251 950 948 Not 

applicable

Not 

applicable

bituminous coal (100%), distillate 

oil (100%), natural gas

CBI CBI Not 

applicable

None 

planned

Y4BR bituminous CBI CBI 138 129 88.25 88.4 1800 1813 1000 996 1000 984 bituminous coal (100%), distillate 

oil (100%), natural gas

CBI CBI Not 

applicable

None 

planned

Y5BR bituminous CBI CBI 145 135 88.25 89.3 1800 1809 1000 991 1000 1000 bituminous coal (100%), distillate 

oil (100%), natural gas

CBI CBI Not 

applicable

None 

planned

Y6BR bituminous CBI CBI 363 347 89.06 88.97 2400 2349 1000 971 1000 998 bituminous coal (100%), distillate 

oil (100%), natural gas

CBI CBI Not 

applicable

None 

planned

Y7BR bituminous CBI CBI 361 345 89.06 88.9 2400 2361 1000 980 1000 965 bituminous coal (100%), distillate 

oil (100%), natural gas

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.

Page 4 of 86 part I, 15
GEORGIA POWER - PLANT YATES

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

NOTES: Original Design Fuel

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

Design Heat Input

Confidential Business Information

Present Maximum Heat Input

Confidential Business Information

MWe Gross Capacity Summer

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

MWe Net Capacity Summer

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

Original Design Gross Efficiency

Taken directly from the original contract boiler data sheet.

Present Operating Gross Efficiency 

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

Design Steam Pressure

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

Operating Steam Pressure

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

Design Steam Temperature

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

Operating Steam Temperature 

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

Design Steam Reheat Temperature 

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

Operating Steam Reheat Temperature

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

Fuel

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

Hours/Year Operated

Confidential Business Information

Page 5 of 86 part I, 15
GEORGIA POWER - PLANT YATES

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

Annual Average Capacity Factor for the Past 3 Years

Confidential Business Information

Applicable NSPS

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

Retirement Year

Georgia Power has not committed to actual retirement dates for Plant Yates Units 1-7. 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 6 of 86 part I, 15
GEORGIA POWER - PLANT YATES

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/will be operated on an as-needed basis.

Dates for future planned controls listed are subject to change.

Boiler ID14 Type15 NOx control16 SO2 control17 PM control18 Other control19

Y1BR tangential-fired (1) low NOx burners (2005) (4) wet flue gas 

desulfurization (FGD) 

(10/1992), calcium based

(2) cold-side electrostatic 

precipitator (ESP) (5/1971)

Not applicable

Y2BR tangential-fired Not applicable Not applicable (3) cold-side electrostatic 

precipitator (ESP) (5/1968)

(2) flue gas conditioning - SO3 

injection (1994)

(1) flue gas conditioning - 

ammonia (SO3 control, 1996)

Y3BR tangential-fired Not applicable Not applicable (3) cold-side electrostatic 

precipitator (ESP) (2/1969)

(2) flue gas conditioning - SO3 

injection (1994)

(1) flue gas conditioning - 

ammonia (SO3 control, 1996)

Y4BR tangential-fired (1) flame attachment nozzle 

(low-NOX burner tip design) 

and close-coupled overfire air 

(5/1995)

Not applicable (4) cold-side electrostatic 

precipitator (ESP) (3/1/1970)

(3) flue gas conditioning - SO3 

injection (1994)

(2) flue gas conditioning - 

ammonia (SO3 control, 1996)

Y5BR tangential-fired (1) flame attachment nozzle 

(low-NOX burner tip design) 

and close-coupled overfire air 

(4/1994)

Not applicable (4) cold-side electrostatic 

precipitator (ESP) (2/27/1968)

(3) flue gas conditioning - SO3 

injection (1994)

(2) flue gas conditioning - 

ammonia (SO3 control, 1995)

Page 7 of 86 part I, 16
GEORGIA POWER - PLANT YATES

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/will be operated on an as-needed basis.

Dates for future planned controls listed are subject to change.

Boiler ID14 Type15 NOx control16 SO2 control17 PM control18 Other control19

Y6BR tangential-fired (1) low-NOX concentric firing 

system + separated overfire 

air (11/1992) 

(2) SCR (6/1/2015), catalyst 

not yet purchased

(7) wet flue gas 

desulfurization (FGD) 

(6/1/2015), calcium based

(5) cold-side electrostatic 

precipitator (ESP) (7/23/1974, 

original install)

(5) hydrated lime injection 

(SO3 control, 6/1/2015)

Y7BR tangential-fired (1) flame attachment nozzle 

(low-NOX burner tip design) 

and separated overfire air 

(3/1994)

(2) SCR (6/1/2015), catalyst 

not yet purchased

(7) wet flue gas 

desulfurization (FGD) 

(6/1/2015), calcium based

(5) cold-side electrostatic 

precipitator (ESP) (4/8/1974, 

original install)

(5) hydrated lime injection 

(SO3 control, 6/1/2015)

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.

Page 8 of 86 part I, 16
GEORGIA POWER - PLANT YATES

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/will be operated on an as-needed basis.

Dates for future planned controls listed are subject to change.

Boiler ID14 Type15 NOx control16 SO2 control17 PM control18 Other control19

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 9 of 86 part I, 16
GEORGIA POWER - PLANT YATES

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

Y1BR Not applicable Not applicable Not applicable Not applicable

Y2BR Not applicable Not applicable Not applicable Not applicable

Y3BR Not applicable Not applicable Not applicable Not applicable

Y4BR Not applicable Not applicable Not applicable Not applicable

Y5BR Not applicable Not applicable Not applicable Not applicable

Y6BR Not applicable Not applicable Not applicable Not applicable

Y7BR 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 10 of 86 part I, 17
GEORGIA POWER - PLANT YATES

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

Y1BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y2BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y3BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y4BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y5BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y6BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y7BR 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 11 of 86 part I, 18
GEORGIA POWER - PLANT YATES

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

Y1BR Not applicable Not applicable Not applicable Not applicable

Y2BR Not applicable Not applicable Not applicable Not applicable

Y3BR Not applicable Not applicable Not applicable Not applicable

Y4BR Not applicable Not applicable Not applicable Not applicable

Y5BR Not applicable Not applicable Not applicable Not applicable

Y6BR Not applicable Not applicable Not applicable Not applicable

Y7BR 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 12 of 86 part I, 19
GEORGIA POWER - PLANT YATES

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

Y1BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y2BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y3BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y4BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y5BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y6BR Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y7BR 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 13 of 86 part I, 20
GEORGIA POWER - PLANT YATES

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)

Y1BR E = 0.7 x (10/R)^0.202, where E equals the 

allowable particulate emission rate in pounds 

per million Btu heat input and R equals the heat 

input in million Btu per hour (Title V permit; 

based on pressure drop across the scrubber)

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)

10% of potential combustion concentration 

(90% 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: 0.38 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

Southern Company Phase II NOx Averaging Plan 

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

(Phase II NOx Compliance Plan; based on annual 

average determined by CEMS)

Y2BR 0.24 lb/MMBtu (Title V permit; based on 3-run 

stack test using Method 5 of 17; test conducted 

every 13 months, but may be deferred for 12 

months if test results from the previous annual 

tests are fifty percent or less of the limit)

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)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

NOx: 0.38 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

Southern Company Phase II NOx Averaging Plan 

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

(Phase II NOx Compliance Plan; based on annual 

average determined by CEMS)

Y3BR 0.24 lb/MMBtu (Title V permit; based on 3-run 

stack test using Method 5 of 17; test conducted 

every 13 months, but may be deferred for 12 

months if test results from the previous annual 

tests are fifty percent or less of the limit)

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)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

NOx: 0.38 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

Southern Company Phase II NOx Averaging Plan 

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

(Phase II NOx Compliance Plan; based on annual 

average determined by CEMS)

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

Boiler ID27

Page 14 of 86 part I, 21
GEORGIA POWER - PLANT YATES

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

Y4BR 0.24 lb/MMBtu (Title V permit; based on 3-run 

stack test using Method 5 of 17; test conducted 

every 13 months, but may be deferred for 12 

months if test results from the previous annual 

tests are fifty percent or less of the limit)

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)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

NOx: 0.33 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

Southern Company Phase II NOx Averaging Plan 

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

(Phase II NOx Compliance Plan; based on annual 

average determined by CEMS)

Y5BR 0.24 lb/MMBtu (Title V permit; based on 3-run 

stack test using Method 5 of 17; test conducted 

every 13 months, but may be deferred for 12 

months if test results from the previous annual 

tests are fifty percent or less of the limit)

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)

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

NOx: 0.33 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

Southern Company Phase II NOx Averaging Plan 

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

(Phase II NOx Compliance Plan; based on annual 

average determined by CEMS)

Y6BR 0.24 lb/MMBtu (Title V permit; based on 3-run 

stack test using Method 5 of 17; test conducted 

every 13 months, but may be deferred for 12 

months if test results from the previous annual 

tests are fifty percent or less of the limit)

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 June 1, 2015 (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: 0.26 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

Southern Company Phase II NOx Averaging Plan 

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

(Phase II NOx Compliance Plan; based on annual 

average determined by CEMS)

Page 15 of 86 part I, 21
GEORGIA POWER - PLANT YATES

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

Y7BR 0.24 lb/MMBtu (Title V permit; based on 3-run 

stack test using Method 5 of 17; test conducted 

every 13 months, but may be deferred for 12 

months if test results from the previous annual 

tests are fifty percent or less of the limit)

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 June 1, 2015 (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: 0.26 lb/MMBtu from May 1 through 

September 30 OR compliance with 5 and 7-plant 

NOx averages of 0.13 lb/MMBtu and 0.18 

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

rolling averages determined by CEMS)

Southern Company Phase II NOx Averaging Plan 

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

(Phase II NOx Compliance Plan; based on annual 

average determined by CEMS)

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

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

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

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

Also include the compliance test method utilized.

29 List the compliance test method utilized.

30 List the compliance test method utilized.

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

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

Page 16 of 86 part I, 21
GEORGIA POWER - PLANT YATES

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.

PM33 PM10 PM2.5 SO2

HCl 

and/or HF HCN

Metal 

HAP34 Hg CO

Other 

organics 

(specify)

Other pollutant (specify)

Y1BR ESP rebuild: 98.0 % collection efficiency 

filterable (expiration 1997)

Not 

applicable

Not 

applicable

Not applicable Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not applicable

Y2BR ESP rebuild: 98.3 % collection efficiency 

filterable(expiration in 1997)

Not 

applicable

Not 

applicable

Not applicable Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not applicable

Y3BR ESP rebuild: 98.3 % collection efficiency 

filterable (expiration in 1995)

Not 

applicable

Not 

applicable

Not applicable Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not applicable

Y4BR ESP rebuild: 98.3 % collection efficiency 

filterable (expiration in 1996)

Not 

applicable

Not 

applicable

Not applicable Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not applicable

Y5BR ESP rebuild: 98.3 % collection efficiency 

filterable (expiration 1996)

Not 

applicable

Not 

applicable

Not applicable Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not applicable

Y6BR ESP rebuild: 99.0 % collection efficiency 

filterable (expiration 1997)

Not 

applicable

Not 

applicable

Not applicable Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not applicable

Y7BR ESP rebuild: 99.0 % collection efficiency 

filterable (expiration 1997)

Not 

applicable

Not 

applicable

Not applicable Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not applicable

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

Please elaborate.

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

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

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

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

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

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

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

Boiler ID32

Page 17 of 86 part I, 22-23
GEORGIA POWER - PLANT YATES

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)

Y1BR Pressure drop across the scrubber monitored continuously; excursions for pressure drop 

less than 10 inches of water reported quarterly; records retained for 5 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

Y2BR Stack test conducted every 13 months, but may be deferred for 12 months if test results 

from the previous annual tests are fifty percent or less of the limit; under the CAM plan, 

opacity monitored continuously by COMS, excursions (3-hour block averages greater 

than 32%) 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.

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Y3BR Stack test conducted every 13 months, but may be deferred for 12 months if test results 

from the previous annual tests are fifty percent or less of the limit; under the CAM plan, 

opacity monitored continuously by COMS, excursions (3-hour block averages greater 

than 32%) 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.

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Y4BR Stack test conducted every 13 months, but may be deferred for 12 months if test results 

from the previous annual tests are fifty percent or less of the limit; under the CAM plan, 

opacity monitored continuously by COMS, excursions (3-hour block averages greater 

than 33%) 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.

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 18 of 86 part I, 24
GEORGIA POWER - PLANT YATES

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

Y5BR Stack test conducted every 13 months, but may be deferred for 12 months if test results 

from the previous annual tests are fifty percent or less of the limit; under the CAM plan, 

opacity monitored continuously by COMS, excursions (3-hour block averages greater 

than 33%) 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.

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Not 

applicable

Y6BR Stack test conducted every 13 months, but may be deferred for 12 months if test results 

from the previous annual tests are fifty percent or less of the limit; under the CAM plan, 

opacity monitored continuously by COMS, excursions (3-hour block averages greater 

than 29%) 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 June 1, 2015, 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

Y7BR Stack test conducted every 13 months, but may be deferred for 12 months if test results 

from the previous annual tests are fifty percent or less of the limit; under the CAM plan, 

opacity monitored continuously by COMS, excursions (3-hour block averages greater 

than 23%) 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 June 1, 2015, 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 19 of 86 part I, 24
GEORGIA POWER - PLANT YATES

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.

