Process Information

1 Name of legal owner of facility:

Alabama Power Company owns Unit 5. Southern Electric Generating Company owns Units 1-4.

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

Alabama Power Company

3 Address of ____ legal owner or _X__ operator:

600 North 18th Street

Birmingham, AL 35291-0830

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):

E C Gaston

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):

Plant Code - 26

5 Complete street address of facility (physical location):

31972 Highway 25 N

Wilsonville, AL 35186

6 Provide mailing address if different:

600 North 18th Street

Birmingham, AL 35291-0830

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

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

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

_X__ 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)

Note: These are the anticipated fuels; however, the permit and design are not necessarily restricted to these fuels.

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 (% _____)

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").
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 (% _____)

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.

1

 The permitting agency allowed this fuel to be combusted for special testing and research purposes.

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 _X__ Neither

Explain: Until the regulations are finalized, we cannot determine with certainty whether we would use the other materials.

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").

457.5 tons

Quantity/year

110,000 gallons

9,000 gallons used oil-contaminated 

waste was burned; no used oil was 

burned

Other Material

Boiler cleaning wastes that are not 

hazardous as defined in 40 CFR Part 

261, Subpart B and ADEM Admin. 

Code R. 335-14-2 may be combusted 

in these units for energy recovery.

Used oil that is not hazardous waste 

as defined in 40 CFR Part 279 and 

ADEM Admin. Code R. 335-14-17, 

and which is generated at Alabama 

Power facilities in the state of 

Alabama may be combusted for 

energy recovery. This includes nonhazardous waste residue that is 

contaminated with used oil and used 

oil that is generated by Alabama 

Power employees who are 

household used oil generators.

Biomass (wood chips)

Actually burn

Yes

Yes

Yes

Permitted to burn

Yes

Yes

No1
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. Boiler ID

6

Original design fuel (i.e., 

coal rank or type of oil)

Design heat input, 

(MMBtu/hr)

7

Present maximum heat 

input, (MMBtu/hr)

8

MWe Gross capacity

summer

MWe Net Capacity

summer

Original design gross 

efficiency (%, HHV)

Present operating gross 

efficiency (%, HHV)

Design steam pressure 

(psig)

Operating steam pressure 

(psig)

Design steam temperature 

(

oF)

temperature (Operating steam 

oF)

Design steam reheat 

temperature (

oF)

9

Operating steam reheat 

temperature (

oF)10

Fuel11

Hours/year operated12

Average annual capacity 

factor for the past 3 years

Applicable NSPS

Estimated year of 

retirement13

1 bituminous CBI CBI 270 254 89.66 87.9 2000 1954 1000 1000 1000 947 bituminous coal, 

No. 2 fuel oil, used 

oil-contaminated 

waste

CBI CBI none not 

available

2 bituminous CBI CBI 270 256 89.66 88.63 2000 2001 1000 1000 1000 995 bituminous coal, 

No. 2 fuel oil, used 

oil-contaminated 

waste, boiler 

cleaning waste

CBI CBI none not 

available

3 bituminous CBI CBI 270 254 89.66 N/A 2000 2003 1000 998 1000 992 bituminous coal, 

No. 2 fuel oil, 

biomass, used oilcontaminated 

waste, boiler 

cleaning waste

CBI CBI none not 

available

4 bituminous CBI CBI 270 256 89.66 88.87 2000 1990 1000 1000 1000 986 bituminous coal, 

No. 2 fuel oil, used 

oil-contaminated 

waste

CBI CBI none not 

available

5 bituminous CBI CBI 884 842 88.7 N/A 3500 3500 1000 1000 1000 986 bituminous coal, 

No. 2 fuel oil, used 

oil-contaminated 

waste

CBI CBI none not 

available

NOTES

"N/A" means not available.

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. See also text to previous response (Part I, No. 11), which indicates that 

the design fuel simply means the fuel for which the boiler is optimized to operate at maximum possible efficiency, but that the boiler was designed to handle and burn a range of fuels.

MWe Gross Capacity Summer. Identifies the gross normal full load as of May 2009. Alabama Power does not change unit capacities from season to season.

MWe Net Capacity Summer. Identifies the net normal full load as of May 2009; taken directly from the 2009 installed and authorized document. Alabama Power does not change unit capacities from season to season.

Original design gross efficiency (%, HHV). Taken directly from the original contract boiler data sheet.

Present operating gross efficiency (%, HHV). 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 (psig). Based on the thermal design of the unit as represented on the turbine heat balance sheet.

Operating steam pressure (psig). 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).

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

Retirement. Alabama Power has not committed to actual retirement dates for Gaston Units 1 - 5. Alabama 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.

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.
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.):

Boiler ID14 Type15 NOx control16 SO2 control17 PM control18 Other control19

1 wall-fired (2) low-NOx burners 

(11/19/1994)

N/A (1) flue gas conditioning - 

sodium injection1 (prior to 

1994)

(3) cold-side ESP was originally 

installed (05/01/1960) but was 

de-energized when a hot-side 

ESP was installed (04/1974)

N/A

2 wall-fired (2) low-NOx burners 

(04/07/1992)

N/A (1) flue gas conditioning - 

sodium injection1 (prior to 

1994)

(3) cold-side ESP was originally 

installed (07/01/1960) but was 

de-energized when a hot-side 

ESP was installed (04/1975)

(4) baghouse (06/06/1999)

N/A

3 wall-fired (2) low-NOx burners 

(05/23/1993)

N/A (1) flue gas conditioning - 

sodium injection1 (prior to 

1994)

(3) cold-side ESP was originally 

installed (06/01/1961) but was 

de-energized when a hot-side 

ESP was installed 

(12/10/1973)

(4) baghouse (12/20/1996)

N/A

4 wall-fired (2) low-NOx burners 

(05/21/1994)

N/A (1) flue gas conditioning - 

sodium injection1 (prior to 

1994)

(3) cold-side ESP was originally 

installed (06/01/1962) but was 

de-energized when a hot-side 

ESP was installed 

(10/15/1972)

N/A
Boiler ID14 Type15 NOx control16 SO2 control17 PM control18 Other control19

5 tangentially-fired (1) low-NOx burners + 

separated OFA (12/19/1993)

(4) SCR (04/29/2006) - the SCR 

uses a titania-vanadia based 

ceramic catalyst and 

anhydrous ammonia as the 

reductant; the catalyst is 

designed to minimize SO3 

formation2

(6) calcium-based wet flue gas 

desulfurization (03/05/2010)

(2) dual-injection trona, 

injection point #1 

(03/05/2010)

(3) hot-side ESP (08/02/1974)

(5) dual-injection trona, 

injection point #2 [SO3] 

(03/05/2010)

Note: "N/A" means not applicable.

1

 Sodium injection on Units 1 - 4 has varied between sodium sulfate and sodium carbonate. Units 1 - 4 still have the capability for sodium injection, but the 

 plant has not used it in several years.

2

 When making catalyst decisions, the primary goal is to achieve the desired NOx performance, with a secondary goal of minimizing SO3 formation.

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

new installation. Also include any pollutants controlled by this technology (e.g., control technology [pollutant controlled]).
17 For each boiler noted in Part I, question 15, provide the company (prime vendor) name and company contact information for each

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

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

etc.).

Name Telephone Address

1 N/A N/A N/A N/A

2 N/A N/A N/A N/A

3 N/A N/A N/A N/A

4 N/A N/A N/A N/A

5 N/A N/A N/A N/A

Note: "N/A" means 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
18 For the control technologies identified in Part I, question 17, provide the date of actual start-up of the demonstration (if the control

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

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

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

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

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

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

Boiler ID22

Demonstration 

activity actual startup date

Demonstration 

activity projected 

start-up date

Demonstration 

activity end-date or 

projected end-date

Type of control (e.g., 

sorbent and type; 

chemical additive23)

Desired HAP emission 

reduction (%) or 

emission rate

Coal rank(s) in use

1 N/A N/A N/A N/A N/A N/A

2 N/A N/A N/A N/A N/A N/A

3 N/A N/A N/A N/A N/A N/A

4 N/A N/A N/A N/A N/A N/A

5 N/A N/A N/A N/A N/A N/A

Note: "N/A" means 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.
19 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 provide a non-demonstration, full-scale operating system.

Name Telephone Address

1 N/A N/A N/A N/A

2 N/A N/A N/A N/A

3 N/A N/A N/A N/A

4 N/A N/A N/A N/A

5 N/A N/A N/A N/A

Note: "N/A" means 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
20 For the control technologies identified in Part I, question 19, provide the date of actual start-up (if the control is currently operating), the

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

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

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

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

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

"inlet" and "outlet" are).

Boiler ID25 Actual start-up date Expected or projected 

start-up date

Type of control (e.g., 

sorbent and type; 

chemical additive)26

Guaranteed HAP 

emission reduction 

(%) or emission rate

Sorbent or additive 

feed rate on which 

guarantee is based

Coal rank(s) upon 

which guarantee is 

based

1 N/A N/A N/A N/A N/A N/A

2 N/A N/A N/A N/A N/A N/A

3 N/A N/A N/A N/A N/A N/A

4 N/A N/A N/A N/A N/A N/A

5 N/A N/A N/A N/A N/A N/A

Note: "N/A" means 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.
21 For each boiler noted in Part I, question 15, provide the following information:

PM28 PM10

(29) PM2.5(30) SO2

HCl and/or 

HF

HCN

Metal 

HAP31 Hg CO

Other 

organics 

(specify)

Other 

pollutant 

(specify)

1 0.12 lb/MMBtu

(Title V permit; annual 

Reference Method 5 or 

17)

N/A N/A 3.8 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A N/A

2 0.12 lb/MMBtu

(Title V permit; annual 

Reference Method 5 or 

17)

N/A N/A 3.8 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A N/A

3 0.12 lb/MMBtu

(Title V permit; annual 

Reference Method 5 or 

17)

N/A N/A 3.8 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A N/A

4 0.12 lb/MMBtu

(Title V permit; annual 

Reference Method 5 or 

17)

N/A N/A 3.8 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A N/A

5 0.12 lb/MMBtu

(Title V permit; annual 

Reference Method 5 or 

17)

N/A N/A 3.8 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

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

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

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

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

Also include the compliance test method utilized.

29 List the compliance test method utilized.

30 List the compliance test method utilized.

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

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

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

Boiler ID27
22 For each boiler noted in Part I, question 15, provide the following information:

PM33 PM10 PM2.5 SO2 HCl and/or HF HCN Metal HAP34 Hg CO

Other organics 

(specify)

Other 

pollutant 

(specify)

1

ESP: 99.3% collection 

efficiency guarantee 

(expired in 1974)

N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

2

baghouse: 0.005 gr/dscf 

(expired in 1999)

N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

3

baghouse: 0.005 gr/dscf 

(expired in 1997)

N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

4

ESP: 0.10 lb/MMBtu, 

filterable (expired in 2009)

N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

5

ESP: 0.06 lb/MMBtu, 

filterable (expired in 2006); 

FGD: CBI

N/A N/A FGD: 98% 

instantaneous removal 

efficiency to meet a 

95% 30-day rolling 

average removal 

efficiency1

N/A N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

1

 These values are not vendor guaranteed rates, but are the performance expectations for the FGD provided by our internal engineering group. Like vendor guarantees, these performance expectations are 

 dependent on specific operating conditions. 

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

PM36 PM10 PM2.5 SO2

HCl 

and/or 

HF

HCN

Metal 

HAP37 Hg CO

Other 

organics 

(specify)

1 Emission tests for particulate matter will be conducted 

annually. Consecutive tests will not be conducted sooner than 

six months apart or later than eighteen months apart unless 

approved by the Director. Results will be reported to the 

Director within thirty days of completion of testing. The 

Director must be notified at least ten days in advance of all 

emission tests that will be conducted submitted as proof of 

compliance with ADEM Rules and Regulations. Submission of 

an annual particulate matter testing schedule with periodic 

updates as changes occur will satisfy the 10-day notification 

requirement.

All records must be maintained for 5 years.