Units 1-7 have the ability to inject a limited amount of natural gas as needed to meet permit limits for NOx emissions during the ozone season.

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

Page 20 of 86 part I, 25-26
GEORGIA POWER - PLANT YATES

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: 

Yates

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

728

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

Page 21 of 86 part II, 1
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

12,182

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.24 13.34 13,217

11,831

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 0.84 12.56 13,193

12,150

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.34 13.8 13,253

11,101

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 0.97 12.75 13,422

12,144

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.08 12.18 13,456

12,205

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.33 12.98 13,358

12,218

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.12 12.81 13,397

11,884

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.05 12.45 13,527

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

Page 22 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

12,091

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.11 11.64 13,566

12,069

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.31 12.82 13,434

12,229

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.11 11.32 13,578

12,125

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1 11.88 13,561

12,231

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.29 11.77 13,637

11,956

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.13 11.67 13,571

12,076

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.24 11.44 13,633

11,928

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 0.98 11.71 13,579

Page 23 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,734

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.33 12.32 13,422

12,105

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.33 12.26 13,490

12,206

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.42 12.57 13,361

12,121

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.08 13.75 13,175

12,140

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

EDWARDS, JAWBONE, 

NORTON, RAVEN, SPLASHDAM TRAIN 1.42 12.54 13,389

7,013

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.31 12.99 13,024

6,958

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.33 13.09 13,034

7,066

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.32 12.92 13,053

Page 24 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

7,030

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.34 13.2 13,002

7,014

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.36 13.01 13,037

7,023

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.29 12.51 13,115

7,048

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.33 12.62 13,097

6,962

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.33 12.35 13,118

6,999

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.35 12.45 13,134

7,198

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.32 12.81 13,018

7,166

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.54 13.45 12,928

Page 25 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

7,001

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.43 12.26 13,135

7,046

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.56 12.48 13,099

6,853

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.2 13.81 12,914

6,778

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.44 13.11 13,030

7,006

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.4 13.14 13,041

7,026

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.25 12.4 13,148

6,944

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.43 12.3 13,139

7,077

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.39 13.69 12,896

Page 26 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

7,102

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.35 13.21 12,994

7,012

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.36 13.1 13,022

7,035

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.11 12.47 13,069

7,017

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.14 11.91 13,160

6,998

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.23 12.05 13,124

7,035

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.34 13.38 12,957

7,026

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.22 12.53 13,101

6,881

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.3 12.82 13,052

Page 27 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

7,039

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.15 12.35 13,137

6,949

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.33 12.29 13,110

7,021

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.22 13.34 12,947

6,985

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.25 12.69 13,086

7,123

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.14 13.06 13,013

6,944

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.18 12.64 13,076

6,957

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.12 13.03 13,068

7,189

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.13 12.74 13,109

Page 28 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

7,029

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.16 13.39 12,989

6,891

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.33 12.88 13,063

7,003

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.33 13.55 12,992

7,065

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.22 14.16 12,842

6,889

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.19 12.35 13,181

7,087

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.18 12.96 12,933

6,917

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.29 12.32 12,997

6,879

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.16 12.52 13,071

Page 29 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

6,806

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.16 13.48 12,988

6,920

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.05 13.7 12,911

6,909

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.21 13.17 13,004

6,926

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR AL

FAYETTE, 

TUSCALOOSA PRATT TRAIN 2.25 12.52 13,131

9,923

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR COLOMBIA N/A GRAN MADRE TRAIN 0.48 5.89 13,124

10,006

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR COLOMBIA N/A GRAN MADRE TRAIN 0.51 6.07 13,107

9,974

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR COLOMBIA N/A GRAN MADRE TRAIN 0.53 5.47 13,236

11,377

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY MARTIN ALMA TRAIN 1.57 9.65 13,394

Page 30 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

12,028

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.95 12.11 13,457

11,694

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 1.12 14.8 13,003

12,084

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 1.09 12.4 13,370

12,033

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.9 12.31 13,447

12,031

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.91 13.31 13,250

11,960

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.89 10.96 13,637

11,969

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.87 12.56 13,376

12,013

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.9 12.32 13,432

Page 31 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

12,031

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.85 11.47 13,539

12,111

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.87 13.01 13,289

12,082

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 1.06 13.02 13,273

12,096

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.95 13.69 13,185

12,057

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.92 13.02 13,320

11,991

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.98 11.84 13,478

12,063

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE IMBODEN, LOW SPLINT, TIGER TRAIN 0.91 13.4 13,270

10,379

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, VA HARLAN, LEE

CREECH, DARBY, HARLAN, 

KELLIOKA TRAIN 0.87 12.24 13,236

Page 32 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

10,454

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, VA HARLAN, LEE

CREECH, DARBY, HARLAN, 

KELLIOKA TRAIN 1.1 11.02 13,403

11,305

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.15 9.84 13,376

11,568

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 0.89 6.88 13,905

11,695

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.01 8.99 13,566

10,282

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.08 10.25 13,254

11,010

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.17 9.34 13,507

10,951

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.12 8.03 13,670

10,987

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.05 7.93 13,777

Page 33 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,735

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

CEDAR GROVE, LYONS, 

STANIFORD TRAIN 1.68 12.1 13,295

10,578

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

CEDAR GROVE, LYONS, 

STANIFORD TRAIN 1.86 11.19 13,497

11,423

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

CEDAR GROVE, LYONS, 

STANIFORD TRAIN 1.4 12.94 13,257

12,093

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

CEDAR GROVE, LYONS, 

STANIFORD TRAIN 1.9 13.3 13,142

12,024

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

CEDAR GROVE, LYONS, 

STANIFORD TRAIN 1.92 12.32 13,297

12,100

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR VA WISE

CEDAR GROVE, LYONS, 

STANIFORD TRAIN 2.03 12.53 13,302

8,418

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.95 9.99 13,487

8,285

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.62 10.06 13,457

Page 34 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

7,247

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 2.03 9.18 13,369

7,645

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 2.05 10.37 13,365

7,733

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 2.37 11.02 13,317

7,729

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 2.37 10.73 13,301

7,748

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 2.41 10.69 13,378

7,930

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.71 10.26 13,437

7,988

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 2.02 8.53 13,665

8,796

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 2.03 11.04 13,246

Page 35 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

10,204

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 2.32 10.11 13,409

11,596

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.1 8.31 13,610

9,740

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.68 10.74 13,346

9,669

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.49 11.68 13,141

9,675

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.48 9.05 13,539

9,979

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.68 6.87 14,015

9,725

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.52 9.92 13,365

9,929

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.59 8.82 13,644

Page 36 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

9,824

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.82 8.33 13,644

10,046

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.84 9.34 13,548

9,393

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.8 9.1 13,570

9,832

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.43 11.61 13,185

10,051

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.65 11.05 13,220

9,645

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.43 10.79 13,340

9,826

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.3 10.65 13,284

9,792

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.51 11.81 13,039

Page 37 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

9,778

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.45 10.76 13,256

9,822

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.45 10.76 13,267

9,738

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.23 9.37 13,534

9,446

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.56 10.15 13,324

10,453

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.21 8.29 13,680

9,787

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.67 10.03 13,367

9,366

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.58 9.49 13,489

9,723

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.47 10.77 13,283

Page 38 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

9,969

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.29 11 13,224

9,793

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.81 8.68 13,598

9,905

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.48 9.35 13,481

9,658

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.48 10.2 13,346

9,732

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.55 9.45 13,462

9,760

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.44 9.67 13,475

9,892

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.5 10.18 13,402

9,434

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.33 11.35 13,249

Page 39 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

10,972

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 0.91 6.09 14,061

9,681

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.64 9.99 13,416

9,758

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.27 10.59 13,184

10,908

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.17 6.95 13,903

9,614

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR TN ANDERSON PEE WEE, WALNUT MTN TRAIN 1.1 7.42 13,952

11,811

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE ALMA TRAIN 1.32 8.97 13,413

11,850

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE ALMA TRAIN 1.76 9.24 13,397

11,850

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.75 10.02 13,658

Page 40 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,907

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.97 12.4 13,098

11,879

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.78 11.8 13,315

12,044

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.82 11.99 13,241

11,668

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.72 9.62 13,518

11,936

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.84 10.75 13,636

11,989

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.88 12.34 13,306

12,028

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.81 10.9 13,496

11,984

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.79 12.28 13,301

Page 41 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

12,075

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.98 11.14 13,430

11,935

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 0.75 12.21 13,296

12,056

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN 1.01 9.9 13,735

N/A

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

ALMA, ELKHORN, ELKHORN #2, 

ELKHORN #3 TRAIN N/A N/A N/A

11,581

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.87 13.2 13,019

11,640

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.79 13.21 13,085

11,601

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.84 13.51 12,956

11,668

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY PIKE

POND CREEK, TAYLOR, 

WILLIAMSON TRAIN 0.85 12.8 13,191

Page 42 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

10,938

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, WV LESLIE, LOGAN ALMA TRAIN 0.78 13.06 13,076

12,194

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, WV LESLIE, LOGAN ALMA TRAIN 0.66 10.45 13,503

10,058

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, WV LESLIE, LOGAN ALMA TRAIN 0.81 12.3 13,183

10,379

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, WV LESLIE, LOGAN ALMA TRAIN 0.79 11.98 13,340

11,703

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, WV LESLIE, LOGAN ALMA TRAIN 0.81 12.27 13,311

10,579

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, WV LESLIE, LOGAN ALMA TRAIN 0.83 11.68 13,413

11,962

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, WV LESLIE, LOGAN ALMA TRAIN 0.77 12.02 13,367

11,968

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY, WV LESLIE, LOGAN ALMA TRAIN 1.02 10.4 13,624

Page 43 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

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

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

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

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

State/Country County42 Coal seam43

% Sulf % Ash Btu/lb

Vendor Analyses

Amount received, dry 

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel source Fuel shipment 

method

11,017

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY MARTIN POND CREEK TRAIN 0.94 9.84 13,371

11,871

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY MARTIN POND CREEK TRAIN 1.01 5.92 14,066

10,944

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY MARTIN POND CREEK TRAIN 0.92 10.53 13,205

11,132

Y1BR, Y2BR, Y3BR, 

Y4BR, Y5BR, Y6BR, 

Y7BR KY MARTIN POND CREEK TRAIN 0.99 10.36 13,138

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 44 of 86 part II, 2 (coal)
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

State/Country County42 Coal seam43

7,627 Y6BR, Y7BR Georgia/USA N/A N/A Truck

15,215 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,520 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,630 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,620 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

15,265 Y6BR, Y7BR Georgia/USA N/A N/A Truck

15,250 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,680 Y6BR, Y7BR Georgia/USA N/A N/A Truck

15,263 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,626 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,635 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,636 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,638 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,639 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,647 Y6BR, Y7BR Georgia/USA N/A N/A Truck

15,188 Y6BR, Y7BR Georgia/USA N/A N/A Truck

15,208 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,606 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,610 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,603 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,591 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,591 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

15,136 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,557 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR 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 45 of 86 part II, 2 (oil)
GEORGIA POWER - PLANT YATES

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

7,549 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,557 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,558 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,533 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,534 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,554 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,521 Y6BR, Y7BR Georgia/USA N/A N/A Truck

22,551 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,520 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,522 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,537 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,543 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,562 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

30,273 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,579 Y6BR, Y7BR Georgia/USA N/A N/A Truck

15,146 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,572 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

22,765 Y6BR, Y7BR Georgia/USA N/A N/A Truck

7,585 Y1BR, Y2BR, Y3BR, Y4BR, Y5BR Georgia/USA N/A N/A Truck

7,624 Y6BR, Y7BR 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.