N/A N/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

be operated, maintained, and certified using 40 CFR Part 75 

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

these units, using pounds per million Btu computed on a 24-

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours or 2 working days of such deviations, including those 

attributable to upset conditions as defined in the permit. The 

report will include the probable cause of said deviations, and 

any corrective actions or preventative measures that were 

taken.

All records must be maintained for 5 years.

N/A N/A N/A N/A N/A N/A

2 Emission tests for particulate matter will be conducted 

annually. Consecutive tests will not be conducted sooner than 

six months apart or later than eighteen months apart unless 

approved by the Director. Results will be reported to the 

Director within thirty days of completion of testing. The 

Director must be notified at least ten days in advance of all 

emission tests that will be conducted submitted as proof of 

compliance with ADEM Rules and Regulations. Submission of 

an annual particulate matter testing schedule with periodic 

updates as changes occur will satisfy the 10-day notification 

requirement.

All records must be maintained for 5 years.

N/A N/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

be operated, maintained, and certified using 40 CFR Part 75 

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

these units, using pounds per million Btu computed on a 24-

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours or 2 working days of such deviations, including those 

attributable to upset conditions as defined in the permit. The 

report will include the probable cause of said deviations, and 

any corrective actions or preventative measures that were 

taken.

All records must be maintained for 5 years.

N/A N/A N/A N/A N/A N/A

3 Emission tests for particulate matter will be conducted 

annually. Consecutive tests will not be conducted sooner than 

six months apart or later than eighteen months apart unless 

approved by the Director. Results will be reported to the 

Director within thirty days of completion of testing. The 

Director must be notified at least ten days in advance of all 

emission tests that will be conducted submitted as proof of 

compliance with ADEM Rules and Regulations. Submission of 

an annual particulate matter testing schedule with periodic 

updates as changes occur will satisfy the 10-day notification 

requirement.

All records must be maintained for 5 years.

N/A N/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

be operated, maintained, and certified using 40 CFR Part 75 

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

these units, using pounds per million Btu computed on a 24-

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours or 2 working days of such deviations, including those 

attributable to upset conditions as defined in the permit. The 

report will include the probable cause of said deviations, and 

any corrective actions or preventative measures that were 

taken.

All records must be maintained for 5 years.

N/A N/A N/A N/A N/A N/A

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

Boiler ID35
PM36 PM10 PM2.5 SO2

HCl 

and/or 

HF

HCN

Metal 

HAP37 Hg CO

Other 

organics 

(specify)

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

Boiler ID35

4 Emission tests for particulate matter will be conducted 

annually. Consecutive tests will not be conducted sooner than 

six months apart or later than eighteen months apart unless 

approved by the Director. Results will be reported to the 

Director within thirty days of completion of testing. The 

Director must be notified at least ten days in advance of all 

emission tests that will be conducted submitted as proof of 

compliance with ADEM Rules and Regulations. Submission of 

an annual particulate matter testing schedule with periodic 

updates as changes occur will satisfy the 10-day notification 

requirement.

All records must be maintained for 5 years.

N/A N/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

be operated, maintained, and certified using 40 CFR Part 75 

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

these units, using pounds per million Btu computed on a 24-

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours or 2 working days of such deviations, including those 

attributable to upset conditions as defined in the permit. The 

report will include the probable cause of said deviations, and 

any corrective actions or preventative measures that were 

taken.

All records must be maintained for 5 years.

N/A N/A N/A N/A N/A N/A

5 Emission tests for particulate matter will be conducted 

annually. Consecutive tests will not be conducted sooner than 

six months apart or later than eighteen months apart unless 

approved by the Director. Results will be reported to the 

Director within thirty days of completion of testing. The 

Director must be notified at least ten days in advance of all 

emission tests that will be conducted submitted as proof of 

compliance with ADEM Rules and Regulations. Submission of 

an annual particulate matter testing schedule with periodic 

updates as changes occur will satisfy the 10-day notification 

requirement.

All records must be maintained for 5 years.

N/A N/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

be operated, maintained, and certified using 40 CFR Part 75 

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

these units, using pounds per million Btu computed on a 24-

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours or 2 working days of such deviations, including those 

attributable to upset conditions as defined in the permit. The 

report will include the probable cause of said deviations, and 

any corrective actions or preventative measures that were 

taken.

All records must be maintained for 5 years.

N/A N/A N/A N/A N/A N/A

Note: "N/A" means 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.
25 For the control technologies identified in Part I, questions 17 and 19, provide the cost information requested.38

Facility Name/Unit No.: N/A

Retrofit to existing boiler? 

Installation on a new boiler?

Total Capital Investment: $ -

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

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

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

No.

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

Note: "N/A" means not applicable.
Fuel Analysis39

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

E C Gaston

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

Plant Code - 26

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

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

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

7,565 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.45 13.30 12,982

7,722 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 12.78 12,972

7,641 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 14.20 12,906

7,514 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 14.05 12,827

7,625 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.89 12,843

7,655 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.61 13,069

7,555 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.57 12.30 13,210

7,544 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.24 12,944

7,773 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.20 13,007

7,526 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.40 12,962

7,575 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.68 12,959

7,394 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 12.38 13,109

7,324 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.27 13,025

7,529 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 12.43 13,117

7,618 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.87 13,056

7,392 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.21 12,898

7,618 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 13.06 13,036

7,483 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.44 12,944

7,597 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.49 12,893

7,440 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 12.89 12,944

7,573 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 12.89 12,951

7,538 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 13.20 12,949

7,621 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.03 13,001

7,442 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 12.83 13,060

7,673 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.23 13.39 12,993

7,501 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 12.32 13,089

7,407 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 12.41 13,122

7,638 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 12.68 13,054

7,579 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.84 13,057

7,687 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 13.01 13,077

7,562 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.04 13,040

7,647 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 13.06 13,018

7,531 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.49 12,975

7,480 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 13.79 12,870

7,594 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 12.78 13,146

7,597 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 12.98 13,028

6,978 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 13.21 12,968

7,559 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.17 12,984

7,608 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 12.10 13,236

7,403 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 12.26 13,151

7,503 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 12.53 13,142

7,149 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 13.26 12,978

7,174 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 12.62 13,063

6,684 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.49 13.20 12,959

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method
D.B. D.B. D.B.

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

7,246 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 12.76 13,090

7,687 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.04 12,846

7,651 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.80 13,083

7,578 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.63 13,069

7,799 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.23 13,159

7,589 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 12.37 13,141

7,542 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.98 13,062

7,535 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.44 12.86 13,042

7,666 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.01 13,058

7,475 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.75 13,114

7,673 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.77 13,069

7,679 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 12.24 13,146

7,640 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 11.92 13,181

7,716 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.24 13,225

7,692 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.02 13,158

7,717 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 11.96 13,232

7,752 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.58 13,133

7,759 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.37 13,078

7,781 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.59 13,118

7,527 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 12.88 13,014

7,611 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 13.06 13,037

7,744 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.02 12,993

7,651 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.08 13,054

7,624 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 13.30 13,007

7,475 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.72 13,096

7,523 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.28 12.49 13,122

7,678 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 12.49 13,100

7,460 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.74 12,944

7,547 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.66 12,883

7,548 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.73 12,938

8,105 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 11.52 13,395

7,623 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.73 12,925

7,729 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 13.90 12,894

7,779 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.20 12,969

7,827 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.44 12,999

7,757 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 13.02 13,017

7,650 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 13.27 12,955

7,684 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.52 12,985

7,794 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.31 12,966

7,603 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.76 13,081

7,617 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.33 13,024

7,585 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.48 12.95 13,029

7,830 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.07 13,078

7,692 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.76 13,081

7,727 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 12.95 13,050

7,899 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.93 13,045
D.B. D.B. D.B.

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

7,865 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.62 13,074

7,892 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 13.19 12,972

7,848 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 12.92 13,039

7,775 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.73 12,886

7,831 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.55 14.44 12,808

7,759 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 12.40 13,105

7,838 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.16 13,206

7,850 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.60 13,119

7,608 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 12.39 13,111

7,781 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 13.00 12,972

7,742 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.44 12.79 13,069

7,846 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 12.77 13,089

7,862 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 12.31 13,132

7,776 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.65 13,084

7,676 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 12.78 13,051

7,810 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.31 12,965

7,690 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.50 13.80 12,951

7,803 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 13.09 13,028

7,770 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.47 12.99 13,098

7,710 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.78 13,062

7,743 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 13.13 13,003

7,082 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.56 13,077

7,768 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 12.89 13,115

7,741 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.51 12,996

7,785 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 13.54 12,921

7,813 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.17 12,962

7,678 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.48 13.35 12,925

7,899 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.63 13,100

7,787 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.64 13,152

7,764 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.88 13,077

7,790 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 12.96 12,987

7,755 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.47 12.51 13,005

7,707 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 12.58 13,087

7,040 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 12.43 13,086

7,902 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 12.73 13,044

7,696 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.44 13,139

7,655 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.21 12.46 13,061

7,689 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.47 13.19 12,956

7,697 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.06 13,029

7,816 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 12.10 13,129

7,818 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 12.70 13,114

7,768 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.55 13.09 13,025

7,605 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 13.60 12,936

7,736 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 13.72 12,936

7,271 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.40 12,912

7,864 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 14.01 12,903
D.B. D.B. D.B.

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

7,788 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 1.16 13.05 13,003

7,731 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.52 12.88 13,031

7,893 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 12.30 13,128

7,725 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.09 13,041

7,884 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.94 13,051

7,808 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.16 13,009

7,730 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.08 13.10 12,965

7,512 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.11 13.15 12,998

6,918 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 1.99 12.98 13,046

7,497 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.09 12.64 13,100

7,739 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.07 13.19 12,967

7,518 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.04 12.81 13,062

7,784 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.07 12.70 13,062

7,831 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.10 12.99 13,030

7,763 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.11 12.92 13,005

7,663 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 14.01 12,857

7,801 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.45 12,924

7,480 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.21 12.60 13,097

7,880 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 12.18 12,818

7,646 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.05 13.03 13,050

7,545 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.08 12.92 13,038

7,646 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.14 12.97 13,028

7,661 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.67 13,071

7,869 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.28 12.63 13,052

7,492 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 12.62 13,115

7,842 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 13.15 13,018

7,693 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.26 12.95 13,069

7,892 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 12.97 13,043

7,790 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.15 13,015

7,923 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.73 12,947

7,749 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 0.83 14.98 12,406

7,414 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.93 13,046

7,717 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.21 12.73 13,060

7,566 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 12.26 13,212

7,726 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 12.09 13,121

7,591 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 12.07 13,198

7,425 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.02 13,181

7,613 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.17 13.16 12,988

7,292 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.10 12.63 13,215

7,440 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.37 13,136

7,787 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 12.92 13,076

7,630 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 12.85 12,984

7,847 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.17 13.48 12,912

7,697 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 13.74 12,892

7,674 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 12.95 13,010

7,653 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.18 13,001
D.B. D.B. D.B.

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

7,101 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.09 13,046

7,630 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.28 12.55 13,096

7,816 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.16 13,053

7,793 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 13.08 13,005

7,822 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 12.70 13,107

7,694 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 12.83 13,028

7,728 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 13.07 12,968

7,850 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 13.17 13,098

7,125 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 13.00 13,051

7,916 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 13.33 12,976

7,780 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 12.91 13,057

7,835 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 13.01 13,025

7,505 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 11.67 13,230

7,700 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 12.82 13,095

7,478 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.21 12.66 13,075

7,823 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.23 13.26 12,986

7,683 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.26 13.63 12,935

7,797 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 12.74 13,103

7,771 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.56 12,911

7,824 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.29 12,988

7,879 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 13.50 12,975

7,940 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.78 13,030

7,734 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.06 13.28 12,908

7,884 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.17 13.90 12,902

7,764 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.04 13.65 12,885

7,748 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 14.06 12,847

7,798 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.13 13.28 12,958

7,675 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.13 12.89 13,049

7,840 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.11 13.04 13,032

7,694 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.13 13.82 12,962

7,754 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.10 13.13 13,004

7,739 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 13.49 12,962

7,778 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 14.29 12,847

7,937 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 13.30 13,014

8,087 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.21 13,044

7,774 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.28 12.58 13,131

7,624 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.60 13,096

7,823 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.05 14.40 12,807

7,761 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 13.35 12,991

7,741 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.26 13.58 12,955

7,754 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 13.22 12,970

7,842 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.23 13.47 12,971

7,661 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.69 13,077

7,628 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.56 13,162

7,744 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.04 13,099

7,779 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 13.36 13,057
D.B. D.B. D.B.