Page 46 of 86 part II, 2 (oil)
GEORGIA POWER - PLANT YATES

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

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 47 of 86 part II, 2 (oil)
GEORGIA POWER - PLANT YATES

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

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

KY - Harlan 

VA - 

Buchanan, 

Dickenson, 

Wise

Clintwood 28.82%, 

Blair 9.16%, Eagle 

10.89%, Norton 

15.19%, L. Banner 

5.15%, Tiller 

6.27%, Bolling 

6.06%, Blue Gem 

0.91%, Aily 6.81%, 

Banner 6.55%, 

Jawbone 4.19% Train

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

 (1)Parsons (2) 

Imboden 

(3)Taggart 

(4)Taggert Marker 

(5)Low Splint C (6) 

Low splint (7) Low 

Splint A Train

09-504 11,367 1.23 11.79 13,262 0.070 93 130 10.7 1.3 17.4 1.6 0.13 15.8 6.1 8.1 21.4 2.5 VA Wise

(1)Morris (2)Cedar 

Grove (3) Mixed 

(4)Parsons 

(5)Taggart (6)#8 Train

09-505 12,229 1.54 10.24 13,258 0.113 2148 69 13.5 1.6 10.6 2.1 0.06 15.8 7.0 9.6 24.2 3.9 KY Martin Alma, Coalburg Train

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

Broaz, Haddix, 

Chilton, Middle 

Whitesburg, 

Upper/Lower 

Alma, Haddix, 

Cedar Grove, 

Williamson Train

09-623 7,557 2.3 13.06 13,035 0.151 151 44 18.3 1.5 13.8 1.7 <0.02 25.6 9.4 6.7 33.8 2.2 AL Fayette Pratt Train

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

Creech, House 

Coal Train

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

Braden, Red Ash, 

Walnut Mountain Train

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

Walnut Mountain, 

Windrock, Pee 

Wee Train

Total amount of 

fuel represented 

by sample, tons

Sample 

ID #

State/ 

Country

County

Fuel 

Shipment 

Method

Nickel, 

ppm

Other trace metal HAP, ppm45

Total 

Sulfur, %

Ash 

Content, 

%

Heating 

Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Coal Seam

Page 48 of 86 part II, 3
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

Total amount of 

fuel represented 

by sample, tons

Sample 

ID #

State/ 

Country

County

Fuel 

Shipment 

Method

Nickel, 

ppm

Other trace metal HAP, ppm45

Total 

Sulfur, %

Ash 

Content, 

%

Heating 

Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Coal Seam

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

(1) Low Splint (2) 

Imboden 

(3)Taggart 

(4)Upper Parsons 

(5)Taggart Marker 

(6)Lower Parsons Train

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

Buchanan, 

Dickenson 

and Wise

Blair 26.61%, 

Clintwoood 

20.34%, Raven 

18.16%, Aily 

12.22%, Eagle 

11.99%, L. Banner 

5.69%, Banner 

4.99% Train

09-514 12,661 1.9 12.38 13,317 0.120 126 98 14.0 1.7 39.7 2.6 0.29 15.1 7.9 7.4 37.4 2.6 VA Wise

Cedar Grove, 

Morris Ryder Train

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

Lower Elkhorn, 

Elkhorn , Alma, 

Clintwood Train

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

Chilton, 

Whitesburg, 

Upper/Lower 

Alma, Cedar Grove Train

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

Walnut Mountain, 

Windrock, Pee 

Wee Train

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

Braden, Red Ash, 

Walnut Mountain Train

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

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

09-641 7,575 2.39 13.06 12,996 0.182 133 68 16.9 1.7 15.2 1.3 0.09 20.9 8.5 9.5 33.7 2.2 AL Fayette Pratt Train

Page 49 of 86 part II, 3
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

Total amount of 

fuel represented 

by sample, tons

Sample 

ID #

State/ 

Country

County

Fuel 

Shipment 

Method

Nickel, 

ppm

Other trace metal HAP, ppm45

Total 

Sulfur, %

Ash 

Content, 

%

Heating 

Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Coal Seam

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

(1) Imboden 

(2)Taggart 

(3)Lower Parsons 

(4)Taggart Marker 

(5)Low Splint (6) 

Low Splint A (7) 

Low Splint D (8) 

Upper Parsons Train

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

Buchanan, 

Dickenson 

and Wise

Clintwoood 

34.89%, Norton 

26.08% Blair 

14.43% Aily 

6.83%, Jawbone 

5.33% Eagle 4.99 

(7) Cedar Grove 

3.10% (8) Bolling 

2.96% (9) Raven 

1.38% Train

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

Lower Elkhorn, 

Elkhorn , Alma, 

Clintwood Train

09-523 12,773 1.63 13.7 13,044 0.157 150 113 15.4 ND 40.8 1.8 0.15 16.6 7.6 7.3 40.6 2.3 VA Wise

Cedar Grove, High 

Splint, Morris 

Ryder, High Splint 

Marker Train

09-110 7,812 2.16 12.63 13,082 0.122 165 35 18.4 1.4 15.6 1.4 0.10 24.9 9.6 11.0 36.2 2.3 AL Fayette Pratt Train

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

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

Chilton, 

Whitesburg, 

Upper/Lower 

Alma, Cedar Grove Train

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

Alma, Taylor, 

Stockton Train

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

Walnut Mountain, 

Windrock, Pee 

Wee Train

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

Braden, Red Ash, 

Walnut Mountain Train

Page 50 of 86 part II, 3
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

, as

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

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

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

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

Total amount of 

fuel represented 

by sample, tons

Sample 

ID #

State/ 

Country

County

Fuel 

Shipment 

Method

Nickel, 

ppm

Other trace metal HAP, ppm45

Total 

Sulfur, %

Ash 

Content, 

%

Heating 

Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Coal Seam

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

Chilton, Lower 

Alma, Cedar 

Grove, #3 Elkhorn Train

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

Walnut Mountain, 

Windrock, Pee 

Wee Train

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

Braden, Red Ash, 

Walnut Mountain Train

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

(1) Parsons 

(2)Taggart (3)Low 

Splint A 

(4)Dorchester Train

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

Mingo, 

Logan

Coalburg, 

Stockton, Alma, 

Lower Cedar Grove Train

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

09-532 12,837 1.59 13.08 13,184 0.101 130 91 17.0 1.6 26.8 3.0 0.15 18.1 9.7 9.1 25.9 2.2 VA Wise

Morris, Cedar 

Grove, High Splint, 

Parsons Train

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

Buchanan, 

Dickenson 

and Wise

Bolling 24.88%, 

Clintwoood 

19.15%, Aily 

15.35%, Blair 

14.42% L. Banner 

13.23%, Raven 

4.52% Eagle 

4.02%, U. Banner 

3.44%, Taggart 

0.98% Train

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

Alma, Taylor, 

Stockton Train

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

Lower Elkhorn, 

Elkhorn , Alma, 

Clintwood Train

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

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

analysis requirement can be bypassed by the respondent.

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

Page 51 of 86 part II, 3
GEORGIA POWER - PLANT YATES

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 52 of 86 part II, 4-6
GEORGIA POWER - PLANT YATES

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

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

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

09-504 5.84 33.51 11.79 54.7 76.11 4.73 1.48 1.23 4.66 131 19.4 0.077 0.025 29.7 17.1 26.5 9.34 1.22 0.972 ND 0.577 2.73 48.6 0.35 0.288 1.36

09-505 6.83 37.22 10.24 52.53 76.72 4.88 1.41 1.54 5.2 317 23.5 0.008 0.000 37.3 16.1 26.3 12.7 2.5 0.876 ND ND 2.2 45.7 0.523 1.82 1.25

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

09-623 7.14 34.92 13.06 52.02 73.1 4.92 1.92 2.3 4.7 220 35.3 0.102 0.044 55.8 26.9 26.08 14.67 4.31 1.3 0.041 0.68 2.38 43.07 0.46 5.31 1.34

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

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

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

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

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

09-514 4.99 34.16 12.38 53.47 76.24 4.86 1.34 1.9 3.28 172 20.1 0.098 0.025 31.1 21.7 24.1 17.9 1.11 1.17 ND ND 3.13 45.3 0.322 0.568 1.02

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

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

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

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

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

09-217 6.04 36.73 9.81 53.45 73.44 4.77 1.47 0.95 9.57 31 20.8 0.038 0.023 43.1 21.9 32.7 5.17 1.15 0.612 ND ND 1.89 52.7 0.375 0.386 1.28

09-641 6.91 34.91 13.06 52.03 73.1 4.78 1.1 2.39 5.57 220 32.1 0.099 0.039 51.0 22.2 25.07 14.91 5.41 1.26 0.041 0.64 2.38 42.44 0.41 5.79 1.24

09-519 6.16 32.55 13.36 54.1 75.2 4.82 1.56 0.9 4.16 132 21.5 0.109 0.048 40.3 22.7 26.8 8.44 1.64 1.35 ND ND 3.29 58.4 0.542 1.25 1.3

09-520 4.92 35.57 9.91 54.52 77.95 4.74 1.69 1.28 4.43 172 20.4 0.075 0.034 31.0 17.7 25.8 12.5 1.78 1.09 ND ND 2.43 58 0.509 1.28 1.42

09-521 5.15 31.19 12.11 56.71 75.69 4.76 1.56 0.75 5.13 285 18.6 0.086 0.048 28.6 12.6 27.4 6.87 1.13 1.18 ND ND 3.27 57.8 0.54 0.715 1.35

09-523 5.05 34.22 13.7 52.08 71.4 4.7 1.39 1.63 7.17 183 17.6 0.131 0.026 33.0 25.8 24.8 16.1 0.949 1.4 ND ND 3.39 47 0.302 0.665 1.1

09-110 6.66 34.78 12.63 52.59 72.71 4.97 1.8 2.16 5.73 230 36.6 0.101 0.042 59.8 42.3 26.37 14.37 4.18 1.32 0.045 0.81 2.34 43.59 0.45 4.76 1.37

09-226 6.43 36.29 10.72 52.99 74.53 4.93 1.59 0.98 7.25 41 21.0 0.042 0.026 45.6 27.4 32.4 4.36 0.883 0.64 ND ND 2.1 56.5 0.37 0.272 1.29

09-527 7.86 32.37 11.8 55.83 74.02 4.43 1.5 0.81 7.44 285 17.6 0.083 0.039 20.4 15.6 24.8 11 1.74 1.33 ND ND 3.03 51.8 0.507 1.42 1.11

09-231 6.67 38.81 8.58 52.6 74.73 4.82 1.6 1.47 8.8 62 29.3 14.578 0.029 44.2 18.7 30 9.74 2.59 0.789 ND ND 1.81 47.7 0.501 2.47 1.21

09-429 6.36 35.29 10.27 54.44 73.63 4.69 1.62 2 7.78 92 45.9 0.085 0.015 61.3 34.8 27.5 11.6 2.72 1.35 ND ND 2.21 45.2 0.273 2.14 1.41

09-430 5.44 35.86 7.32 56.82 76.71 4.86 1.61 0.94 8.56 82 32.3 0.056 0.029 49.0 22.6 28.5 7.98 3.13 1.46 ND 0.441 2.25 48.3 0.376 2.33 1.37

09-233 7.03 31.74 12.37 55.89 73.57 4.52 1.35 0.74 7.46 255 20.5 0.084 0.034 23.3 17.2 23.7 12.7 1.67 1.04 0.132 ND 2.9 50.1 0.451 1.27 1.22

09-436 6.32 35.44 9.45 55.11 75 4.78 1.83 1.87 7.06 112 35.2 0.070 0.015 47.6 23.3 28 11.4 2.48 1.25 ND 0.477 2.17 48.2 0.253 2.19 1.38

09-437 6.02 36.44 6.61 56.95 77.61 4.94 1.74 1.31 7.79 71 28.2 0.054 0.015 39.6 20.3 32.3 4.08 0.902 0.651 ND ND 1.54 56.5 0.173 ND 1.75

09-529 6.24 33.15 12.13 54.71 75.15 4.65 1.44 1.01 5.62 122 24.1 0.092 0.037 41.2 20.5 26.9 6.59 1.2 1.06 ND 0.403 2.65 52.4 0.435 0.695 1.51

09-530 6.14 32.04 12.06 55.9 74.64 4.58 1.36 0.8 6.56 317 10.6 0.226 0.082 13.6 14.1 25.3 5.02 0.88 0.998 ND ND 2.38 56.1 0.291 0.556 1.44

09-241 7.18 35.8 11.46 52.75 73.15 4.74 1.45 0.89 8.31 31 22.7 0.052 0.026 48.8 23.3 28.5 3.76 0.833 0.679 ND ND 1.97 52.9 0.325 0.353 1.24

09-532 5.65 33.92 13.08 53.01 73.25 4.71 1.31 1.59 6.06 132 23.5 0.109 0.023 37.5 31.6 27.7 14.2 1.02 1.32 ND ND 3.52 54.4 0.292 0.575 1.21

Sample 

ID #

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

Page 53 of 86 part II, 7
GEORGIA POWER - PLANT YATES

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

09-534 5.91 28.73 13.4 57.87 71.07 4.35 1.49 1.07 8.62 162 17.8 0.087 0.033 29.8 22.0 27.5 9.14 2.04 1.11 ND 0.353 2.64 58.4 0.431 1.09 1.78

09-535 6.75 37.55 9.27 53.18 74.41 4.84 1.6 1.35 8.53 62 21.3 0.045 0.033 35.5 15.3 30.1 11.7 2.59 0.809 ND ND 1.89 48.5 0.545 1.51 1.34

09-239 6.42 31.36 11.8 56.85 74.7 4.56 1.5 0.89 6.56 315 21.4 0.080 0.043 33.1 13.0 30.3 5.64 1.14 1.15 ND ND 2.9 51 0.57 1.08 1.4

Page 54 of 86 part II, 7
GEORGIA POWER - PLANT YATES

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 Units 2&3 Particulate Emissions Test (March 1, 2005)

Report 2 Units 4&5 Particulate Emissions Test (March 2, 2005)

Report 3 Unit 6 Particulate Emissions Test (April 27, 2005)

Report 4 Unit 7 Particulate Emissions Test (April 27, 2005)

Report 5 Units 2&3 Particulate Emissions Test (February 28, 2007)