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

7,681 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 13.22 13,036

7,130 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.12 13.56 12,953

7,781 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.10 14.63 12,822

7,790 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 13.60 12,942

7,710 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.09 12.74 13,059

7,730 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.13 13.54 12,954

7,792 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.52 12,969

7,753 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 12.73 13,046

7,937 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 13.74 12,953

7,709 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.27 12,944

7,630 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 12.17 13,124

7,806 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 12.61 13,087

6,396 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.90 16.27 12,617

6,598 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.71 16.32 12,542

6,557 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.71 15.35 12,721

6,825 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.09 15.11 12,691

6,826 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.50 16.08 12,610

6,740 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.75 12.70 13,183

6,619 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.71 12.65 13,066

6,743 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.08 13.58 12,977

6,737 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.80 13.77 13,011

6,296 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.66 13.94 12,971

6,743 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.42 15.76 12,592

6,686 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.29 15.63 12,558

6,612 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.20 15.37 12,715

6,030 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.99 13.38 13,028

6,503 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.51 13.06 12,991

6,588 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.79 11.77 13,286

6,623 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.93 14.53 12,882

6,500 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.60 12.93 13,160

6,570 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.55 13.93 12,911

6,367 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.01 14.43 12,885

6,475 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.74 12.26 13,218

6,595 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.45 12.37 13,265

6,720 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.47 13.59 13,109

6,673 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.64 13.01 13,046

6,738 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.89 14.39 12,869

6,633 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 14.40 12,887

6,659 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 14.28 12,914

6,702 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.77 14.40 12,919

6,694 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.66 13.89 12,910

6,677 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.84 14.86 12,762

6,857 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.00 14.28 12,862

6,653 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.75 12.50 13,112

6,643 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 11.37 13,308

6,550 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.79 13.65 13,001
D.B. D.B. D.B.

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

6,500 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 13.86 12,971

6,549 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.80 13.71 12,921

6,644 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.72 13.89 12,913

6,593 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.77 13.56 13,014

6,484 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.80 13.57 13,027

6,722 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.81 14.04 12,977

6,643 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 14.35 12,870

6,673 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.76 14.47 12,806

6,688 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.85 14.80 12,721

6,601 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.97 14.16 12,904

9,993 1, 2, 3, 4, 5 ALABAMA HARLAN HARLAN, KELLIOKA, SPLINT, HARLAN TRAIN 1.08 9.65 13,518

9,931 1, 2, 3, 4, 5 ALABAMA HARLAN HARLAN, KELLIOKA, SPLINT, HARLAN TRAIN 1.12 11.22 13,224

6,655 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER TRAIN 1.86 13.87 12,954

6,580 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER TRAIN 1.61 14.73 12,764

6,601 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER TRAIN 1.38 14.17 12,786

6,626 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER TRAIN 1.59 14.69 12,762

6,598 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER TRAIN 1.60 12.32 13,238

6,597 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER TRAIN 1.75 13.52 12,999

6,750 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER TRAIN 1.70 12.85 13,040

8,787 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 17.03 12,648

8,831 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.94 16.29 12,754

8,677 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 16.96 12,632

8,848 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.98 16.49 12,743

9,004 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.10 17.95 12,470

8,951 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.88 17.31 12,484

8,974 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.82 18.55 12,411

8,940 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.90 18.98 12,361

8,872 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.94 18.40 12,492

9,000 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.02 19.06 12,322

8,939 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 17.85 12,431

8,969 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.12 19.41 12,245

8,863 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.17 17.30 12,680

8,741 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.23 17.81 12,621

9,777 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.11 17.15 12,670

9,198 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.11 16.30 12,512

9,261 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.17 13.60 13,319

9,466 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.99 16.90 12,472

8,957 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.94 16.18 12,683

9,443 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.93 15.73 12,841

8,943 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.91 16.67 12,706

8,955 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 16.29 12,755

8,949 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.97 17.52 12,516

8,578 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.86 15.94 12,859

8,688 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.99 15.88 12,828

8,781 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.98 15.78 12,867

8,940 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.08 14.47 13,077
D.B. D.B. D.B.

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

8,508 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.95 15.65 12,961

8,603 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.02 14.13 13,217

7,502 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 13.90 13,184

9,118 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.09 13.66 13,245

9,061 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 14.54 13,105

9,305 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.15 13.56 13,192

9,335 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.07 13.21 13,304

9,826 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.10 14.44 13,062

9,733 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 15.11 12,966

9,850 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.04 14.53 13,006

9,831 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.11 13.00 13,350

9,734 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 14.70 13,019

10,031 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.07 15.66 12,896

9,930 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.02 15.44 12,852

9,524 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 14.71 12,950

9,537 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.06 15.75 12,783

9,787 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.01 14.26 13,001

9,277 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.96 15.65 12,807

9,121 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 15.74 12,753

9,254 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.08 14.90 12,941

9,844 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.96 14.35 13,054

9,912 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.98 14.70 13,029

10,142 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.98 14.61 13,072

9,754 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.86 15.01 12,909

9,805 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.92 14.17 13,075

9,369 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.97 14.45 13,095

9,590 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.02 14.24 13,176

9,635 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.97 14.69 13,083

9,815 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 16.05 12,834

9,042 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.92 15.36 12,913

9,220 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.94 15.90 12,806

9,260 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.93 15.14 13,016

9,171 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.95 16.28 12,813

8,791 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.04 16.34 12,816

8,904 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.17 16.43 12,750

9,037 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.10 14.35 13,048

8,987 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 16.16 12,801

8,787 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.88 16.11 12,730

8,954 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.96 15.73 12,887

8,916 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 15.74 12,805

8,950 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 16.49 12,839

9,149 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.08 15.61 12,942

10,132 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 16.79 12,717

9,533 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.99 15.83 12,883

9,522 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 17.77 12,472

9,190 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.08 16.19 12,775
D.B. D.B. D.B.

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

8,776 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 15.29 12,863

6,645 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.97 13.76 12,795

6,705 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.15 13.64 12,796

6,718 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.98 12.80 12,937

6,657 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.90 14.31 12,933

6,722 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.92 14.31 12,860

6,612 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.01 13.40 13,008

6,720 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.11 13.78 12,811

0 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN N/A N/A N/A

6,602 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.93 14.00 12,713

6,546 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.97 11.37 13,257

6,467 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.74 14.09 12,834

6,653 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.11 14.54 12,748

6,697 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.02 12.13 12,999

6,468 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.08 11.11 13,318

6,606 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.12 12.51 13,150

6,285 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.05 13.35 12,970

6,216 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.03 12.73 12,932

6,302 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.98 13.56 12,934

6,648 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.90 12.61 12,985

6,581 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.88 16.52 12,458

6,546 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.88 16.59 12,436

6,527 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.98 14.24 12,800

10,228 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.92 8.85 13,667

9,961 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.89 9.28 13,656

10,197 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.91 8.71 13,712

10,294 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.84 8.36 13,831

10,146 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.88 7.76 13,842

9,929 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.79 7.36 13,958

10,207 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.82 7.47 13,924

10,186 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.90 8.44 13,760

10,516 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.96 7.48 13,945

10,508 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.97 8.51 13,750

10,369 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 1.10 8.37 13,732

10,451 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 1.04 7.59 13,888

10,161 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.99 8.63 13,703

10,107 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.93 7.85 13,861

10,317 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.93 8.87 13,706

10,129 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.90 8.27 13,793

10,399 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.92 7.48 13,931

10,236 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.88 8.56 13,751

10,397 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.91 8.13 13,833

10,257 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.98 7.48 14,024

10,318 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.86 8.13 13,831

10,358 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.94 8.89 13,685

10,394 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.86 8.40 13,776
D.B. D.B. D.B.

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

Vendor Analyses

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

9,244 1, 2, 3, 4, 5 KENTUCKY HARLAN HARLAN, KELLIOKA, SPLINT TRAIN 1.07 8.81 13,558

9,509 1, 2, 3, 4, 5 KENTUCKY HARLAN HARLAN, KELLIOKA, SPLINT TRAIN 1.16 10.24 13,393

6,559 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 1.05 8.53 13,887

6,740 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.97 8.38 13,909

6,672 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 1.04 10.64 13,538

6,404 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 1.35 10.13 13,578

6,210 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.97 9.00 13,799

6,659 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.97 8.01 13,995

6,301 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.89 8.49 13,964

6,682 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.93 8.44 13,865

6,358 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.94 8.36 13,930

6,259 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.90 9.15 13,792

6,460 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.92 8.86 13,777

6,325 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.95 8.31 13,925

6,198 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.92 9.06 13,744

6,582 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.87 10.53 13,629

6,516 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.91 8.06 13,879

10,142 1, 2, 3, 4, 5 KENTUCKY FLOYD ONYX TRAIN 1.08 13.95 12,795

10,303 1, 2, 3, 4, 5 KENTUCKY FLOYD ONYX TRAIN 1.16 11.88 13,112

9,717 1, 2, 3, 4, 5 KENTUCKY FLOYD ONYX TRAIN 1.19 11.84 13,131

9,903 1, 2, 3, 4, 5 KENTUCKY FLOYD ONYX TRAIN 1.07 12.75 12,855

9,945 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.80 13.71 12,690

10,120 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.99 14.37 12,544

9,987 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.85 13.76 12,679

10,023 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.01 11.85 13,093

10,123 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.91 12.58 12,900

9,939 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.89 11.88 12,923

9,962 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 13.69 12,786

10,037 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.85 12.85 12,883

10,141 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 13.75 12,666

10,210 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.01 12.87 12,827

9,921 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.93 13.46 12,755

9,977 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.92 10.85 13,145

9,978 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.06 15.01 12,415

10,196 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.91 10.26 13,243

10,027 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.79 14.08 12,671

10,057 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.86 14.33 12,601

10,280 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.83 12.71 12,880

10,116 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.82 9.79 13,393

10,031 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.94 12.21 12,961
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):

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

09-603 9,590 0.93 19.23 12,230 0.063 98 94 16.3 1.8 19.7 1.5 0.09 24.3 8.9 10.5 53.4 1.0 AL Cullman, Jefferson, Shelby, Tuscaloosa, Walker Black Creek, Jagger, Upper New Castle, Blue 

Creek, Lower Helena, Yeshic, Thompson, Mary 

Lee, Fiines, Washed Thompson

Train

09-605 7,914 2.22 12.41 13,044 0.096 144 52 16.8 1.5 12.7 1.6 0.12 21.6 8.5 9.5 28.4 2.1 AL Fayette Pratt Train

09-606 7,008 1.71 13.19 12,878 0.226 136 61 15.2 3.0 43.5 2.3 0.33 21.2 9.5 9.0 25.0 3.1 AL Walker, Tuscaloosa Washed America - Pratt, JWR Blue Creek seam 

fines, America, Pratt

Train

09-607 6,895 1.03 7.95 13,880 0.128 127 ND 6.9 1.2 26.8 1.1 0.18 11.2 4.1 4.9 29.4 1.9 AL Walker Nickel Plate, Top America, Washed Top 

America, Washed Nickel Plate

Train

09-608 7,123 0.94 14.35 12,829 0.078 435 61 12.4 1.9 12.5 1.7 0.04 18.1 7.6 5.4 38.5 1.3 AL Jefferson, Walker Mary Lee, Top American, American #1 Train

09-609 8,133 2.22 13.20 12,939 0.095 169 68 15.9 1.1 13.2 1.6 0.07 21.5 8.2 7.5 62.4 1.8 AL Fayette, Marion, Winston Pratt, Butahatchee, Meredyth Train

09-618 6,899 1.57 13.51 13,058 0.187 134 69 15.6 2.2 26.8 1.4 0.13 21.6 8.6 7.4 29.7 2.5 AL Walker, Tuscaloosa Washed America - Pratt, JWR Blue Creek, 

America, Pratt

Train

09-619 7,123 0.94 14.49 12,653 0.096 481 82 21.0 2.1 16.5 1.7 0.04 21.5 11.8 7.3 76.3 1.1 AL Jefferson, Walker Blue Creek, Top American, Bear Creek, Black 

Creek, Blue Creek, Bear Creek High Ash

Train

09-623 7,557 2.30 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

09-624 7,108 1.02 10.32 13,609 0.125 143 34 10.0 1.7 26.1 1.6 0.24 16.5 7.0 3.4 32.7 2.0 AL Walker Nickel Plate, Top America, Washed Nickel 

Plate, Washed Top America

Train

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

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

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

09-416 10,152 1.17 9.91 13,419 0.089 154 57 15.5 1.6 7.9 2.8 <0.02 15.6 8.0 9.7 19.9 2.1 KY Harlan Harlan, Creech, Kellioki, Darby, Splint Train

09-625 8,200 2.38 13.40 12,907 0.130 157 63 16.5 1.7 11.6 1.6 0.05 22.6 8.2 8.5 32.1 2.1 AL Fayette, Walker Pratt, Mary Lee Train

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

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

09-409 10,800 0.89 13.05 12,741 ND 567 111 13.1 <1 5.4 2.6 ND 22.8 8.1 10.5 13.8 5.2 KY Perry and Breathitt Hazard 5A, Hazard #7, Hazard #8, Hazard #9 Train

09-646 10,020 1.01 15.42 12,872 0.078 116 66 20.4 1.9 41.0 2.0 0.20 27.9 12.4 11.5 59.8 1.0 AL Jefferson, Shelby, Tuscaloosa, Walker Blue Creek #2, #2 Upper& Lower Mary Lee, 

Lower Helena #1, Mary Lee, Blue Creek, #3 

Fines, Thompson, #2 Upper & Lower New 

Castle

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

09-639 7,116 1.67 13.97 12,948 0.256 108 65 11.6 2.1 33.4 1.5 0.24 20.6 7.6 8.7 31.0 2.7 AL Walker, Tuscaloosa Pratt, Bottom & Top America, Nickle Plate, 

Blue Creek

Train

09-637 8,320 2.44 12.97 12,994 0.236 142 47 16.6 1.9 25.5 1.3 0.21 21.3 8.8 9.3 35.5 2.1 AL Fayette, Walker Pratt, Mary Lee Train

09-635 6,600 1.00 8.41 13,872 0.209 111 43 9.3 2.3 16.6 1.7 0.10 13.9 6.1 5.7 18.9 2.0 AL Walker, Tuscaloosa Top America, Nickle Plate, Blue Creek Train

09-633 8,864 0.90 15.40 12,534 0.105 337 62 17.4 2.2 16.9 2.3 0.04 22.5 11.2 9.9 76.2 1.1 AL Jefferson, Walker, Franklin Blue Creek, Bear Creek, Black Creek, America 

#1, Mary Lee, Top America, Nickle Plate

Barge

09-108 8,273 2.02 14.00 12,826 0.124 180 51 18.6 1.6 16.7 1.3 0.09 27.0 10.1 11.0 37.6 2.1 AL Fayette, Walker Pratt, Marylee 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

09-650 7,113 1.34 13.82 12,842 0.149 430 63 19.5 2.0 27.8 2.4 0.24 25.5 11.9 11.3 55.3 1.6 AL Walker, Franklin, Winston Mary Lee (WC), Bear Creek, Black Creek, 

Jefferson, Blend, Blue Crrek, Parrish America 

#1, Pratt, Bottom&Top America, Nickel 

Plate

Train

09-652 7,114 1.71 13.44 13,023 0.294 218 46 18.1 2.7 45.8 1.9 0.27 22.6 8.6 8.5 29.5 2.1 AL Walker, Franklin, Winston Mary Lee (WC), Bear Creek, Black Creek & HA, 

Jefferson, Parrish America 1 & 2, Pratt, Blue 

Creek, Bottom & Top America, Nickle Plate

Train

09-655 6,851 1.01 8.53 13,911 0.163 160 36 11.1 2.5 29.8 1.6 0.11 13.5 6.9 5.9 29.2 1.7 AL Jefferson, Walker, Franklin Top America & Washed, Nickle Plate & 

Washed, Blue Creek Fines (WC)

Train

09-660 9,996 0.95 16.10 12,859 0.071 112 69 17.5 2.2 17.0 1.5 0.04 24.6 10.7 9.4 42.9 1.1 AL Jefferson, Shelby Blue Creek #2, Lower Helena #1, Blue Creek, 

#3 fines (WC)

Train

09-444 11,080 0.80 12.88 12,797 0.039 743 80 16.5 1.0 5.9 2.5 <0.02 26.4 9.1 12.5 13.6 5.1 KY Perry and Breathitt Hazard 5A, Hazard #7, Hazard #8, Hazard #9, 

Hazard #10

Train

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

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

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

09-434 10,800 1.01 12.87 12,856 ND 506 101 10.6 <1 7.7 1.8 ND 23.3 7.0 10.4 11.1 3.6 KY Perry and Breathitt Hazard 5A, Hazard #7, Hazard #8, Hazard #9, 

Hazard #10

Train

09-112 7,121 1.80 14.31 12,843 0.231 127 49 15.1 1.9 40.5 1.9 0.22 26.4 8.1 9.0 23.6 2.7 AL Walker Bottom America Seam Washed, # 3 American 

Seam, JWR Processed Fines (Blue Creek 

Seam), Pratt Seam

Train

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

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

Note: "ND" means non-detect.

Note: Alabama Power collects this information on select coal shipments, but does not have this information available on a shipment by shipment basis. The information Alabama Power provides in this response 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 response represents only a very small portion of our actual shipments.

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.

Sample ID # State/Country County Coal Seam

Fuel 

Shipment 

Method

Total amount of fuel 

represented by 

sample, tons

Total Sulfur, 

%

Ash Content, 

%

Heating Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Nickel, 

ppm

Other Trace Metal HAP, ppm
4 Were the data provided in Part II, question 3 above, acquired pursuant to:

____ permit requirements

____ contractual obligations

____ standard operational procedures

_X__ other (please specify to support R&D projects, plant performance, and TRI reporting)

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

____ Fuel supplier (name and address)

_X__ Other (name and address)

Analytical services are conducted by Alabama Power Company's in-house laboratory.

Alabama Power Company, General Services Laboratory

744 Highway 87, GSC #8

Calera, AL 35040

6 Name and address of laboratory performing analyses:

Alabama Power Company, General Services Laboratory

744 Highway 87, GSC #8

Calera, AL 35040

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

09-603 6.38 26.91 19.23 53.86 71.25 4.39 1.30 0.93 2.90 250 27.1 0.131 0.027 52.7 28.4 30.71 7.37 1.05 1.13 0.04391 0.27 2.79 53.82 0.19 1.11 1.36

09-605 4.99 35.20 12.41 52.39 74.47 4.82 1.60 2.22 4.48 230 32.1 0.097 0.046 49.5 20.6 26.42 14.71 4.78 1.29 0.03627 0.78 2.31 41.56 0.50 5.91 1.30

09-606 4.16 31.80 13.19 55.01 74.30 4.68 1.54 1.71 4.58 670 36.1 0.073 0.029 50.3 17.7 29.37 11.54 2.50 0.91 0.02999 1.62 2.07 46.55 0.30 2.67 1.58

09-607 4.33 31.25 7.95 60.80 80.60 4.84 1.76 1.03 3.82 200 15.4 0.062 0.035 21.1 7.6 28.08 9.38 5.70 1.29 0.05858 0.37 2.04 44.49 0.59 6.32 1.33

09-608 4.50 30.23 14.35 55.42 72.93 4.65 1.72 0.94 5.41 250 17.8 0.11 0.047 34.9 14.9 26.72 6.50 1.88 1.27 0.04251 0.38 2.94 56.61 0.44 1.77 1.24

09-609 7.07 34.61 13.20 52.19 72.66 4.84 1.69 2.22 5.39 210 28.8 0.104 0.038 50.3 19 25.99 15.60 3.62 1.31 0.07485 0.71 2.42 44.33 0.39 3.91 1.29

09-618 5.60 31.32 13.51 55.17 73.74 4.70 1.60 1.57 4.88 470 29.4 0.08 0.039 46.7 13.3 27.97 10.71 2.68 0.98 0.03477 1.19 1.89 49.33 0.39 2.53 1.66

09-619 7.30 31.30 14.49 54.21 72.21 4.60 1.67 0.94 6.09 300 20.4 0.107 0.032 40.7 18.3 27.15 7.12 1.98 1.23 0.08333 0.71 3.03 55.36 0.30 1.58 1.23

09-623 7.14 34.92 13.06 52.02 73.10 4.92 1.92 2.30 4.70 220 35.3 0.102 0.044 55.8 26.9 26.08 14.67 4.31 1.30 0.04097 0.68 2.38 43.07 0.46 5.31 1.34

09-624 6.25 30.15 10.32 59.53 77.66 4.77 1.93 1.02 4.30 280 21.4 0.075 0.039 32.2 11.6 27.21 8.99 4.17 1.21 0.05017 0.44 2.21 48.65 0.51 4.68 1.50

09-403 7.84 36.22 7.97 55.81 78.63 4.98 1.63 1.02 5.78 102 18.7 0.059 0.024 29.2 16 25.60 11.20 2.05 1.11 ND ND 2.69 50.40 0.45 1.30 1.25

09-405 7.99 35.92 10.46 53.62 77.90 4.93 1.61 0.95 4.16 224 37.1 0.118 0.057 63.3 25.3 28.10 6.40 1.80 0.86 ND 0.49 2.26 51.40 0.41 0.96 1.39

09-408 7.46 34.97 13.54 51.50 71.21 4.61 1.43 1.17 8.04 133 19.6 0.049 0.011 32.9 11.1 26.40 6.26 1.14 0.59 ND ND 1.80 58.20 ND ND 1.57

09-416 6.40 35.15 9.91 54.94 76.35 5.06 1.61 1.17 5.90 90 22.8 0.058 0.029 40.7 20.7 28.94 7.36 1.28 0.98 0.03176 0.28 2.68 55.02 0.39 1.48 1.36

09-625 6.90 35.01 13.40 51.59 72.50 4.93 1.52 2.38 5.27 220 31.4 0.105 0.044 50.9 21.9 26.04 14.16 4.10 1.30 0.03795 0.7 2.35 44.26 0.44 4.81 1.39

09-421 6.84 36.29 8.42 55.29 75.08 4.91 1.68 1.09 8.82 112 18.9 0.046 0.030 32.8 12.0 28.50 8.31 2.47 0.92 ND 0.69 1.99 47.30 0.63 1.79 1.59

09-415 8.61 34.91 10.48 54.61 73.16 4.79 1.48 0.91 9.19 123 19.3 0.089 0.033 30.7 16.0 25.20 8.30 1.56 1.42 ND ND 3.19 53.80 0.49 1.07 1.15

09-409 8.39 34.31 13.05 52.46 70.77 4.53 1.48 0.89 9.28 143 21.4 0.052 0.013 32.4 9.4 27.50 4.26 1.19 0.62 ND 0.47 1.72 55.40 0.18 0.43 1.89

09-646 7.02 28.09 15.42 56.49 74.03 4.49 1.45 1.01 3.60 300 28.3 0.136 0.028 51.7 34.8 24.82 8.90 1.40 1.46 0.06132 0.27 3.47 56.34 0.24 1.60 1.20

09-641 6.91 34.91 13.06 52.03 73.10 4.78 1.10 2.39 5.57 220 32.1 0.099 0.039 51.0 22.2 25.07 14.91 5.41 1.26 0.04078 0.64 2.38 42.44 0.41 5.79 1.24

09-639 5.90 30.40 13.97 55.63 73.71 4.68 1.67 1.67 4.30 520 30.1 0.077 0.039 40.8 11.8 27.56 10.09 3.37 0.91 0.03515 1.39 1.89 48.42 0.38 3.63 1.65