Report 6 Units 4&5 Particulate Emissions Test (February 28, 2007)

Report 7 Unit 6 Particulate Emissions Test (February 28, 2007)

Report 8 Unit 7 Particulate Emissions Test (February 28, 2007)

Report 9 Units 2&3 Particulate Emissions Test (February 25, 2009)

Report 10 Units 4&5 Particulate Emissions Test (February 25, 2009)

Report 11 Unit 6 Particulate Emissions Test (February 24, 2009)

Report 12 Unit 7 Particulate Emissions Test (February 24, 2009)

Report 13 Unit 6 SCR Baseline (September 12, 2008 to October 2, 2008)

Report 14 Unit 6 Sorbent Injection Mercury Study (February 28, 2005 to March 22, 2005)

Report 15 DRAFT Unit 1 Boiler Chemical Addition Mercury Study (October 31, 2007 to November 7, 2007)

Report 16 Unit 1 Sorbent Injection for Small ESP Mercury Control (January 2005)

Report 17 Unit 1 Field Testing of a Wet FGD Additive for Enhanced Mercury Control (May 15, 2007 to September 27, 2007)

Report 18 Unit 1 Multi-Method Mercury Speciation Testing (March 15, 2006 to March 21, 2006)

Report 19 Unit 1 SO3 Testing (March to August 2008)

Report 20 Unit 1 SO3 Testing (October 2009)

Report 21 Unit 1 ACI into FGD (November 2009 to December 2009)

Report 22 Unit 1 Lime Injection into FGD (February 2006)

Report 23 Unit 1 Lime Injection into FGD (February 2007)

Page 55 of 86 part II, 8
GEORGIA POWER - PLANT YATES

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: 3/1/2005 Type: stack Constituents: PM

Report 2 Date: 3/2/2005 Type: stack Constituents: PM

Report 3 Date: 4/27/2005 Type: stack Constituents: PM

Report 4 Date: 4/27/2005 Type: stack Constituents: PM

Report 5 Date: 2/28/2007 Type: stack Constituents: PM

Report 6 Date: 2/28/2007 Type: stack Constituents: PM

Report 7 Date: 2/28/2007 Type: stack Constituents: PM

Report 8 Date: 2/28/2007 Type: stack Constituents: PM

Report 9 Date: 2/25/2009 Type: stack Constituents: PM

Report 10 Date: 2/25/2009 Type: stack Constituents: PM

Report 11 Date: 2/24/2009 Type: stack Constituents: PM

Report 12 Date: 2/24/2009 Type: stack Constituents: PM

Report 13 Date: 9/12/2008-10/2/2008 Type: duct Constituents: CO

Report 14 Date: 2/28/2005-3/22/2005 Type: duct/stack Constituents: Hg

Report 15 Date: 10/31/2007-11/7/2007 Type: duct/stack Constituents: Hg

Report 16 Date: Jan 2005 Type: duct/stack Constituents: HCl, HF

Report 17 Date:

5/15/2007-5/30/2007

8/28/2007-9/27/2007 Type: duct/stack Constituents: Hg

Report 18 Date: 3/15/2006-3/21/2006 Type: duct/stack Constituents: Hg, HCl, SO3

Report 19 Date: Mar 2008-Aug 2008 Type: duct/stack Constituents: SO3

Report 20 Date: Oct 2009 Type: duct/stack Constituents: SO3

Report 21 Date: Nov 2009-Dec 2009 Type: stack Constituents: PM

Report 22 Date: Feb 2006 Type: duct/stack Constituents: SO3

Report 23 Date: Feb 2007 Type: duct/stack Constituents: SO3

Page 56 of 86 part II, 8
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

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

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

Although Report 13 reflects testing at the economizer outlet (upstream of all post-combustion control devices), there are

no control devices downstream designed to reduce CO.

Reports 15, 16, 17, 18, 19, 20, 22, 23 reflect testing upstream of the scrubber, at the inlet duct.

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.

Page 57 of 86 part II, 8
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

The control configuration shown below is representative of the conditions present during Reports 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 

15, 16, 17, 18, 21.

Boiler ID Type NOx control SO2 control PM control Other control

Y1BR tangentialfired(1) low NOx burners (3) wet flue gas 

desulfurization (FGD)

(2) cold-side electrostatic 

precipitator 

Y2BR tangentialfired(3) cold-side electrostatic 

precipitator

(2) flue gas conditioning 

(SO3 injection)

(1) flue gas 

conditioning (ammonia)

Y3BR tangentialfired(3) cold-side electrostatic 

precipitator

(2) flue gas conditioning 

(SO3 injection)

(1) flue gas 

conditioning (ammonia)

Y4BR tangentialfired(1) flame attachment 

nozzle (low-NOX burner 

tip design) and closecoupled overfire air 

(4) cold-side electrostatic 

precipitator 

(3) flue gas conditioning 

(SO3 injection)

(2) flue gas 

conditioning (ammonia) 

Y5BR tangentialfired(1) flame attachment 

nozzle (low-NOX burner 

tip design) and closecoupled overfire air

(4) cold-side electrostatic 

precipitator 

(3) flue gas conditioning 

(SO3 injection) 

(2) flue gas 

conditioning (ammonia) 

Y6BR tangentialfired(1) low-NOX concentric 

firing system + separated 

overfire air

(5) cold-side electrostatic 

precipitator

Y7BR tangentialfired(1) flame attachment 

nozzle (low-NOX burner 

tip design) and separated 

overfire air

(5) cold-side electrostatic 

precipitator 

Page 58 of 86 part II, 8
GEORGIA POWER - PLANT YATES

EGU HAPs ICR, OMB Control No. 2060-0631

April 5, 2010

The control configuration shown below is representative of the conditions present during Reports 19, 20, 22, 23.

Boiler ID Type NOx control SO2 control PM control Other control

Y1BR tangentialfired(1) low NOx burners (3) wet flue gas 

desulfurization (FGD)

(2) cold-side electrostatic 

precipitator 

(3) lime injection 

(temporary system 

installed and operated 

for research & 

development purposes 

only)

8g Do any of these test reports reflect testing at a location upstream of 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 15, 16, 17, 18, 19, 20, 22, 23 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 59 of 86 part II, 8
GEORGIA POWER - PLANT YATES

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 not available for this facility, however some mercury CEMS data are provided in reports in response to Part II 

Question 12 of this ICR for reference. These data are collected for research purposes and do not necessarily follow any specific 

QA/QC guidelines.

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 60 of 86 part II, 9-11
GEORGIA POWER - PLANT YATES

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)

Y2BR & 

Y3BR 3/1/2005 See Attachment 1 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y4BR & 

Y5BR 3/2/2005 See Attachment 2 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y6BR 4/27/2005 See Attachment 3 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y7BR 4/27/2005 See Attachment 4 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y2BR & 

Y3BR 2/28/2007 See Attachment 5 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y4BR & 

Y5BR 2/28/2007 See Attachment 6 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y6BR 2/28/2007 See Attachment 7 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y7BR 2/28/2007 See Attachment 8 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y2BR & 

Y3BR 2/25/2009 See Attachment 9 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y4BR & 

Y5BR 2/25/2009 See Attachment 10 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y6BR 2/24/2009 See Attachment 11 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y7BR 2/24/2009 See Attachment 12 Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

Y6BR

9/12/2008-

10/2/2008 Not applicable Not applicable Not applicable Not applicable Not applicable See Attachment 13 Not applicable

Y6BR

2/28/2005-

3/22/2005 Not applicable Not applicable Not applicable Not applicable See Attachment 14 Not applicable Not applicable

Y1BR

10/31/2007-

11/7/2007 Not applicable Not applicable Not applicable Not applicable See Attachment 15 Not applicable Not applicable

Y1BR Jan 2005 Not applicable Not applicable See Attachment 16 Not applicable Not applicable Not applicable Not applicable

Y1BR

5/15/2007-

9/27/2007 Not applicable Not applicable Not applicable Not applicable See Attachment 17 Not applicable Not applicable

Boiler ID

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

Page 61 of 86 part II, 12
GEORGIA POWER - PLANT YATES

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

Y1BR

3/15/2006-

3/21/2006 Not applicable Not applicable See Attachment 18 Not applicable See Attachment 18 Not applicable Not applicable

Y1BR

Nov 2009-Dec 

2009

Final data not yet 

available Not applicable Not applicable Not applicable Not applicable Not applicable Not applicable

47 Provide emission test data for all tests conducted since January 1, 2005. Please indicate test data acquired both before and after

any control device. Use additional pages as necessary. EPA may, at some future date, request a copy of one or more emission test reports.

Data generated to fulfill both Federal and State requirements must be provided. Note that data generated pursuant to CAA Title V

must be maintained and available for 5 years. Also include averaging times and measurement units for all pollutants.

48 For each emissions test run the respondent should provide the following process information: Unit Load (MW), Net generation during run (MWh net),

Flue gas moisture content (%), Flue gas flow rate (dscfm or Nm3/hr), Flue gas oxygen content (%, dry), Flue gas carbon dioxide content (%, dry), Flue gas

temperature at sampling point (oF), Flue gas pressure at sampling point (atm), Standard temperature (oF), Standard pressure (atm).

49 If emission testing recorded the emissions of filterable and condensable PM, separately, please include those separate emission results. 

Also, please include separate emission results for total PM, PM10, and PM2.5.

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

indicate emission level for all metal HAP for which an emission test has been conducted.

51 Please provide separate results for total Hg, elemental Hg, oxidized Hg, and particulate Hg, as available. If the emissions testing recorded

the amount of unburned carbon in fly ash (as reflected by the "Loss of Ignition" [L.O.I]) at the time of any Hg testing, please include these data.

Page 62 of 86 part II, 12
ATTACHMENT 1 - Yates Report 1 Test Results

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

Run 1 Run 2 Run 3

Test Date 3/1/2005 3/1/2005 3/1/2005

Run Start Time 8:15 9:45 11:15

Run End Time 9:20 10:55 12:25

Meter Volume (dacf), Vm: 41.29 42.335 41.707

Sqrt Delta P ("wc): 1.02 1.03 1.01

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 28.92 29.22 29.20

Delta H ("wc): 1.4 1.5 1.4

Volume in Impingers (mls), VIc: 58.0 64.1 63.0

Static Pressure ("wc), Pg: -1.50 -1.50 -1.60

Stack Pressure ("Hg), Ps: 28.81 29.11 29.08

Stack Temperature (F), Ts: 245 248 249

Meter Coefficient (no units), Y: 0.983 0.983 0.983

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 59 65 67

Stack Diameter (inches): 197 197 197

Area Stack (sq. ft.), As: 211.67 211.67 211.67

Nozzle Diameter (inches), dp: 0.214 0.214 0.214

Area Nozzle (sq. ft.), An: 0.000249 0.000249 0.000249

Percent CO2 (% dry volume): 11.6 11.5 11.6

Percent O2 (% dry volume): 7.1 7.3 7.2

Percent (N2 + CO) (% dry volume): 81.3 81.2 81.2

Particulate Collected (mg), Mn: 130.5 98.8 115.5

Molec. Wt. Dry (lb/lb-mole), Md: 30.140 30.132 30.144

Volume Water (scf), Vwstd 2.730 3.017 2.965

Meter Volume (dscf), Vmstd: 40.029 41.034 40.209

Wet Fraction (v/v), Bws: 0.064 0.068 0.069

Molec. Wt. Wet (lb/lb-mole), Ms: 29.365 29.301 29.310

Stack Gas Sampled (acf), Vma: 59.321 60.706 59.616 Averages

Stack Gas Velocity (fps), Vs: 66.56 67.07 66.23 67

Volumetric Flowrate (dscfm), Qs: 570,451 575,779 567,321 571,183

Volumetric Flowrate (acfm), Qa: 845,386 851,807 841,147 846,113

Grainloading (gr/dscf), cs: 0.0503 0.0372 0.0443 0.04

Emission Rate (lb/hour), E: 245.87 183.35 215.62 214.9

Percent Isokinetic Sampling (%), I: 99.64 101.19 100.64 100.49

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 2310.81 2298.59 2281.47 2296.95