09-637 6.61 34.93 12.97 52.10 72.82 4.93 1.68 2.44 5.16 230 31.6 0.099 0.043 50.5 22.2 25.86 15.73 4.27 1.26 0.04328 0.71 2.33 42.36 0.45 5.36 1.31

09-635 5.76 30.40 8.41 61.19 79.36 4.89 1.59 1.00 4.75 200 22.2 0.049 0.029 29.8 8.7 28.22 8.56 3.12 0.96 0.03551 0.42 2.12 50.97 0.46 3.24 1.58

09-633 6.39 30.25 15.40 54.35 71.39 4.55 1.55 0.90 6.21 250 21.3 0.117 0.034 41.5 22.3 26.33 6.69 1.54 1.26 0.07830 0.45 2.93 57.39 0.30 1.64 1.22

09-108 7.18 34.21 14.00 51.79 71.67 4.86 1.79 2.02 5.66 260 33.7 0.116 0.048 59.6 23.4 26.31 12.72 4.13 1.37 0.04252 0.71 2.49 45.85 0.46 4.19 1.36

09-110 6.66 34.78 12.63 52.59 72.71 4.97 1.80 2.16 5.73 230 36.6 0.101 0.042 59.8 42.3 26.37 14.37 4.18 1.32 0.04537 0.81 2.34 43.59 0.45 4.76 1.37

09-650 7.03 32.31 13.82 53.87 70.84 4.59 1.63 1.34 7.78 300 34.5 0.098 0.028 47.5 19.1 26.41 9.62 1.74 1.18 0.06332 0.5 2.65 54.07 0.27 1.89 1.35

09-652 7.14 30.81 13.44 55.75 73.35 4.83 1.76 1.71 4.91 410 33.7 0.089 0.030 45.5 16.1 27.09 11.82 1.26 1.10 0.03475 0.54 2.74 51.97 0.29 1.37 1.42

09-655 7.59 30.26 8.53 61.21 79.28 4.96 2.01 1.01 4.21 210 17.2 0.055 0.027 27.2 10.8 25.46 9.99 4.45 1.07 0.05418 0.35 2.25 49.93 0.43 4.29 1.40

09-660 8.29 26.24 16.10 57.66 72.97 4.55 1.47 0.95 3.96 370 21.7 0.145 0.034 48.6 24.3 28.57 6.64 1.00 1.49 0.04217 0.27 3.58 55.52 0.28 1.08 1.23

09-444 7.05 33.46 12.88 53.66 72.72 4.83 1.54 0.80 7.23 160 24.7 0.048 0.018 39.1 9.1 26.38 3.61 1.04 0.61 0.01673 0.38 1.84 62.66 0.19 0.87 2.22

09-426 7.44 34.50 9.28 56.21 75.38 4.81 1.50 1.23 7.81 143 28.2 0.077 0.027 42.9 23.8 23.40 11.90 1.55 1.25 ND ND 2.70 52.40 0.60 1.38 1.17

09-428 6.51 36.36 9.48 54.17 74.68 4.87 1.57 1.07 8.33 61 28.6 0.042 0.014 44.3 23.0 27.50 7.37 1.26 0.88 ND ND 2.17 54.00 0.42 0.98 1.38

09-433 6.62 35.69 8.34 55.97 76.07 4.84 1.60 1.06 8.09 92 21.5 0.046 0.032 30.8 13.1 28.10 7.94 2.27 0.93 ND ND 2.08 50.80 0.56 1.93 1.46

09-434 6.23 33.69 12.87 53.44 71.73 4.46 1.46 1.01 8.46 102 20.1 0.044 0.013 34.0 8.7 25.40 4.28 1.17 0.53 ND 0.53 1.43 55.20 0.16 ND 1.88

09-112 8.25 31.24 14.31 54.45 72.57 4.77 1.85 1.80 4.70 540 36.5 0.073 0.034 52.1 13.0 27.91 11.05 1.94 0.85 0.02613 1.42 1.83 50.31 0.33 2.00 1.68

09-447 8.22 35.99 9.67 54.33 74.45 4.77 1.73 0.91 8.48 113 21.2 0.068 0.034 35.8 22.2 27.10 7.87 2.12 1.11 ND ND 2.49 53.80 0.51 1.25 1.24

09-448 6.88 35.96 8.24 55.80 76.49 4.88 1.61 0.91 7.87 92 19.7 0.040 0.030 28.3 10.4 28.60 6.94 2.32 0.80 ND 0.44 1.81 53.30 0.58 1.56 1.59

Note: "ND" means non-detect.

Sample ID 

#

Proximate Analyses, % by wt Ultimate Analyses, % by wt Other Trace Metals, ppm Ash Mineralogy, % by wt
8a What emission test report(s), parametric monitoring data, and other data or monitoring are available for the boilers noted in Part I,

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

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

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

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

Report 1 Unit 1 Particulate Emissions Test (May 12, 2005)

Report 2 Unit 2 Particulate Emissions Test (May 11, 2005)

Report 3 Unit 3 Particulate Emissions Test (April 15, 2005)

Report 4 Unit 4 Particulate Emissions Test (March 29, 2005)

Report 5 Unit 5 Particulate Emissions Test (June 23, 2005)

Report 6 Unit 1 Particulate Emissions Test (June 1, 2006)

Report 7 Unit 2 Particulate Emissions Test (June 9, 2006)

Report 8 Unit 3 Particulate Emissions Test (April 26, 2006)

Report 9 Unit 4 Particulate Emissions Test (February 9, 2006)

Report 10 Unit 5 Particulate Emissions Test (May 16, 2006)

Report 11 Unit 1 Particulate Emissions Test (May 8, 2007)

Report 12 Unit 2 Particulate Emissions Test (August 23, 2007)

Report 13 Unit 3 Particulate Emissions Test (February 13, 2007)

Report 14 Unit 4 Particulate Emissions Test (April 18, 2007)

Report 15 Unit 5 Particulate Emissions Test (May 10, 2007)

Report 16 Unit 1 Particulate Emissions Test (April 17, 2008)

Report 17 Unit 2 Particulate Emissions Test (July 9, 2008)

Report 18 Unit 3 Particulate Emissions Test (May 28, 2008)

Report 19 Unit 4 Particulate Emissions Test (May 29, 2008)

Report 20 Unit 5 Particulate Emissions Test (May 1, 2008)

Report 21 Unit 1 Particulate Emissions Test (July 29 and 30, 2009)

Report 22 Unit 2 Particulate Emissions Test (March 25, 2009)

Report 23 Unit 3 Particulate Emissions Test (June 2, 2009)

Report 24 Unit 4 Particulate Emissions Test (July 8, 2009)

Report 25 Unit 5 Particulate Emissions Test (April 16, 2009)

Report 26 Unit 1 Compliance Assurance Monitoring Test (June 2, 2006)

Report 27 Unit 4 Compliance Assurance Monitoring Test (February 10, 2006)

Report 28 Unit 5 Compliance Assurance Monitoring Test (May 17, 2006)

Report 29 Unit 5 SO3 Test (March 2009)

Report 30 Unit 5 SO3 Test (October - November 2009)

Report 31 Unit 1 Boiler Baseline Performance Test for SCR (August 13-20, 2008)

Report 32 Unit 2 SCR Baseline Test (July 9 -29, 2008)

Report 33 Unit 3 Flue Gas Analyzer Verification Performance Test (February 2-9, 2005)

Report 34 Unit 4 Flame Doctor Test (September 11-18, 2009)

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

air pollutants) sampled for:

Report 1 Date: 5/12/2005 Type: duct Constituents: PM

Report 2 Date: 5/11/2005 Type: duct Constituents: PM

Report 3 Date: 4/15/2005 Type: duct Constituents: PM

Report 4 Date: 3/29/2005 Type: duct Constituents: PM

Report 5 Date: 6/23/2005 Type: duct Constituents: PM

Report 6 Date: 6/1/2006 Type: duct Constituents: PM

Report 7 Date: 6/9/2006 Type: duct Constituents: PM

Report 8 Date: 4/26/2006 Type: duct Constituents: PM

Report 9 Date: 2/9/2006 Type: duct Constituents: PM
Report 10 Date: 5/16/2006 Type: duct Constituents: PM

Report 11 Date: 5/8/2007 Type: duct Constituents: PM

Report 12 Date: 8/23/2007 Type: duct Constituents: PM

Report 13 Date: 2/13/2007 Type: duct Constituents: PM

Report 14 Date: 4/18/2007 Type: duct Constituents: PM

Report 15 Date: 5/10/2007 Type: duct Constituents: PM

Report 16 Date: 4/17/2007 Type: duct Constituents: PM

Report 17 Date: 7/9/2008 Type: duct Constituents: PM

Report 18 Date: 5/28/2008 Type: duct Constituents: PM

Report 19 Date: 5/29/2008 Type: duct Constituents: PM

Report 20 Date: 5/1/2008 Type: duct Constituents: PM

Report 21 Date: 7/29-7/30/2009 Type: duct Constituents: PM

Report 22 Date: 3/25/2009 Type: duct Constituents: PM

Report 23 Date: 6/2/2009 Type: duct Constituents: PM

Report 24 Date: 7/8/2009 Type: duct Constituents: PM

Report 25 Date: 4/16/2009 Type: duct Constituents: PM

Report 26 Date: 6/2/2006 Type: duct Constituents: PM

Report 27 Date: 2/10/2006 Type: duct Constituents: PM

Report 28 Date: 5/17/2006 Type: duct Constituents: PM

Report 29 Date: 3/1-3/31/2009 Type: duct Constituents: SO3

Report 30 Date: 10/1-11/30/2009 Type: duct Constituents: SO3

Report 31 Date: 8/13-8/20/2009 Type: duct Constituents: CO, NOx, CO2

Report 32 Date: 7/9-7/29/2008 Type: duct Constituents: CO, NOx, CO2

Report 33 Date: 2/2-2/9/2005 Type: duct Constituents: CO, NOx, CO2

Report 34 Date: 9/11-9/18/2009 Type: duct Constituents: CO, NOx, CO2, unburned carbon

8c Do any of these test reports reflect testing at a location before 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).

Reports 29 and 30 contain SO3 data that was collected at the economizer outlet, SCR outlet, and air heater outlet.

Reports 31, 32, 33, and 34 tests for CO were conducted at the economizer outlet.

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 note which reports and identify the other material(s) or non-fossil fuels used.

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

Yes ____ No _X__ If yes, please note which reports.
8f Did the unit's control configuration differ from that shown in Part I, question 16, at the time of these test results?

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

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

14, 16, 17, 18, 19, 21, 22, 23, 24, 26, 27, 31, 32, 33, and 34 (no sodium injection operating on Units 1-4; no SCR, FGD, or trona installed on Unit 5).

Boiler ID

1

2

3

4

5

Note: "N/A" means not applicable.

The control configuration shown below is representative of the Unit 5 conditions present during Reports 10, 15, 20, 25, 28, 29, and 30 (no FGD,

no trona).

Boiler ID

5

Note: "N/A" means not applicable.

tangentially-fired (1) low-NOx burners + separated 

OFA (12/19/1993)

(3) SCR (04/29/2006) - the SCR 

uses a titania-vanadia based 

ceramic catalyst and anhydrous 

ammonia as the reductant; the 

catalyst is designed to minimize 

SO3 formation1

N/A (2) hot-side ESP 

(08/02/1974)

N/A

Type NOx control SO2 control PM control Other control

NOx control SO2 control PM control Other control

tangentially-fired (1) low-NOx burners + separated 

OFA (12/19/1993)

N/A (2) hot-side ESP 

(08/02/1974)

N/A

wall-fired

wall-fired

wall-fired

wall-fired

Type

N/A

N/A

(1) low-NOx burners 

(05/21/1994)

N/A

N/A

N/A

N/A

(2) cold-side ESP was 

originally installed 

(05/01/1960) but was 

de-energized when a 

hot-side ESP was 

installed (04/1974)

(2) cold-side ESP was 

originally installed 

(07/01/1960) but was 

de-energized when a 

hot-side ESP was 

installed (04/1975)

(3) baghouse 

(06/06/1999)

(2) cold-side ESP was 

originally installed 

(06/01/1961) but was 

de-energized when a 

hot-side ESP was 

installed (12/10/1973)

(3) baghouse 

(12/20/1996)

(2) cold-side ESP was 

originally installed 

(06/01/1962) but was 

de-energized when a 

hot-side ESP was 

installed (10/15/1972)

N/A

(1) low-NOx burners N/A

(11/19/1994)

(1) low-NOx burners 

(04/07/1992)

(1) low-NOx burners 

(05/23/1993)
1

 When making catalyst decisions, the primary goal is to achieve the desired NOx performance, with a secondary goal of minimizing SO3 formation.
8g Do any of these test reports reflect testing at a location before a post combustion SO2 emission control device (e.g., FGD, SDA, Dry Scrubber)?