Emission Rate (lbs/mmBtu), E: 0.106 0.080 0.095 0.094

Allowable Rate (lb/mmBtu): 0.240 0.240 0.240 0.240

Average Unit Gross Load (MW) 204 204 204 204

Particulate Emission Results Summary

Plant Yates Units 2-3

Page 63 of 86 Att. 1
ATTACHMENT 2 - Yates Report 2 Test Results

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

Run 1 Run 2 Run 3

Test Date 3/2/2005 3/2/2005 3/2/2005

Run Start Time 8:15 9:45 11:15

Run End Time 9:25 10:55 12:25

Meter Volume (dacf), Vm: 58.825 59.502 60.585

Sqrt Delta P ("wc): 1.52 1.52 1.54

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.20 29.22 29.20

Delta H ("wc): 3.0 3.0 3.1

Volume in Impingers (mls), VIc: 96.6 100.1 100.7

Static Pressure ("wc), Pg: -2.70 -3.20 -3.00

Stack Pressure ("Hg), Ps: 29.00 28.98 28.98

Stack Temperature (F), Ts: 283 285 287

Meter Coefficient (no units), Y: 0.983 0.983 0.983

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 55 60 65

Stack Diameter (inches): 174.96 174.96 174.96

Area Stack (sq. ft.), As: 166.96 166.96 166.96

Nozzle Diameter (inches), dp: 0.214 0.214 0.214

Area Nozzle (sq. ft.), An: 0.000249 0.000249 0.000249

Percent CO2 (% dry volume): 0.0 0.0 0.0

Percent O2 (% dry volume): 0.0 0.0 0.0

Percent (N2 + CO) (% dry volume): 100.0 100.0 100.0

Particulate Collected (mg), Mn: 121.9 121.9 132.0

Molec. Wt. Dry (lb/lb-mole), Md: 28.000 28.000 28.000

Volume Water (scf), Vwstd 4.547 4.712 4.740

Meter Volume (dscf), Vmstd: 58.231 58.389 58.921

Wet Fraction (v/v), Bws: 0.072 0.075 0.074

Molec. Wt. Wet (lb/lb-mole), Ms: 27.276 27.253 27.255

Stack Gas Sampled (acf), Vma: 91.139 91.959 93.000 Averages

Stack Gas Velocity (fps), Vs: 105.47 106.27 107.54 106

Volumetric Flowrate (dscfm), Qs: 675,049 675,925 682,544 677,839

Volumetric Flowrate (acfm), Qa: 1,056,537 1,064,534 1,077,309 1,066,127

Grainloading (gr/dscf), cs: 0.0323 0.0322 0.0346 0.03

Emission Rate (lb/hour), E: 186.87 186.60 202.20 191.9

Percent Isokinetic Sampling (%), I: 96.61 96.75 96.68 96.68

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 4141.41 4146.78 4187.38 4158.52

Emission Rate (lbs/mmBtu), E: 0.045 0.045 0.048 0.046

Allowable Rate (lb/mmBtu): 0.240 0.240 0.240 0.240

Average Unit Gross Load (MW) 282 282 282 282

Particulate Emission Results Summary

Plant Yates Units 4-5

Page 64 of 86 Att. 2
ATTACHMENT 3 - Yates Report 3 Test Results

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

Run 1 Run 2 Run 3

Test Date 4/27/2005 4/27/2005 4/27/2005

Run Start Time 8:00 9:55 11:40

Run End Time 9:25 11:10 12:50

Meter Volume (dacf), Vm: 37.455 39.265 40.262

Sqrt Delta P ("wc): 1.44 1.46 1.46

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.01 29.01 29.01

Delta H ("wc): 1.4 1.4 1.4

Volume in Impingers (mls), VIc: 46.0 47.0 45.5

Static Pressure ("wc), Pg: -2.50 -2.70 -2.40

Stack Pressure ("Hg), Ps: 28.83 28.81 28.83

Stack Temperature (F), Ts: 249 258 261

Meter Coefficient (no units), Y: 0.985 0.985 0.985

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 73 79 83

Stack Diameter (inches): 209.53 209.53 209.53

Area Stack (sq. ft.), As: 239.45 239.45 239.45

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): 12.5 12.6 12.5

Percent O2 (% dry volume): 7.0 6.8 6.9

Percent (N2 + CO) (% dry volume): 80.5 80.6 80.6

Particulate Collected (mg), Mn: 12.3 18.6 20.2

Molec. Wt. Dry (lb/lb-mole), Md: 30.285 30.289 30.276

Volume Water (scf), Vwstd 2.165 2.212 2.142

Meter Volume (dscf), Vmstd: 35.518 36.829 37.508

Wet Fraction (v/v), Bws: 0.057 0.057 0.054

Molec. Wt. Wet (lb/lb-mole), Ms: 29.579 29.593 29.613

Stack Gas Sampled (acf), Vma: 52.515 55.133 56.177 Averages

Stack Gas Velocity (fps), Vs: 94.36 96.19 96.15 96

Volumetric Flowrate (dscfm), Qs: 916,924 923,152 922,324 920,800

Volumetric Flowrate (acfm), Qa: 1,355,716 1,381,956 1,381,382 1,373,018

Grainloading (gr/dscf), cs: 0.0053 0.0078 0.0083 0.01

Emission Rate (lb/hour), E: 41.87 61.70 65.57 56.4

Percent Isokinetic Sampling (%), I: 95.59 98.45 100.36 98.13

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 3741.23 3811.80 3790.33 3781.12

Emission Rate (lbs/mmBtu), E: 0.011 0.016 0.017 0.015

Allowable Rate (lb/mmBtu): 0.240 0.240 0.240 0.240

Average Unit Gross Load (MW) 359 361 360 360

Particulate Emission Results Summary

Yates Unit 6

Page 65 of 86 Att. 3
ATTACHMENT 4 - Yates Report 4 Test Results

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

Run 1 Run 2 Run 3

Test Date 4/27/2005 4/27/2005 4/27/2005

Run Start Time 8:00 9:55 11:40

Run End Time 9:25 11:10 12:50

Meter Volume (dacf), Vm: 40.748 41.472 41.249

Sqrt Delta P ("wc): 1.45 1.44 1.46

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.01 29.01 29.01

Delta H ("wc): 1.4 1.4 1.4

Volume in Impingers (mls), VIc: 54.4 54.1 52.8

Static Pressure ("wc), Pg: -2.70 -2.60 -2.60

Stack Pressure ("Hg), Ps: 28.81 28.82 28.82

Stack Temperature (F), Ts: 255 262 266

Meter Coefficient (no units), Y: 0.983 0.983 0.983

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 72 75 80

Stack Diameter (inches): 209.53 209.53 209.53

Area Stack (sq. ft.), As: 239.45 239.45 239.45

Nozzle Diameter (inches), dp: 0.176 0.176 0.176

Area Nozzle (sq. ft.), An: 0.000168 0.000168 0.000168

Percent CO2 (% dry volume): 12.6 12.7 12.6

Percent O2 (% dry volume): 6.8 6.9 6.8

Percent (N2 + CO) (% dry volume): 80.6 80.4 80.6

Particulate Collected (mg), Mn: 15.2 15.2 16.0

Molec. Wt. Dry (lb/lb-mole), Md: 30.288 30.304 30.289

Volume Water (scf), Vwstd 2.561 2.546 2.485

Meter Volume (dscf), Vmstd: 38.672 39.103 38.542

Wet Fraction (v/v), Bws: 0.062 0.061 0.061

Molec. Wt. Wet (lb/lb-mole), Ms: 29.525 29.552 29.545

Stack Gas Sampled (acf), Vma: 57.984 59.129 58.535 Averages

Stack Gas Velocity (fps), Vs: 95.28 95.30 96.59 96

Volumetric Flowrate (dscfm), Qs: 912,980 905,498 913,793 910,757

Volumetric Flowrate (acfm), Qa: 1,368,906 1,369,227 1,387,794 1,375,309

Grainloading (gr/dscf), cs: 0.0061 0.0060 0.0064 0.01

Emission Rate (lb/hour), E: 47.56 46.65 50.31 48.2

Percent Isokinetic Sampling (%), I: 100.41 102.37 99.98 100.92

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 3778.73 3712.33 3773.16 3754.74

Emission Rate (lbs/mmBtu), E: 0.013 0.013 0.013 0.013

Allowable Rate (lb/mmBtu): 0.240 0.240 0.240 0.240

Average Unit Gross Load (MW) 353 354 351 353

Particulate Emission Results Summary

Yates Unit 7

Page 66 of 86 Att. 4
ATTACHMENT 5 - Yates Report 5 Test Results

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

Run 1 Run 2 Run 3

Test Date 2/28/2007 2/28/2007 2/28/2007

Run Start Time 9:15 11:10 12:40

Run End Time 10:30 12:20 13:50

Meter Volume (dacf), Vm: 42.721 43.269 43.568

Sqrt Delta P ("wc): 1.06 1.07 1.07

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.10 29.10 29.10

Delta H ("wc): 1.6 1.6 1.6

Volume in Impingers (mls), VIc: 55.6 55.5 56.2

Static Pressure ("wc), Pg: -2.10 -2.20 -2.20

Stack Pressure ("Hg), Ps: 28.95 28.94 28.94

Stack Temperature (F), Ts: 255 263 267

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: 64 73 79

Stack Diameter (inches): 197 197 197

Area Stack (sq. ft.), As: 211.67 211.67 211.67

Nozzle Diameter (inches), dp: 0.214 0.214 0.214

Area Nozzle (sq. ft.), An: 0.000249 0.000249 0.000249

Percent CO2 (% dry volume): 11.8 11.8 11.8

Percent O2 (% dry volume): 7.8 7.9 7.9

Percent (N2 + CO) (% dry volume): 80.5 80.4 80.2

Particulate Collected (mg), Mn: 80.6 63.2 59.6

Molec. Wt. Dry (lb/lb-mole), Md: 30.193 30.197 30.211

Volume Water (scf), Vwstd 2.617 2.612 2.645

Meter Volume (dscf), Vmstd: 41.435 41.271 41.148

Wet Fraction (v/v), Bws: 0.059 0.060 0.060

Molec. Wt. Wet (lb/lb-mole), Ms: 29.469 29.471 29.473

Stack Gas Sampled (acf), Vma: 61.626 62.129 62.301 Averages

Stack Gas Velocity (fps), Vs: 69.91 70.92 71.08 71

Volumetric Flowrate (dscfm), Qs: 596,982 598,274 596,258 597,171

Volumetric Flowrate (acfm), Qa: 887,888 900,637 902,785 897,103

Grainloading (gr/dscf), cs: 0.0300 0.0236 0.0223 0.03

Emission Rate (lb/hour), E: 153.56 121.23 114.19 129.7

Percent Isokinetic Sampling (%), I: 98.32 97.72 97.76 97.93

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 2301.45 2288.87 2269.49 2286.61

Emission Rate (lbs/mmBtu), E: 0.07 0.05 0.05 0.06

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.240

Average Unit Gross Load (MW) 208 208 208 208

Particulate Emission Results Summary

Yates Unit 2-3

Page 67 of 86 Att. 5
ATTACHMENT 6 - Yates Report 6 Test Results

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

Run 1 Run 2 Run 3

Test Date 2/28/2007 2/28/2007 2/28/2007

Run Start Time 9:15 11:10 12:40

Run End Time 10:30 12:20 13:50

Meter Volume (dacf), Vm: 44.52 42.975 43.28

Sqrt Delta P ("wc): 1.57 1.55 1.56

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.10 29.10 29.10

Delta H ("wc): 1.6 1.6 1.6

Volume in Impingers (mls), VIc: 65.1 62.9 63.5

Static Pressure ("wc), Pg: -2.00 -2.10 -1.90

Stack Pressure ("Hg), Ps: 28.95 28.95 28.96

Stack Temperature (F), Ts: 284 290 292

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: 60 72 77

Stack Diameter (inches): 175 175 175

Area Stack (sq. ft.), As: 167.03 167.03 167.03

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): 13.2 12.9 13.0

Percent O2 (% dry volume): 6.4 6.5 6.5

Percent (N2 + CO) (% dry volume): 80.4 80.6 80.4

Particulate Collected (mg), Mn: 49.2 65.7 56.8

Molec. Wt. Dry (lb/lb-mole), Md: 30.364 30.328 30.347

Volume Water (scf), Vwstd 3.064 2.961 2.989

Meter Volume (dscf), Vmstd: 44.004 41.503 41.399

Wet Fraction (v/v), Bws: 0.065 0.067 0.067

Molec. Wt. Wet (lb/lb-mole), Ms: 29.559 29.507 29.515

Stack Gas Sampled (acf), Vma: 68.508 65.248 65.336 Averages

Stack Gas Velocity (fps), Vs: 104.88 104.51 104.86 105

Volumetric Flowrate (dscfm), Qs: 675,162 666,254 665,903 669,106

Volumetric Flowrate (acfm), Qa: 1,051,131 1,047,446 1,050,928 1,049,835

Grainloading (gr/dscf), cs: 0.0173 0.0244 0.0212 0.02

Emission Rate (lb/hour), E: 99.84 139.58 120.91 120.1

Percent Isokinetic Sampling (%), I: 105.06 100.42 100.22 101.90

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 2867.10 2822.75 2808.23 2832.69

Emission Rate (lbs/mmBtu), E: 0.03 0.05 0.04 0.04

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit Gross Load (MW) 282 280 280 281

Particulate Emission Results Summary

Yates Unit 4-5

Page 68 of 86 Att. 6
ATTACHMENT 7 - Yates Report 7 Test Results

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

Run 1 Run 2 Run 3

Test Date 2/28/2007 2/28/2007 2/28/2007

Run Start Time 15:45 17:15 18:45

Run End Time 16:55 18:25 20:00

Meter Volume (dacf), Vm: 40.73 40.78 41.529

Sqrt Delta P ("wc): 1.44 1.45 1.45

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.00 29.00 28.98

Delta H ("wc): 1.3 1.4 1.4

Volume in Impingers (mls), VIc: 52.8 53.3 54.1

Static Pressure ("wc), Pg: -2.20 -2.10 -2.00

Stack Pressure ("Hg), Ps: 28.84 28.85 28.83

Stack Temperature (F), Ts: 268 269 268

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: 79 81 78

Stack Diameter (inches): 195.96 195.96 195.96

Area Stack (sq. ft.), As: 209.44 209.44 209.44

Nozzle Diameter (inches), dp: 0.178 0.178 0.178

Area Nozzle (sq. ft.), An: 0.000172 0.000172 0.000172

Percent CO2 (% dry volume): 12.2 12.2 12.3

Percent O2 (% dry volume): 6.2 6.2 6.1

Percent (N2 + CO) (% dry volume): 81.6 81.6 81.6

Particulate Collected (mg), Mn: 17.4 19.1 20.0

Molec. Wt. Dry (lb/lb-mole), Md: 30.199 30.201 30.207

Volume Water (scf), Vwstd 2.485 2.509 2.546

Meter Volume (dscf), Vmstd: 38.675 38.563 39.457

Wet Fraction (v/v), Bws: 0.060 0.061 0.061

Molec. Wt. Wet (lb/lb-mole), Ms: 29.462 29.456 29.467

Stack Gas Sampled (acf), Vma: 58.881 58.812 60.070 Averages

Stack Gas Velocity (fps), Vs: 95.69 96.15 96.04 96

Volumetric Flowrate (dscfm), Qs: 789,816 792,265 792,753 791,611

Volumetric Flowrate (acfm), Qa: 1,202,442 1,208,286 1,206,898 1,205,876

Grainloading (gr/dscf), cs: 0.0069 0.0076 0.0078 0.01

Emission Rate (lb/hour), E: 46.89 51.83 53.25 50.7

Percent Isokinetic Sampling (%), I: 99.35 98.75 100.98 99.69

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 3415.80 3410.89 3444.02 3423.57

Emission Rate (lbs/mmBtu), E: 0.01 0.02 0.02 0.01

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit Gross Load (MW) 361 363 364 363

Particulate Emission Results Summary

Yates Unit 6

Page 69 of 86 Att. 7
ATTACHMENT 8 - Yates Report 8 Test Results

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

Run 1 Run 2 Run 3

Test Date 2/28/2007 2/28/2007 2/28/2007

Run Start Time 15:45 17:15 18:45

Run End Time 16:55 18:25 20:00

Meter Volume (dacf), Vm: 41.019 40.872 39.197

Sqrt Delta P ("wc): 1.49 1.47 1.45

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.00 29.00 29.98

Delta H ("wc): 1.4 1.4 1.4

Volume in Impingers (mls), VIc: 55.7 56.1 56.3

Static Pressure ("wc), Pg: -2.30 -2.20 -2.20

Stack Pressure ("Hg), Ps: 28.83 28.84 29.82

Stack Temperature (F), Ts: 274 275 272

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: 79 80 77

Stack Diameter (inches): 195.96 195.96 195.96

Area Stack (sq. ft.), As: 209.44 209.44 209.44

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 12.3 12.2

Percent O2 (% dry volume): 6.0 5.9 6.0

Percent (N2 + CO) (% dry volume): 81.8 81.8 81.8

Particulate Collected (mg), Mn: 40.3 40.3 30.3

Molec. Wt. Dry (lb/lb-mole), Md: 30.196 30.204 30.197

Volume Water (scf), Vwstd 2.622 2.641 2.650

Meter Volume (dscf), Vmstd: 38.598 38.382 38.225

Wet Fraction (v/v), Bws: 0.064 0.064 0.065

Molec. Wt. Wet (lb/lb-mole), Ms: 29.420 29.418 29.407

Stack Gas Sampled (acf), Vma: 59.474 59.240 56.829 Averages

Stack Gas Velocity (fps), Vs: 99.57 98.11 95.21 98

Volumetric Flowrate (dscfm), Qs: 812,047 798,822 804,774 805,214

Volumetric Flowrate (acfm), Qa: 1,251,230 1,232,944 1,196,448 1,226,874

Grainloading (gr/dscf), cs: 0.0161 0.0162 0.0122 0.01

Emission Rate (lb/hour), E: 112.20 111.00 84.27 102.5

Percent Isokinetic Sampling (%), I: 96.07 97.12 96.01 96.40

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 3559.62 3517.28 3519.87 3532.26

Emission Rate (lbs/mmBtu), E: 0.03 0.03 0.02 0.03

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit Gross Load (MW) 363 361 362 362

Particulate Emission Results Summary

Yates Unit 7

Page 70 of 86 Att. 8
ATTACHMENT 9 - Yates Report 9 Test Results

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

Run 1 Run 2 Run 3

Test Date 2/25/2009 2/25/2009 2/25/2009

Run Start Time 10:05 11:50 13:25

Run End Time 11:20 13:05 14:35

Meter Volume (dacf), Vm: 38.582 39.446 39.89

Sqrt Delta P ("wc): 0.98 1.00 1.01

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.32 29.32 29.33

Delta H ("wc): 1.4 1.4 1.4

Volume in Impingers (mls), VIc: 51.7 52.7 54.9

Static Pressure ("wc), Pg: -1.50 -1.40 -1.40

Stack Pressure ("Hg), Ps: 29.21 29.22 29.23

Stack Temperature (F), Ts: 265 265 265

Meter Coefficient (no units), Y: 0.985 0.985 0.985

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 63 66 69

Stack Diameter (inches): 197.04 197.04 197.04

Area Stack (sq. ft.), As: 211.76 211.76 211.76

Nozzle Diameter (inches), dp: 0.210 0.210 0.210

Area Nozzle (sq. ft.), An: 0.000241 0.000241 0.000241

Percent CO2 (% dry volume): 11.2 11.3 11.3

Percent O2 (% dry volume): 7.8 7.9 8.0

Percent (N2 + CO) (% dry volume): 81.0 80.8 80.7

Particulate Collected (mg), Mn: 109.0 110.3 103.1

Molec. Wt. Dry (lb/lb-mole), Md: 30.100 30.120 30.132

Volume Water (scf), Vwstd 2.434 2.481 2.584

Meter Volume (dscf), Vmstd: 37.683 38.318 38.578

Wet Fraction (v/v), Bws: 0.061 0.061 0.063

Molec. Wt. Wet (lb/lb-mole), Ms: 29.366 29.383 29.370

Stack Gas Sampled (acf), Vma: 56.423 57.335 57.834 Averages

Stack Gas Velocity (fps), Vs: 64.91 66.03 66.64 66

Volumetric Flowrate (dscfm), Qs: 550,822 560,641 564,771 558,745

Volumetric Flowrate (acfm), Qa: 824,761 838,893 846,665 836,773

Grainloading (gr/dscf), cs: 0.0446 0.0444 0.0412 0.04

Emission Rate (lb/hour), E: 210.73 213.53 199.61 208.0

Percent Isokinetic Sampling (%), I: 100.44 100.35 100.29 100.36

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 2112.72 2133.92 2144.12 2130.26

Emission Rate (lbs/mmBtu), E: 0.10 0.10 0.09 0.10

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit 2 Gross Load (MW) 105 105 105 105

Average Unit 3 Gross Load (MW) 105 105 105 105

Average Sum Gross Load (MW) 110 110 110 110

Particulate Emission Results Summary

Plant Yates Units 2-3

Page 71 of 86 Att. 9
ATTACHMENT 10 - Yates Report 10 Test Results

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

Run 1 Run 2 Run 3

Test Date 2/25/2009 2/25/2009 2/25/2009

Run Start Time 10:05 11:50 13:25

Run End Time 11:20 13:05 14:35

Meter Volume (dacf), Vm: 40.46 41.287 40.957

Sqrt Delta P ("wc): 1.54 1.54 1.53

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.32 29.32 29.33

Delta H ("wc): 1.4 1.4 1.4

Volume in Impingers (mls), VIc: 54.8 58.0 57.8

Static Pressure ("wc), Pg: -3.10 -3.20 -3.10

Stack Pressure ("Hg), Ps: 29.09 29.08 29.10

Stack Temperature (F), Ts: 295 296 296

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: 64 67 70

Stack Diameter (inches): 167.03 167.03 167.03

Area Stack (sq. ft.), As: 152.17 152.17 152.17

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): 11.8 11.8 11.9

Percent O2 (% dry volume): 7.1 7.0 7.0

Percent (N2 + CO) (% dry volume): 81.1 81.2 81.1

Particulate Collected (mg), Mn: 81.1 88.7 71.9

Molec. Wt. Dry (lb/lb-mole), Md: 30.177 30.163 30.179

Volume Water (scf), Vwstd 2.579 2.730 2.721

Meter Volume (dscf), Vmstd: 39.937 40.470 39.978

Wet Fraction (v/v), Bws: 0.061 0.063 0.064

Molec. Wt. Wet (lb/lb-mole), Ms: 29.439 29.394 29.403

Stack Gas Sampled (acf), Vma: 62.525 63.617 62.876 Averages

Stack Gas Velocity (fps), Vs: 103.77 103.92 103.19 104

Volumetric Flowrate (dscfm), Qs: 605,145 603,544 599,024 602,571

Volumetric Flowrate (acfm), Qa: 947,417 948,745 942,121 946,094

Grainloading (gr/dscf), cs: 0.0313 0.0338 0.0277 0.03

Emission Rate (lb/hour), E: 162.55 175.04 142.41 160.0

Percent Isokinetic Sampling (%), I: 99.13 100.72 100.25 100.03

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 2451.35 2462.58 2444.13 2452.69

Emission Rate (lbs/mmBtu), E: 0.07 0.07 0.06 0.07

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit 4 Gross Load (MW) 138 138 138 138

Average Unit 5 Gross Load (MW) 145 145 145 145

Average Sum Gross Load (MW) 283 283 283 283

Particulate Emission Results Summary

Plant Yates Units 4-5

Page 72 of 86 Att. 10
ATTACHMENT 11 - Yates Report 11 Test Results

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

Run 1 Run 2 Run 3

Test Date 2/24/2009 2/24/2009 2/24/2009

Run Start Time 14:00 15:50 17:20

Run End Time 15:25 17:05 18:30

Meter Volume (dacf), Vm: 41.809 40.325 40.862

Sqrt Delta P ("wc): 1.43 1.45 1.43

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.22 29.22 29.22

Delta H ("wc): 1.3 1.4 1.3

Volume in Impingers (mls), VIc: 72.8 67.7 68.1

Static Pressure ("wc), Pg: -2.60 -2.80 -2.80

Stack Pressure ("Hg), Ps: 29.03 29.01 29.01

Stack Temperature (F), Ts: 260 261 263

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: 61 66 69

Stack Diameter (inches): 209.53 209.53 209.53

Area Stack (sq. ft.), As: 239.45 239.45 239.45

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): 13.1 13.1 13.1

Percent O2 (% dry volume): 5.4 5.4 5.3

Percent (N2 + CO) (% dry volume): 81.5 81.5 81.5

Particulate Collected (mg), Mn: 22.9 41.2 37.1

Molec. Wt. Dry (lb/lb-mole), Md: 30.313 30.317 30.315

Volume Water (scf), Vwstd 3.427 3.187 3.205

Meter Volume (dscf), Vmstd: 41.345 39.489 39.795

Wet Fraction (v/v), Bws: 0.077 0.075 0.075

Molec. Wt. Wet (lb/lb-mole), Ms: 29.371 29.398 29.397

Stack Gas Sampled (acf), Vma: 62.897 60.116 60.692 Averages

Stack Gas Velocity (fps), Vs: 94.22 95.61 94.78 95

Volumetric Flowrate (dscfm), Qs: 889,842 902,355 892,833 895,010

Volumetric Flowrate (acfm), Qa: 1,353,702 1,373,679 1,361,667 1,363,016

Grainloading (gr/dscf), cs: 0.0086 0.0161 0.0144 0.01

Emission Rate (lb/hour), E: 65.30 124.48 110.12 100.0

Percent Isokinetic Sampling (%), I: 109.83 103.44 105.36 106.21

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 4039.95 4105.59 4079.73 4075.09

Emission Rate (lbs/mmBtu), E: 0.02 0.03 0.03 0.02

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit Gross Load (MW) 363 363 363 363