Yes ____ No _X__ 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 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.
9 What type of deviation reporting is required for violations of permit requirements?

Deviations from permit requirements shall be reported within 48 hours or 2 working days of such deviations, including those

attributable to upset conditions as defined in the permit. The report will include the probably cause of said deviations, and any

corrective actions or preventive measures that were taken.

The date, time, duration, magnitude, cause and corrective action taken for each excess emission are also included in the quarterly

reports submitted to ADEM.

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 cause and corrective action reports are also included in each of the quarterly reports submitted to ADEM.

Additionally, all deviations from permit terms and conditions are reported in the annual Title V compliance certifications,

submitted to both ADEM and EPA.

Note: A malfunction is not necessarily a period of non-compliance with permit terms and conditions. Not all reported deviations 

are considered violations of permit requirements.

11 Are continuous emissions monitoring system (CEMS) data available (e.g., mercury, continuous opacity monitoring systems) that are not

already being provided to the U.S. EPA, even if from short-term testing?

Yes _X__ No ____ If yes46, please note for which pollutants CEMS data are available and the period of time (both total period and calendar

period) for which the data are available. If CEM data are being provided to EPA, please note to which Office the data are being provided.

Mercury CEMS data are available1 for the following periods of time:

Unit 1-2: June 26, 2008 - December 31, 2009

Units 3-4: May 19, 2009 - December 31, 2009

Unit 5: June 10, 2008 - September 3, 2009

COMS data are available for the following time periods:

Unit 1-2: April 1, 1993 - December 31, 2009

Units 3-4: April 1, 1993 - December 31, 2009

Unit 5: November 15, 1993 - December 31, 2009

1

 Alabama Power considers CEMS data "available" only if it is maintained and subject to quality assurance/quality control

procedures that meet the requirements of 40 CFR Part 75.

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 CEMS data be submitted by the respondent. The respondent should also mark the periods of start up, shut down and malfunction events (SSM) in the data sets.
12 For each boiler noted in Part I, question 15, provide the following information:

Test 

Report

Date of test PM49 SO2 HCl/HF/HCN Metal HAP50 Hg51 CO

Other organics 

(specify)

1 Report 1 5/12/2005 See Attachment 1 N/A N/A N/A N/A N/A N/A

2 Report 2 5/11/2005 See Attachment 2 N/A N/A N/A N/A N/A N/A

3 Report 3 4/15/2005 See Attachment 3 N/A N/A N/A N/A N/A N/A

4 Report 4 3/29/2005 See Attachment 4 N/A N/A N/A N/A N/A N/A

5 Report 5 6/23/2005 See Attachment 5 N/A N/A N/A N/A N/A N/A

1 Report 6 6/1/2006 See Attachment 6 N/A N/A N/A N/A N/A N/A

2 Report 7 6/9/2006 See Attachment 7 N/A N/A N/A N/A N/A N/A

3 Report 8 4/26/2006 See Attachment 8 N/A N/A N/A N/A N/A N/A

4 Report 9 2/9/2006 See Attachment 9 N/A N/A N/A N/A N/A N/A

5 Report 10 5/16/2006 See Attachment 10 N/A N/A N/A N/A N/A N/A

1 Report 11 5/8/2007 See Attachment 11 N/A N/A N/A N/A N/A N/A

2 Report 12 8/23/2007 See Attachment 12 N/A N/A N/A N/A N/A N/A

3 Report 13 2/13/2007 See Attachment 13 N/A N/A N/A N/A N/A N/A

4 Report 14 4/18/2007 See Attachment 14 N/A N/A N/A N/A N/A N/A

5 Report 15 5/10/2007 See Attachment 15 N/A N/A N/A N/A N/A N/A

1 Report 16 4/17/2007 See Attachment 16 N/A N/A N/A N/A N/A N/A

2 Report 17 7/9/2008 See Attachment 17 N/A N/A N/A N/A N/A N/A

3 Report 18 5/28/2008 See Attachment 18 N/A N/A N/A N/A N/A N/A

4 Report 19 5/29/2008 See Attachment 19 N/A N/A N/A N/A N/A N/A

5 Report 20 5/1/2008 See Attachment 20 N/A N/A N/A N/A N/A N/A

1 Report 21 7/29-7/30/2009 See Attachment 21 N/A N/A N/A N/A N/A N/A

2 Report 22 3/25/2009 See Attachment 22 N/A N/A N/A N/A N/A N/A

3 Report 23 6/2/2009 See Attachment 23 N/A N/A N/A N/A N/A N/A

4 Report 24 7/8/2009 See Attachment 24 N/A N/A N/A N/A N/A N/A

5 Report 25 4/16/2009 See Attachment 25 N/A N/A N/A N/A N/A N/A

1 Report 26 6/2/2006 See Attachment 26 N/A N/A N/A N/A N/A N/A

4 Report 27 2/10/2006 See Attachment 27 N/A N/A N/A N/A N/A N/A

5 Report 28 5/17/2006 See Attachment 28 N/A N/A N/A N/A N/A N/A

1 Report 31 8/13-8/20/2008 N/A N/A N/A N/A N/A See Attachment 29 N/A

2 Report 32 7/9-7/29/2008 N/A N/A N/A N/A N/A See Attachment 30 N/A

3 Report 33 2/2-2/9/2005 N/A N/A N/A N/A N/A See Attachment 31 N/A

4 Report 34 9/11-9/18/2009 N/A N/A N/A N/A N/A See Attachment 32 N/A

Note: "N/A" means not applicable.

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

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

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

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

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

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

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

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

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

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

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

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

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

Boiler ID

Emissions test results (indicate format of emission data)47,48
ATTACHMENT 1 - Gaston Report 1 Test Results

Title of Run RUN 1 RUN 2 RUN 3a RUN 3b

Date Month/Day/Year 5/12/2005 5/12/2005 5/12/2005 5/12/2005

Sampling Time -Start Military 0744 0744 1020 1020

Sampling Time -Stop Military 0952 0950 1120 1120

Number of Ports dimensionless 12 12 6 6

Number of Points per Port dimensionless 5 5 5 5

Heat Input Million Btu per Hour 2503 2403 2524 2524

Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00

Barometric Pressure Inches Mercury 30.30 30.30 30.30 30.30

Meter Correction Factor dimensionless 1.011 1.051 1.051 1.011

Oxygen Concentration Mole Percent O2 6.0 6.0 5.5 6.5

Carbon Dioxide Concentration Mole Percent CO2 12.0 11.0 13.0 13.0

Volume of Gas Metered Actual Cubic Feet 75.995 79.655 37.153 36.425

Volume of Water Collected Milliliters 141.0 122.0 63.0 68.0

Sampling Time Minutes 120 120 60 60

Nozzle Diameter Inches 0.272 0.272 0.272 0.272

Weight of Solids Collected Milligrams 52.0 54.6 30.5 22.2

Area of Stack Square Feet 432.0000 432.0000 216.0000 216.0000

Avg. Sqr. Root Velocity Pressure Inches Water 0.5965 0.6007 0.5654 0.5804

Average Orifice Pressure (DH) Inches Water 1.4 1.8 1.7 1.3

Average Stack Temperature Degrees F 258 259 264 268

Average Meter Temperature Degrees F 73 76 84 82

Average Generation MW 270 270 271 271

RUN 1 RUN 2 RUN 3a RUN 3b Average

Volume of Gas Sampled Standard Dry 77.350 83.847 38.549 36.487 78.744

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.20 29.23 29.42 29.34 39.07

Water vapor in Stack Gas Percent 7.9 6.4 7.1 8.1 9.8

Average Stack Gas Velocity Feet per second 39.1 39.4 37.1 38.3 38.8

Stack Gas Flow Rate Actual Cubic 1,014,548 1,022,514 481,166 495,767 1,004,665

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 733,852 737,729 344,892 353,680 723,384

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 675,862 690,442 320,256 325,156 670,572

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0104 0.0100 0.0122 0.0094 0.0104

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0069 0.0068 0.0081 0.0061 0.0069

 Cubic Foot

Particulate Emission Rate Pounds per Hour 60.0 59.3 33.4 26.1 49.7

Particulate Emission Rate Pounds per Million 0.0240 0.0247 0.0133 0.0103 0.0241

Allowable Particulate Emission Rate Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 102.1 108.3 107.4 100.1 104.7

TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E.C. GASTON STEAM PLANT, UNIT 1

5/12/2005

Calculations
ATTACHMENT 2 - Gaston Report 2 Test Results

Side A Side A Side A Side B Side B Side B Unit

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Average

Date Month/Day/Year 5/11/2005 5/11/2005 5/11/2005 5/11/2005 5/11/2005 5/11/2005

Sampling Time -Start Military 0810 1034 1300 0810 1034 1300

Sampling Time -Stop Military 1018 1250 1510 1018 1242 1508

Number of Ports dimensionless 16 16 16 16 16 16

Number of Points per Port dimensionless 4 4 4 4 4 4

Heat Input Million Btu per Hour 2,811 2,718 2,711 2,811 2,718 2,711

Stack Static Pressure Inches Water -22.00 -22.00 -22.00 -22.00 -22.00 -22.00

Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10 30.10 30.10

Meter Correction Factor dimensionless 1.051 1.051 1.051 1.011 1.011 1.011

Oxygen Concentration Mole Percent O2 4.0 3.6 4.0 7.8 7.3 7.5

Carbon Dioxide Concentration Mole Percent CO2 11.3 12.0 12.0 11.5 12.3 12.0

Volume of Gas Metered Actual Cubic Feet 77.854 81.175 84.369 81.700 81.910 81.830

Volume of Water Collected Milliliters 91 142 126 104 126 133

Sampling Time Minutes 128.00 128.00 128.00 128.00 128.00 128.00

Nozzle Diameter Inches 0.215 0.205 0.216 0.215 0.215 0.215

Weight of Solids Collected Milligrams 4.9 15.2 14.2 8.5 11.0 13.7

Area of Stack Square Feet 135.298 135.298 135.298 135.298 135.298 135.298

Avg. Sqr. Root Velocity Pressure Inches Water 0.8889 0.9219 0.9210 0.9728 0.9690 0.9643

Average Orifice Pressure (DH) Inches Water 1.4 1.4 1.6 1.4 1.4 1.4

Average Stack Temperature Degrees F 282 286 291 247 254 254 269

Average Meter Temperature Degrees F 82 90 96 77 84 89

Average Generation MW 270 268 269 270 268 269

Side A Side A Side A Side A Side B Side B Side B Side B Unit

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average Average

Volume of Gas Sampled Standard Dry 80.483 82.621 85.112 82.738 82.047 81.173 80.344 81.188

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.36 29.16 29.29 29.27 29.47 29.42 29.34 29.41

Water vapor in Stack Gas Percent 5.1 7.5 6.5 6.4 5.6 6.8 7.2 6.6

Average Stack Gas Velocity Feet per second 60.1 62.8 62.7 61.9 64.1 64.2 64.0 64.1

Stack Gas Flow Rate Actual Cubic 488,008 509,398 509,363 502,256 520,545 521,189 519,699 520,478 1,022,734

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 330,593 342,930 340,723 338,082 369,769 367,095 365,565 367,477 705,558

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 313,887 317,264 318,527 316,559 348,949 342,100 339,140 343,396 659,956