Particulate Emission Results Summary

Yates Unit 6

Page 73 of 86 Att. 11
ATTACHMENT 12 - Yates Report 12 Test Results

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

Run 1 Run 2 Run 3

Test Date 2/24/2009 2/24/2009 2-24=09

Run Start Time 14:00 15:50 17:20

Run End Time 15:25 17:05 18:30

Meter Volume (dacf), Vm: 40.082 38.579 39.572

Sqrt Delta P ("wc): 1.43 1.43 1.44

Sampling Time (min): 60 60 60

Barometric Pressure ("Hg), Pbar: 29.22 29.22 29.22

Delta H ("wc): 1.3 1.3 1.3

Volume in Impingers (mls), VIc: 59.0 56.8 57.7

Static Pressure ("wc), Pg: -2.60 -2.70 -2.70

Stack Pressure ("Hg), Ps: 29.03 29.02 29.02

Stack Temperature (F), Ts: 259 262 264

Meter Coefficient (no units), Y: 0.985 0.985 0.985

Pitot Coefficient (no units) Cp: 0.840 0.840 0.840

Meter OutletTemperature (F), Tm: 68 71 76

Stack Diameter (inches): 209.53 209.53 209.53

Area Stack (sq. ft.), As: 239.45 239.45 239.45

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 13.1

Percent O2 (% dry volume): 5.3 5.4 5.5

Percent (N2 + CO) (% dry volume): 81.7 81.6 81.5

Particulate Collected (mg), Mn: 54.8 68.9 54.8

Molec. Wt. Dry (lb/lb-mole), Md: 30.292 30.296 30.309

Volume Water (scf), Vwstd 2.777 2.674 2.716

Meter Volume (dscf), Vmstd: 38.650 36.981 37.631

Wet Fraction (v/v), Bws: 0.067 0.067 0.067

Molec. Wt. Wet (lb/lb-mole), Ms: 29.468 29.467 29.481

Stack Gas Sampled (acf), Vma: 58.124 55.884 56.997 Averages

Stack Gas Velocity (fps), Vs: 94.17 94.19 94.88 94

Volumetric Flowrate (dscfm), Qs: 899,604 895,476 899,949 898,343

Volumetric Flowrate (acfm), Qa: 1,352,892 1,353,205 1,363,107 1,356,401

Grainloading (gr/dscf), cs: 0.0219 0.0288 0.0225 0.02

Emission Rate (lb/hour), E: 168.82 220.69 173.20 187.6

Percent Isokinetic Sampling (%), I: 101.55 97.62 98.84 99.33

F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780

Heat Input (mmBtu/hour): 4119.48 4074.29 4077.03 4090.26

Emission Rate (lbs/mmBtu), E: 0.04 0.05 0.04 0.05

Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24

Average Unit Gross Load (MW) 365 364 363 364

Particulate Emission Results Summary

Yates Unit 7

Page 74 of 86 Att. 12
ATTACHMENT 13 - Yates Report 13 Test Results

Start 

Time

End 

Time

Unit 

Load

Avg. Econ. 

Gas Outlet 

CO 

Avg. Econ. 

Gas Outlet 

O2 

Avg. Econ. 

Gas Outlet 

CO2

Avg. Econ. 

Gas 

Outlet 

Temp

Military Military MW ppm % Dry % Dry Deg F 

2 Baseline 1 9/12/2008 9:36 10:03 362 90 3.35 15.37 666

3 Baseline 3 9/25/2008 8:05 8:41 366 64 4.31 14.73 670

4 Baseline 4 9/25/2008 11:45 12:21 364 72 4.3 14.66 672

5 Baseline 5 9/26/2008 7:25 8:01 361 128 3.43 15.32 665

6 Opt - 1 9/26/2008 9:40 10:16 361 77 3.17 15.58 666

7 Opt - 2 9/29/2008 11:29 12:05 362 67 3.93 14.91 670

8 Opt - 2 9/29/2008 14:06 14:42 365 32 4.51 14.37 675

9 Daily Baseline 9/30/2008 7:18 7:54 364 42 4.06 14.86 665

10 High NOx 9/30/2008 9:49 10:25 361 20 3.82 15.07 667

11 Low O2 9/30/2008 11:37 12:13 362 54 3.16 15.58 661

12 High O2 9/30/2008 14:12 14:48 363 69 4.36 14.48 670

13 Daily Baseline 10/1/2008 8:20 8:56 362 31 3.67 15.25 663

14 Increase Tilts 10/1/2008 9:42 10:18 368 38 3.6 15.37 667

15 Decrease Tilts 10/1/2008 11:21 11:57 361 33 3.62 15.33 661

16 VWO 10/1/2008 13:14 13:50 371 62 3.66 15.25 670

17 Temp vs. Load; E Mill off 10/1/2008 21:28 22:04 285 9 3.45 15.39 607

18 Mid Load; D&E Mills off 10/1/2008 23:18 23:54 238 8 3.62 15.26 573

19 Low Load; D&E Mills off 10/2/2008 0:40 1:16 201 15 3.85 15.04 544

20 Low Low Load; D&E Mills 

off

10/2/2008 1:59 2:35 160 9 4.07 14.87 510

SCR Baseline Test Results Summary

Yates Unit 6

Title 

of Run Description Date

Page 75 of 86 Att. 13
ATTACHMENT 14 - Yates Report 14 Test Results

Unit 6 Sorbent Injection Mercury Study (February 28, 2005 to March 22, 2005)

Table 8. Snap Shot Results from Constant Rate Injection Test at 6 lb/MMacf Injection.

ESP Inlet Hg ESP Outlet Hg Mercury

Date Point (μg/dNm^3, 3% O2) (μg/dNm^3, 3% O2) Capture

3/11/2005 15:45 11.4 (SCEM) 2.9 (SCEM) 75%

3/12/2005 9:20 (SCEM) 4.4 (SCEM) 66%

3/19/2005 14:00 11.2 (TE) 3.2 (STM) 71%

3/19/2005 14:00 11.2 (COAL) 3.2 (STM) 71%

3/19/2005 22:00 17.4 (TE) 2.1 (STM) 88%

SCEM Value obtained by semi-continuous emission monitor

TE Value obtained by Thermo Electron, corrected to dry conditions

STM Value obtained by sorbent trap method

COAL Value obtained by coal analysis

Table 9. STM Results for the Constant Rate Injection Test, ESP A Outlet, 6 lb/MMacf

Result

Date Run (μg/Nm^3, 3% O2)

3/19/2005 1A 3.28

3/19/2005 1B 3.14

3/19/2005 2A 2.03

3/19/2005 2B 2.15

3/20/2005 3A 0.38

3/20/2005 3B 0.37

3/20/2005 4A 0.82

3/20/2005 4B 0.9

3/21/2005 5A 1.69

3/21/2005 5B 1.85

3/21/2005 6A 1.5

3/21/2005 6B 1.59

Table 15 Baseline Condition Method 17 Particulate Measurement Results

Date 3/2/2005 Run 1 Run 2 Run 3

Unit Load MW 360 360 360

gr/dscf 0.0394 0.038 0.038

lb/MMBtu 0.0853 0.0817 0.0604

gr/dscf 0.0385

lb/MMBtu 0.0758

Table 16 Maximum Injection Condition Method 17 Particulate Measurement Results

Date 3/8/2005 Run 1 Run 2 Run 3

Unit Load MW 360 360* 360

gr/dscf 0.0328 0.025 0.0237

lb/MMBtu 0.071 0.0544 0.052

gr/dscf 0.0272

lb/MMBtu 0.0592

* Unit load started to decrease near the end of the test.

PM Emissions

Average

PM Emissions

Average

Page 76 of 86 Att. 14
ATTACHMENT 15 - Yates Report 15 Test Results

DRAFT Unit 1 Boiler Chemical Addition Mercury Study (October 31, 2007 to November 7, 2007)

Table 4. Calcium Chloride Injection Testing Outline

6-Nov 886 240-550 91-113 36.6

Table 10. Comparison of Ontario Hydro and SCEM Results at ESP Outlet

BL 1-Nov 9:45 11:45 9.6 3.7 61 9.3 4.3 54 -3% 14%

BL 1-Nov 12:15 14:15 9.4 3.7 61 7.9 4.3 46 -18% 15%

BL 1-Nov 14:40 16:40 10.3 4.3 58 11 4.1 63 7% -6%

Br (370) 3-Nov 13:30 15:30 7.9 2 74 1 0.7 37 -153% -102%

Br (370) 3-Nov 16:10 18:10 8 2 75 0.3 0.4 -43 -186% -132%

Br (100) 4-Nov 13:45 15:15 7.8 2.9 63 2.5 0.6 77 -102% -133%

Br (100) 4-Nov 15:45 17:15 7.5 2.8 63 3.2 1.9 40 -81% -39%

Cl (240-550) 6-Nov 15:45 17:45 9.2 3 67 4 2.2 46 -79% -33%

* BL = baseline (no bromide injection); Br = calcium bromide injection at ppm Br in coal dry basis, stated in parentheses; Cl = calcium chloride 

injection at ppm Cl in coal dry basis, stated in parentheses.

Total Hg Elem. Hg

OH Results – ESP Outlet % RD

Elem. Hg 

(μg/Nm3) % Oxid.

Total Hg 

(μg/Nm3) % Oxid.

Date in 

2007

Measured 

Coal Conc. 

(ppm Cl, 

dry)

Actual 

CaCl2 

Injection 

rate (ppm 

Cl in coal, 

dry)

Theoretical 

Gas Conc. 

(ppmv Cl, 

dry 3% O2)

Measured 

Gas Conc. 

(ppmv HCl, 

dry 3% O2)

Condition*

Date in 2007 Start Time End Time

Elem. Hg 

(μg/Nm3)

SCEM Results - ESP Outlet

Total Hg 

(μg/Nm3)

Page 77 of 86 Att. 15
ATTACHMENT 15 - Yates Report 15 Test Results

Table 11. Comparison of Sorbent Tube, OH and SCEM Results at ESP Outlet

ST OH URS SCEM

0 1-Nov 9:45 11:45 10.1 9.6 9.3 -5.1 -7.7

0 1-Nov 12:25 14:25 9.9 9.4 8.2 -5.5 -18.8

0 1-Nov 14:40 16:40 10 10.3 11 2.7 9.4

370 3-Nov 13:30 15:30 7.8 7.9 1 1.1 -152.6

370 3-Nov 16:10 18:10 7.9 8 0.3 1.4 -186.9

Table 12. Comparison of Ontario Hydro and Thermo CEM Results at ESP Outlet

BL 1-Nov 9:45 11:45 9.6 3.7 61 9.8 5.3 46 2% 34%

BL 1-Nov 12:15 14:15 9.4 3.7 61 9.6 5.1 48 5% 34%

BL 1-Nov 14:40 16:40 10.3 4.3 58 11 6.1 45 7% 35%

Br (370) 3-Nov 13:30 15:30 7.9 2 74 7.3 0.8 89 -8% -89%

Br (370) 3-Nov 16:10 18:10 8 2 75 10.9 2 82 31% -3%

Br (100) 4-Nov 13:45 15:15 7.8 2.9 63 10.6 2.2 79 31% -27%

Br (100) 4-Nov 15:45 17:15 7.5 2.8 63 6.7 3.5 48 -11% 23%

Cl (240-550) 6-Nov 15:45 17:45 9.2 3 67 9.1 2.2 75 -2% -30%

* BL = baseline (no bromide injection); Br = calcium bromide injection at ppm Br in coal, stated in parentheses; Cl = calcium chloride injection 

at ppm Cl in coal, stated in parentheses.

OH Results – ESP Outlet Thermo CEM Results-ESP Outlet % RSD

Total Hg 

(μg/Nm3)

Elem. Hg 

(μg/Nm3) % Oxid.

Total Hg 

(μg/Nm3)

Elem. Hg 

Condition

(μg/Nm3) % Oxid. Total Hg Elem. Hg *Date in 2007 Start Time End Time

Br 

Injection 

Rate 

(ppm in 

coal)

Date in 

2007 Start Time End Time

Between 

OH and 

ST

Between 

SCEM and ST

% RSD

Total Hg 

(μg/dNm3 

at 3% O2)

Total Hg 

(μg/dNm3 at 3% 

O2)

Total Hg 

(μg/dNm3 at 

3% O2)

Page 78 of 86 Att. 15
ATTACHMENT 15 - Yates Report 15 Test Results

Table 13. Comparison of Sorbent Tube and Thermo CEM Results at JBR Outlet

ST Thermo CEM % RSD

BL 4-Nov 9:12 10:42 5.3 2.4 -75

BL 4-Nov 11:15 12:45 5.9 2.8 -71

Br (100) 4-Nov 13:45 15:15 4.5 2.8 -47

BL 5-Nov 8:07 9:37 5.3 1.8 -99

BL 5-Nov 10:06 11:36 6.3 3 -71

Br (260) 5-Nov 15:20 16:50 4.8 3.4 -34

BL 6-Nov 8:00 9:30 5.5 2.9 -62

BL 6-Nov 9:53 11:23 4.1 2.4 -52

Cl (240-550) 6-Nov 14:15 15:15 4 2 -67

Cl (240-550) 6-Nov 15:45 17:45 3.8 2 -62

BL 7-Nov 7:52 9:22 4 1.8 -76

BL 7-Nov 9:43 11:13 4.2 1.8 -80

Br (220) 7-Nov 11:45 14:45 3.3 2.6 -24

* BL = baseline (no bromide injection); Br = calcium bromide injection at ppm Br in coal dry basis, stated in parentheses; Cl = calcium chloride

injection at ppm Cl in coal dry basis, stated in parentheses.

Total Hg 

(μg/dNm3 

at 3% O2)

Total Hg 

(μg/dNm3 at 3% 

O2)

Between 

CEM and ST

Condition

*

Date in 

2007 Start Time End Time

Page 79 of 86 Att. 15
ATTACHMENT 15 - Yates Report 15 Test Results

Table 14. Total and Oxidized Flue Gas Mercury Concentrations (dry, at 3% O2) Measured by SCEM during Baseline Conditions

Ave. Tot. Hg

Ave. Elem 

Hg Ave. Tot. Hg

Ave. Elem 

Hg

Ave. Tot. 