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0009 0.0028 0.0026 0.0021 0.0016 0.0021 0.0026 0.0021 0.0021

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0006 0.0018 0.0016 0.0013 0.0011 0.0014 0.0017 0.0014 0.0014

 Cubic Foot

Particulate Emission Rate Pounds per Hour 2.5 7.7 7.0 5.7 4.8 6.1 7.6 6.2 11.9

Particulate Emission Rate Pounds per Million 0.001 0.003 0.003 0.0021 0.002 0.002 0.003 0.0023 0.004

Isokinetic Corrected Btu (Heat Input) 0.001 0.003 0.003 0.0024 0.002 0.002 0.003 0.0023 0.005

Isokinetic Rate Percent 107.5 120.1 111.0 98.6 99.5 99.3

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E.C. GASTON STEAM PLANT, UNIT 2

5/11/2005

Calculations
ATTACHMENT 3 - Gaston Report 3 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 4/14/2005 4/14/2005 4/14/2005 4/14/2005 4/14/2005 4/14/2005

Sampling Time -Start Military 0723 0945 1204 0723 0945 1204

Sampling Time -Stop Military 0931 1153 1412 0929 1151 1410

Heat Input Million Btu per Hour 2610 2604 2596 2610 2604 2596

Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -18.00 -18.00 -18.00

Barometric Pressure Inches Mercury 29.95 29.95 29.95 29.95 29.95 29.95

Meter Correction Factor dimensionless 1.051 1.051 1.051 0.999 0.999 0.999

Oxygen Concentration Mole Percent O2 7.0 7.0 7.3 5.8 5.8 5.8

Carbon Dioxide Concentration Mole Percent CO2 11.8 11.5 11.3 11.5 12.3 12.0

Volume of Gas Metered Actual Cubic Feet 67.524 70.000 70.805 81.010 80.239 83.039

Volume of Water Collected Milliliters 94.00 100.0 108.0 124.00 121.0 139.0

Sampling Time Minutes 128 128 128 128 128 128

Nozzle Diameter Inches 0.215 0.215 0.215 0.210 0.210 0.210

Weight of Solids Collected Milligrams 5.5 12.0 2.4 4.5 3.5 2.7

Area of Stack Square Feet 134.24 134.24 134.24 134.24 134.24 134.24

Avg. Sqr. Root Velocity Pressure Inches Water 0.8048 0.8216 0.8310 0.9732 0.9660 0.9852

Average Orifice Pressure (DH) Inches Water 1.1 1.1 1.1 1.5 1.5 1.5

Average Stack Temperature Degrees F 254 257 260 229 234 240

Average Meter Temperature Degrees F 61 63 70 59 62 68

Average Generation MW 271 271 271 271 271 271

Side A Side A Side A 3 Runs Side B Side B Side B 3 Runs

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 72.146 74.517 74.365 73.676 82.739 81.514 83.431 82.561

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.457 29.400 29.316 29.391 29.275 29.394 29.266 29.312

Water vapor in Stack Gas Percent 5.8 5.9 6.4 6.0 6.6 6.5 7.3 6.8

Average Stack Gas Velocity Feet per second 53.18 54.46 55.26 54.30 63.37 62.99 64.66 63.68

Stack Gas Flow Rate Actual Cubic 428,339 438,603 445,119 437,354 510,447 507,383 520,778 512,869

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 302,885 308,879 312,209 307,991 373,974 369,168 375,758 372,967

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 285,383 290,527 292,232 289,381 349,331 345,058 348,433 347,608

 Feet Per Minute

Particulate Concentration Grains per Standard 0.00117 0.00248 0.00050 0.00138 0.00084 0.00066 0.00050 0.00067

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.00078 0.00164 0.00033 0.00092 0.00057 0.00045 0.00033 0.00045

 Cubic Foot

Particulate Emission Rate Pounds per Hour 2.87 6.18 1.24 3.43 2.51 1.96 1.49 1.98

Particulate Emission Rate Pounds per Million 0.00110 0.00237 0.00048 0.00132 0.00096 0.00075 0.00057 0.00076

 Btu (Heat Input)

Combined Particulate Emission Rate Pounds per Million 0.00206 0.00312 0.00105 0.00208

Allowable Particulate Emission Rate Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 105.1 106.7 105.8 105.9 103.2 103.0 104.4 103.5

TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

UNIT 3 E.C. GASTON STEAM PLANT

4/14/2005

Calculations
ATTACHMENT 4 - Gaston Report 4 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 3/29/2005 3/29/2005 3/29/2005

Sampling Time -Start Military 0710 0930 1140

Sampling Time -Stop Military 0910 1130 1340

Number of Ports dimensionless 12 12 12

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 2,505 2,450 2,473

Stack Static Pressure Inches Water -8.50 -8.50 -8.50

Barometric Pressure Inches Mercury 29.60 29.60 29.60

Meter Correction Factor dimensionless 1.0510 1.0510 1.0510

Oxygen Concentration Mole Percent O2 5.5 5.5 6.0

Carbon Dioxide Concentration Mole Percent CO2 13.0 13.5 13.0

Volume of Gas Metered Actual Cubic Feet 66.585 80.300 85.458

Volume of Water Collected Milliliters 149 134 147

Sampling Time Minutes 120.00 120.00 120.00

Nozzle Diameter Inches 0.266 0.288 0.293

Weight of Solids Collected Milligrams 37.5 34.6 14.2

Area of Stack Square Feet 432.000 432.000 432.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.5855 0.5863 0.5917

Average Orifice Pressure (DH) Inches Water 1.303 1.8 1.9

Average Stack Temperature Degrees F 233.45 240.6 240.2

Average Meter Temperature Degrees F 54.72 68.1 74.9

Average Generation MW 271 271 271

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 71.266 83.860 88.149 81.092

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.20 29.51 29.42 29.38

Water vapor in Stack Gas Percent 9.0 7.0 7.3 7.7

Average Stack Gas Velocity Feet per second 38.1 38.1 38.5 38.2

Stack Gas Flow Rate Actual Cubic 986,503 987,477 997,956 990,645

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 727,301 720,586 728,614 725,500

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 662,139 670,180 675,584 669,301

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0081 0.0064 0.0025 0.0056

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0054 0.0043 0.0017 0.0038

 Cubic Foot

Particulate Emission Rate Pounds per Hour 46.0 36.5 14.4 32.3

Particulate Emission Rate Pounds per Million 0.018 0.015 0.006 0.013

 Btu (Heat Input)

Isokinetic Rate Percent 100.4 99.6 100.3 100.1

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 4

Calculations
ATTACHMENT 5 - Gaston Report 5 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/23/2005 6/23/2005 6/23/2005

Sampling Time -Start Military 0808 0936 1054

Sampling Time -Stop Military 0928 1050 1207

Number of Ports dimensionless 10 10 10

Number of Points per Port dimensionless 3 3 3

Heat Input Million Btu per Hour 8,540 8,495 8,048

Stack Static Pressure Inches Water -1.50 -1.50 -1.50

Barometric Pressure Inches Mercury 30.20 30.20 30.20

Meter Correction Factor dimensionless 1.051 1.051 1.051

Oxygen Concentration Mole Percent O2 6.0 4.5 5.0

Carbon Dioxide Concentration Mole Percent CO2 15.0 15.0 14.0

Volume of Gas Metered Actual Cubic Feet 44.280 43.230 43.220

Volume of Water Collected Milliliters 65.00 81.00 100.00

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.245 0.248 0.249

Weight of Solids Collected Milligrams 16.2 17.0 19.4

Area of Stack Square Feet 812.500 812.500 812.500

Avg. Sqr. Root Velocity Pressure Inches Water 0.9000 0.8676 0.8668

Average Orifice Pressure (DH) Inches Water 2.2 2.0 2.0

Average Stack Temperature Degrees F 286 287 291

Average Meter Temperature Degrees F 76 85 89

Average Generation MW 879 878 876

3 Runs

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 46.496 44.620 44.308 45.141

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.86 29.59 29.25 29.56

Water vapor in Stack Gas Percent 6.2 7.9 9.6 7.9

Average Stack Gas Velocity Feet per second 58.9 57.1 57.5 57.8

Stack Gas Flow Rate Actual Cubic 2,870,932 2,781,190 2,802,263 2,818,128

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 2,042,213 1,977,139 1,981,677 2,000,343

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 1,916,128 1,821,497 1,791,372 1,842,999

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 143,518 136,430 134,174 138,041

Per Minute

Particulate Concentration Grains per Standard 0.0054 0.0059 0.0067 0.0060

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0036 0.0038 0.0043 0.0039

 Cubic Foot

Particulate Emission Rate Pounds per Hour 88.1 91.6 103.5 94.4

Particulate Emission Rate Pounds per Million 0.010 0.011 0.013 0.011

 Btu (Heat Input)

Allowable Particulate Emission Rate Pounds per Million 0.12 0.12 0.12 0.12

 Btu (Heat Input)

Isokinetic Rate Percent 100.3 98.9 99.0 99.4

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 5

Calculations
ATTACHMENT 6 - Gaston Report 6 Test Results 

A Side A Side A Side B Side B Side B Side

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/1/2006 6/1/2006 6/1/2006 6/1/2006 6/1/2006 6/1/2006

Sampling Time -Start Military 1050 1203 1315 1050 1203 1315

Sampling Time -Stop Military 1150 1303 1415 1150 1303 1415

Number of Ports dimensionless 6 6 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5 5 5

Heat Input Million Btu per Hour 2,572 2,571 2,571 2,572 2,571 2,571

Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00 -12.00 -12.00

Barometric Pressure Inches Mercury 29.98 29.98 29.98 29.98 29.98 29.98

Standard Orifice Pressure DH@ Inches Water 2.008 2.008 2.008 2.378 2.378 2.378

Meter Correction Factor dimensionless 0.967 0.967 0.967 0.938 0.938 0.938

Oxygen Concentration Mole Percent O2 8.0 8.0 7.0 6.5 6.0 7.0

Carbon Dioxide Concentration Mole Percent CO2 11.5 11.0 12.0 11.5 11.5 11.0

Volume of Gas Metered Actual Cubic Feet 38.714 42.490 42.455 43.499 42.593 42.200

Volume of Water Collected Milliliters 66 72 71 65 64 62

Sampling Time Minutes 60 60 60 60 60 60

Nozzle Diameter Inches 0.275 0.275 0.275 0.275 0.275 0.275

Weight of Solids Collected Milligrams 90.5 76.1 86.3 65.5 61.2 48.6

Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.6121 0.6111 0.6110 0.6163 0.6067 0.5977

Average Orifice Pressure (DH) Inches Water 1.4433 1.7423 1.7420 2.1300 2.0713 2.0020

Average Stack Temperature Degrees F 265 267 269 271 271 272

Average Meter Temperature Degrees F 83 86 87 81 82 83

Average Generation MW 269 269 269 269 269 269

A Side A Side A Side A Side B Side B Side B Side B Side

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 36.585 40.018 39.890 38.831 40.101 39.183 38.760 39.348

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.16 30.08 30.20 30.147 30.10 30.08 30.04 30.073

Water vapor in Stack Gas Percent 7.8 7.8 7.7 7.8 7.1 7.1 7.0 7.1

Average Stack Gas Velocity Feet per second 40.5 40.5 40.5 40.487 40.9 40.3 39.7 40.313

Stack Gas Flow Rate Actual Cubic 524,600 525,030 524,502 524,711 530,313 522,218 514,831 522,454

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 371,336 370,805 369,483 370,541 372,248 366,683 361,265 366,732

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 342,272 341,854 340,921 341,682 345,860 340,504 335,969 340,778

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0381 0.0293 0.0333 0.034 0.0252 0.0241 0.0193 0.023

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0249 0.0191 0.0217 0.022 0.0164 0.0157 0.0126 0.015

 Cubic Foot

Particulate Emission Rate Pounds per Hour 111.8 85.8 97.4 98.310 74.6 70.2 55.6 66.793

Particulate Emission Rate Pounds per Million 0.043 0.033 0.038 0.038 0.029 0.027 0.022 0.026

 Btu (Heat Input)