Hg

Ave. Elem 

Hg

(μg/Nm3) (μg/Nm3) (μg/Nm3) (μg/Nm3) (μg/Nm3) (μg/Nm3)

1-Nov 8:52 20:47 10.2 3.7 64 10.5 7.6 28 8.3 4.2 50

2-Nov 7:47 13:23 12.1 6.7 45 10.1 7.1 30 6.5 3.3 49

3-Nov 8:08 12:56 11.7 6.9 41 9.2 4.5 51 6.3 3.9 38

4-Nov 7:06 13:14 - 9.2* - 11.5 6.4 44 7.8 2.2 72

5-Nov 8:19 12:37 12.8 7 45 8.5 6 29 7.1 3.5 51

6-Nov 8:18 12:30 8.9 6.1 31 10.5 5.4 49 4.3 2.8 35

7-Nov 7:50 11:13 10.3 7 32 8.2 4.1 50 8.2 4.6 44

11/1-11/7 11 6.2 43 9.8 6.1 38 7.7 3.6 53

*Note values were not used in average for 11/1 through 11/7.

End Time % Hg Oxid. % Hg Oxid. % Hg Oxid.

AH Inlet AH Outlet ESP Outlet

Date in 

Nov. 2007 Start Time

Page 80 of 86 Att. 15
ATTACHMENT 15 - Yates Report 15 Test Results

Table 15. Mercury Measurements Across the JBR Scrubber at Baseline.

ST Thermo CEM

8:52 20:47 8.3 4.2 no data no data no data 4.6

9:45 11:45 9.3 4.3 9.6 3.7 no data 4.3

12:15 14:15 7.8 4.3 9.4 3.6 no data 4.8

14:40 16:40 11 4 10.3 4.3 no data 4.8

2-Nov 7:47 13:23 6.5 3.3 no data no data no data 4.4

3-Nov 8:08 12:56 6.3 3.9 no data no data no data 3.8

7:06 13:14 7.8 2.2 no data no data no data 2.5

9:12 10:42 no data no data no data no data 5.2 2.6

11:15 12:45 7.8 no data no data no data 5.9 2.9

8:19 12:37 7.1 3.5 no data no data no data 2.7

8:07 9:37 no data 2.8 no data no data 5.3 1.9

10:06 11:36 7.1 4.1 no data no data 6.3 3.1

8:18 12:30 4.3 2.8 no data no data no data 2.5

8:00 9:30 no data 3.2 no data no data 5.5 2.9

9:53 11:23 4.3 2.6 no data no data 4.1 2.6

7:50 11:13 8.2 4.6 no data no data no data 1.8

7:52 9:22 no data 4.2 no data no data 4 1.8

9:43 11:13 8.2 4.6 no data no data 4.2 2.2

7-Nov

ESP Outlet 

Hg°

JBR 

Outlet 

Date Start Time HgT

JBR Outlet 

HgT

1-Nov

4-Nov

5-Nov

6-Nov

End Time

ESP Outlet 

HgT

ESP Outlet 

Hg°

ESP Outlet 

HgT

URS SCEM OH

Page 81 of 86 Att. 15
ATTACHMENT 16 - Yates Report 16 Test Results

Unit 1 Sorbent Injection for Small ESP Mercury Control (January 2005)

Table 3-19. Unit 1- Method 26A Data at ESP Outlet for Baseline Characterization Tests

Carbon Injection Rate HCl HF

(lb/hr) (ppmv) (ppmv)

Baseline 25.71 12.73

Table 3-19. Unit 1- Method 26A Data at ESP Outlet for Baseline Characterization Tests

Carbon Injection Rate HCl HF

(lb/hr) (ppmv) (ppmv)

143 18.71 13.31

200 17.95 12.02

All concentrations corrected to 3% O2.

Page 82 of 86 Att. 16
ATTACHMENT 17 - Yates Report 17 Test Results

Unit 1 Field Testing of a Wet FGD Additive for Enhanced Mercury Control (May 15, 2007 to Sept 27, 2007)

Table 39. JBR Mercury Removal Data, by SCEM and CEM during the May 2007 TMT-15 Additive Portion of the Test Program

Total Hg Hgo

5/15/2007 6:00-17:00 0 (baseline) 5.7 1.5 2.4 26 57 (assumed 23

5/18/2007 8:00-16:00 20 7.6 2.1 3.2 28 57 (assumed 21

5/24/2007 6:00-20:00 40 7.4 1.7 3.2 23 36 (assumed 53

5/29/2007 4:00-14:00 40 3.9 1.1 4.7 29 -8.2 (assumed 112

Table 40. Results of Ontario Hydro Measurements During TMT-15 Test at Yates Unit 1

(mean values for three Ontario Hydro runs +/- 95% confidence interval about the mean)

JBR Inlet Stack JBR Inlet Stack * Stack **

3.6 +/- 0.6 4.6 +/- 0.2 4.7 +/- 0.7 8.9 +/- 2.9 7.5 +/- 0.9

3.4 +/- 0.7 0.2 +/- 0.1 4.8 +/- 0.2 0.7 +/- 0.2 0.5 +/- 0.1

7.0 +/- 0.4 4.8 +/- 0.2 9.5 +/- 0.5 9.6 +/- 3.1 8.0 +/- 0.9

52 +/- 9 49 +/- 5

95% +/- 2% 87% +/- 5% 89% +/- 1%

1.0 +/- 0.7 4.2 +/- 2.7 3.0 +/- 1.9

29% +/- 17% 88% +/- 59% 60% +/- 34%

31% +/- 6% -1% +/- 31% 15% +/- 16%

* Results including apparent outlier value for one of three runs

** Results for two runs, excluding apparent outlier value for one of three runs

Overall Hg Removal across Absorber, %

Hg+2, μg/Nm^3 @ 3%O2

Total Hg, μg/Nm^3 @ 3%O2

Mercury Oxidation at JBR Inlet, %

Hg+2 Removal across Absorber, %

Hgo Re-emissions, % of JBR inlet Hg+2

Hgo Re-emissions across Absorber, μg/Nm^3 

Hgo, μg/Nm^3 @ 3%O2

Hg Oxidation 

at Inlet, %

Total Hg 

Removal 

by FGD, %

Hg+2 

Capture 

by FGD, %

Hgo Reemission, % 

of inlet 

Hg+2

Condition

Baseline

5/15/2007

With TMT-15 @ 40 mL/ton coal

5/24/2007

Date Time Averaged

TMT-15 Dose 

Rate, mL/ton 

of coal fired

JBR Inlet Hg, μg/Nm^3 @ 

3%O2

JBR Outlet 

Total Hg, 

μg/Nm^3 

@3% O2

Page 83 of 86 Att. 17
ATTACHMENT 17 - Yates Report 17 Test Results

Table 45. JBR Mercury Removal Data, by SCEM and CEM during the August and September 2007 Nalco 8034 Additive Portion of the Test Program

Total Hg HgoTotal Hg Hgo

8/28/2007 10:00-21:00 0 4.6 2.4 2.9 2.8 53 36 94 18

9/8/2007 6:00-16:00 875 3.8 2.0 3.5 4.0 51 9 132 113

9/18/2007 6:00-20:00 525 5.7 1.5 3.1 2.4 27 46 84 22

9/26/2007 11:00-21:00 525 6.4 2.2 3.8 3.6 35 41 96 33

Table 46. Results of Ontario Hydro Measurements During Nalco 8034 Test at Yates Unit 1

(mean values for three Ontario Hydro runs +/- 95% confidence interval about the mean)

JBR Inlet Stack JBR Inlet * Stack *

3.7 +/- 0.9 4.2 +/- 1.1 4.5 +/- 0.3 5.0 +/- 0.3

2.9 +/- 0.3 < 0.3 3.4 +/- 0.3 < 0.5

6.6 +/- 1.2 4.2 +/- 1.1 8.0 +/- 0.1 5.0 +/- 0.3

56 +/- 4 56 +/- 5

>90% >86%

0.5 +/- 0.9 0.5 +/- 0.1

18% +/- 32% 15% +/- 1%

36% +/- 13% 38% +/- 4%

* Results for two runs, excluding apparent outlier value for one of three runs

Hgo Re-emissions, % of JBR inlet Hg+2

Overall Hg Removal across Absorber, %

JBR Outlet Total Hg, 

μg/Nm^3 @3% O2

With Nalco 8034 @ 525 g/g FGD Inlet Hg+2

9/18/2007

Hgo, μg/Nm^3 @ 3%O2

Hg+2, μg/Nm^3 @ 3%O2

Total Hg, μg/Nm^3 @ 3%O2

Mercury Oxidation at JBR Inlet, %

Hg+2 Removal across Absorber, %

Hgo Re-emissions across Absorber, μg/Nm^3 

Total Hg 

Removal 

by FGD, %

Hg+2 

Removal by 

FGD, %

Hgo Reemission, %

Condition

Baseline

8/28/2007

JBR Inlet Hg, μg/Nm^3 @ 

3%O2

Date Time Averaged

Nalco 8034, 

g/g FGD Inlet 

Hg +2

Hg 

Oxidation 

at Inlet, %

Page 84 of 86 Att. 17
ATTACHMENT 18 - Yates Report 18 Test Results

Unit 1 Multi-Method Mercury Speciation Testing (March 15, 2006 to March 21, 2006)

Table 1-2 Mercury overviews at FGD Inlet

OHM SCEM Drift from OHM SCEM Drift from Appendix K Drift from

Hg(0) Hg(0) OHM Hg(T) Hg(T) OHM Hg(T) OHM

Date Condition μg/Nm^3 μg/Nm^3 % μg/Nm^3 μg/Nm^3 % μg/Nm^3 %

High load 6.05 6.10 0.4% 14.03 11.35 10.5% 11.60 9.5%

High load 6.20 6.20 0.0% 12.77 10.80 8.3%

3/16/2006 Low load 2.32 2.61 5.8% 8.26 8.50 1.4% 7.98 1.7%

Low load 2.38 2.78 7.8% 8.86 9.19 1.8%

Low load 2.40 3.03 11.6% 9.60 9.54 0.3%

High load 3.41 3.98 7.7% 8.05 6.32 12.0% 9.28 4.5%

High load 4.17 5.00 9.1% 9.79 7.96 10.3%

High load 5.48 5.81 2.9% 12.65 11.37 5.3%

High load 3.74 4.45 8.7% 8.87 9.16 1.6% 7.73 1.8%

High load 3.15 4.06 12.6% 7.39 8.56 7.3%

High load 3.53 4.05 6.9% 7.78 8.77 6.0%

High load 4.96 4.26 7.6% 9.62 9.87 1.3% 8.82 2.8%

High load 4.65 4.89 2.5% 9.36 9.88 2.7%

High load 4.67 4.51 1.8% 8.98 9.85 4.6%

3/15/2006

3/17/2006

3/18/2006

3/20/2006

3/21/2006

Page 85 of 86 Att. 18
ATTACHMENT 18 - Yates Report 18 Test Results

Table 1-3 Mercury overviews at FGD Inlet

OHM SCEM Drift from OHM SCEM Drift from Appendix K Drift from

Hg(0) Hg(0) OHM Hg(T) Hg(T) OHM Hg(T) OHM

Date Condition μg/Nm^3 μg/Nm^3 % μg/Nm^3 μg/Nm^3 % μg/Nm^3 %

High load 4.17 4.94 8.5% 4.75 6.09 12.4% 4.47 3.0%

High load 4.13 4.59 5.3% 4.96 5.42 4.4%

3/16/2006 Low load 1.97 2.40 9.8% 2.77 2.98 3.7% 2.06 14.7%

Low load 2.06 2.40 7.6% 3.16 2.77 6.6%

Low load 2.04 2.64 12.7% 2.36 2.88 9.9%

High load 3.25 2.78 7.8% 3.50 3.40 1.4% 4.23 0.7%

High load 3.78 3.33 6.4% 3.93 3.15 11.0%

High load 4.80 3.44 16.4% 5.08 3.81 14.3%

High load 3.84 4.16 4.0% 4.17 3.81 4.5% 3.47 9.2%

High load 3.40 3.96 7.6% 3.67 3.92 3.3%

High load 3.85 4.22 4.6% 4.01 4.04 0.4%

High load 4.36 4.00 4.4% 4.64 4.56 0.9% 4.36 2.1%

High load 4.29 4.45 1.8% 4.50 4.65 1.6%

High load 4.33 4.04 3.5% 4.51 4.17 3.9%

Table 1-8 HCl measurement at the stack

HCl

Time Date mg/NM^3

13:15-15:20 3/16/2006 1.06

14:20-16:20 3/17/2006 0.57

0.82

13:15-15:20 3/16/2006 0.65

14:20-16:20 3/17/2006 0.35

Average 0.50

3/15/2006

3/17/2006

3/18/2006

3/20/2006

3/21/2006

Average

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