Isokinetic Rate Percent 93.3 102.1 102.1 99.174 101.2 100.4 100.7 100.753

Post Test Meter Correction Factor dimensionless 0.98 0.98 0.98 0.981 0.97 0.98 0.97 0.973

Percent Difference Allowed 5% 1.10 1.50 1.49 1.36 3.19 4.01 3.40 3.53

Combined Particulate Emission Rate Pounds per Million 0.072 0.061 0.059 0.064

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 1

Calculations
ATTACHMENT 7 - Gaston Report 7 Test Results 

A Side A Side A Side B Side B Side B Side

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/9/2006 6/9/2006 6/9/2006 6/9/2006 6/9/2006 6/9/2006

Sampling Time -Start Military 0744 0950 1154 0744 0950 1154

Sampling Time -Stop Military 0936 1142 1346 0936 1142 1346

Number of Ports dimensionless 16 16 16 16 16 16

Number of Points per Port dimensionless 4 4 4 4 4 4

Heat Input Million Btu per Hour 2,769 2,833 2,659 2,769 2,833 2,659

Stack Static Pressure Inches Water -22.00 -22.00 -22.00 -22.00 -22.00 -22.00

Barometric Pressure Inches Mercury 29.92 29.92 29.92 29.92 29.92 29.92

Standard Orifice Pressure DH@ Inches Water 2.008 2.008 2.008 2.378 2.378 2.378

Meter Correction Factor dimensionless 0.967 0.967 0.967 0.938 0.938 0.938

Oxygen Concentration Mole Percent O2 8.5 7.0 7.0 7.5 7.0 5.5

Carbon Dioxide Concentration Mole Percent CO2 10.5 11.5 11.5 11.5 10.5 11.0

Volume of Gas Metered Actual Cubic Feet 71.483 73.087 73.458 73.910 74.450 76.500

Volume of Water Collected Milliliters 133 119 114 120 111 118

Sampling Time Minutes 112 112 112 112 112 112

Nozzle Diameter Inches 0.215 0.215 0.215 0.215 0.215 0.215

Weight of Solids Collected Milligrams 14.0 15.6 20.7 11.0 18.1 22.0

Area of Stack Square Feet 135.298 135.298 135.298 135.298 135.298 135.298

Avg. Sqr. Root Velocity Pressure Inches Water 0.8966 0.9126 0.9148 0.9250 0.9416 0.9706

Average Orifice Pressure (DH) Inches Water 1.3371 1.3857 1.3911 1.6568 1.6961 1.7758

Average Stack Temperature Degrees F 281 286 289 273 275 281

Average Meter Temperature Degrees F 76 81 85 87 92 96

Average Generation MW 269 269 269 269 269 269

A Side A Side A Side A Side B Side B Side B Side B Side

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 68.367 69.194 69.054 68.872 67.146 67.144 68.472 67.587

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.02 30.12 30.12 30.09 30.14 29.96 29.98 30.03

Water vapor in Stack Gas Percent 8.4 7.5 7.2 7.7 7.8 7.2 7.5 7.5

Average Stack Gas Velocity Feet per second 61.0 62.1 62.3 61.8 62.4 63.7 65.9 64.0

Stack Gas Flow Rate Actual Cubic 495,081 503,884 506,039 501,668 506,244 517,182 535,298 519,575

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 333,493 337,253 337,177 335,974 344,953 351,438 360,888 352,426

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 305,517 311,996 312,865 310,126 318,187 326,065 333,810 326,021

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0032 0.0035 0.0046 0.0037 0.0025 0.0042 0.0049 0.0039

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0019 0.0021 0.0029 0.0023 0.0016 0.0026 0.0031 0.0024

 Cubic Foot

Particulate Emission Rate Pounds per Hour 8.3 9.3 12.4 10.0 6.9 11.6 14.2 10.9

Particulate Emission Rate Pounds per Million 0.003 0.003 0.005 0.004 0.002 0.004 0.005 0.004

 Btu (Heat Input)

Isokinetic Rate Percent 107.2 106.2 105.7 106.4 101.1 98.6 98.3 99.3

Post Test Meter Correction Factor dimensionless 0.95 0.95 0.95 0.95 0.95 0.96 0.96 0.95

Percent Difference Allowed 5% -1.88 -1.97 -1.93 -1.93 0.80 1.85 1.78 1.48

Combined Particulate Emission Rate Pounds per Million 0.005 0.007 0.010 0.008

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 2

Calculations
ATTACHMENT 8 - Gaston Report 8 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 4/26/2006 4/26/2006 4/26/2006 4/26/2006 4/26/2006 4/26/2006

Sampling Time -Start Military 0750 1015 1234 0750 1015 1234

Sampling Time -Stop Military 0958 1223 1442 0958 1233 1442

Number of Ports dimensionless 16 16 16 16 16 16

Number of Points per Port dimensionless 4 4 4 4 4 4

Heat Input Million Btu per Hour 2,575 2,618 2,616 2,575 2,618 2,616

Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -20.00 -20.00 -20.00

Barometric Pressure Inches Mercury 29.97 29.97 29.97 29.97 29.97 29.97

Standard Orifice Pressure DH@ Inches Water 1.960 1.960 1.960 2.311 2.311 2.311

Meter Correction Factor dimensionless 1.011 1.011 1.011 0.978 0.978 0.978

Oxygen Concentration Mole Percent O2 7.5 7 7.25 7.25 7.5 7

Carbon Dioxide Concentration Mole Percent CO2 12.25 12 12 11.75 11.25 11.5

Volume of Gas Metered Actual Cubic Feet 75.900 78.200 76.050 79.008 77.372 76.975

Volume of Water Collected Milliliters 126 135 124 117 127 122

Sampling Time Minutes 128 128 128 128 128 128

Nozzle Diameter Inches 0.215 0.216 0.210 0.215 0.215 0.215

Weight of Solids Collected Milligrams 16.40 15.80 17.90 20.50 14.20 18.20

Area of Stack Square Feet 134.24 134.24 134.24 134.24 134.24 134.24

Avg. Sqr. Root Velocity Pressure Inches Water 0.9437 0.9246 0.9386 0.9122 0.8901 0.8986

Average Orifice Pressure (DH) Inches Water 1.3 1.4 1.3 1.6 1.5 1.5

Average Stack Temperature Degrees F 261 264 265 254 250 250

Average Meter Temperature Degrees F 76 75 74 74 73 72

Average Generation MW 271 271 271 271 271 271

Side A Side A Side A Side A Side B Side B Side B Side B

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 76.019 78.448 76.441 76.969 76.895 75.405 75.137 75.812

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.37 29.29 29.34 29.33 29.36 29.21 29.26 29.28

Water vapor in Stack Gas Percent 7.2 7.5 7.1 7.3 6.7 7.3 7.1 7.0

Average Stack Gas Velocity Feet per second 62.7 61.7 62.6 62.3 60.5 59.0 59.5 59.7

Stack Gas Flow Rate Actual Cubic 505,247 496,759 503,998 502,002 487,469 475,218 479,477 480,721

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 354,077 346,739 351,473 350,763 343,085 336,702 339,592 339,793

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 328,452 320,757 326,540 325,250 320,155 311,970 315,480 315,868

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 24,601 24,025 24,458 24,361 23,980 23,367 23,629 23,659

Per Minute

Particulate Concentration Grains per Standard 0.0033 0.0031 0.0036 0.0033 0.0041 0.0029 0.0037 0.0036

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0022 0.0020 0.0023 0.0022 0.0027 0.0019 0.0025 0.0024

 Cubic Foot

Particulate Emission Rate Pounds per Hour 9.4 8.5 10.1 9.3 11.3 7.8 10.1 9.7

Particulate Emission Rate Pounds per Million 0.0036 0.0033 0.0039 0.0036 0.0044 0.0030 0.0039 0.0037

 Btu (Heat Input)

Combined Particulate Emission Rate Pounds per Million 0.0080 0.0062 0.0077 0.0073

Allowable 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 96.3 100.8 102.0 99.7 99.9 100.5 99.1 99.8

Post Test Meter Correction Factor dimensionless 1.04 1.03 1.01 1.03 1.00 1.00 1.01 1.00

Percent Difference Allowed 5% 2.84 1.70 0.01 1.52 2.45 2.11 3.15 2.57

Calculations

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 3
ATTACHMENT 9 - Gaston Report 9 Test Results 

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 2/9/2006 2/9/2006 2/9/2006 2/9/2006 2/9/2006 2/9/2006

Sampling Time -Start Military 0756 0917 1041 0756 0917 1041

Sampling Time -Stop Military 0856 1017 1141 0856 1017 1141

Number of Ports dimensionless 6 6 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5 5 5

Heat Input Million Btu per Hour 2,663 2,656 2,658 2,663 2,656 2,658

Stack Static Pressure Inches Water -9.00 -9.00 -9.00 -9.00 -9.00 -9.00

Barometric Pressure Inches Mercury 30.20 30.20 30.20 30.20 30.20 30.20

Standard Orifice Pressure DH@ Inches Water 2.03 2.03 2.03 2.35 2.35 2.35

Meter Correction Factor dimensionless 1.004 1.004 1.004 0.988 0.988 0.988

Oxygen Concentration Mole Percent O2 7.0 7.5 7.0 7.5 7.5 7.5

Carbon Dioxide Concentration Mole Percent CO2 12.0 11.5 12.0 12.0 11.5 11.5

Volume of Gas Metered Actual Cubic Feet 41.000 38.400 37.950 35.612 34.508 35.085

Volume of Water Collected Milliliters 61.00 52.00 55.00 55.00 57.00 53.00

Sampling Time Minutes 60 60 60 60 60 60

Nozzle Diameter Inches 0.280 0.275 0.275 0.275 0.275 0.275

Weight of Solids Collected Milligrams 14.1 25.1 15.3 15.9 19.7 38.7

Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.5765 0.5655 0.5955 0.5359 0.5430 0.5599

Average Orifice Pressure (DH) Inches Water 1.6 1.4 1.6 1.6 1.6 1.7

Average Stack Temperature Degrees F 228 231 233 229 235 232

Average Meter Temperature Degrees F 46 47 49 44 44 48

Average Generation MW 270 270 269 270 270 269

Side A Side A Side A Side A Side B Side B Side B Side B Combined

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average Average

Volume of Gas Sampled Standard Dry 43.526 40.667 40.057 41.417 37.333 36.171 36.554 36.686 39.128

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.45 29.45 29.46 29.45 29.43 29.30 29.36 29.36 29.410

Water vapor in Stack Gas Percent 6.2 5.7 6.1 6.0 6.5 6.9 6.4 6.6 6.276

Average Stack Gas Velocity Feet per second 36.8 36.2 38.2 37.0 34.3 34.9 35.9 35.0 36.072

Stack Gas Flow Rate Actual Cubic 476,955 468,803 494,497 480,085 443,967 452,840 465,353 454,053 934,138

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 361,452 353,850 371,843 362,382 335,769 339,424 350,501 341,898 704,280

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 339,084 333,762 349,270 340,705 313,995 315,986 328,109 319,363 660,069

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 25,397 24,999 26,160 25,519 23,518 23,667 24,575 23,920 49,439

Per Minute

Particulate Concentration Grains per Standard 0.0050 0.0095 0.0059 0.0068 0.0066 0.0084 0.0163 0.0104 0.0085

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0035 0.0068 0.0042 0.0048 0.0046 0.0059 0.0115 0.0073 0.0060

 Cubic Foot

Particulate Emission Rate Pounds per Hour 14.5 27.2 17.6 19.8 17.7 22.7 45.9 28.7 48.5

Particulate Emission Rate Pounds per Million 0.005 0.010 0.007 0.007 0.007 0.009 0.017 0.011 0.018

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 108.0 106.3 100.1 104.8 103.8 99.9 97.2 100.3

Post Test Meter Correction Factor dimensionless 0.96 0.95 1.01 0.97 1.00 1.04 1.05 1.03

Difference (Allowed 5%) Percent -4.81 -5.28 0.78 -3.10 1.32 4.75 -1.06 1.67

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 4

Calculations
ATTACHMENT 10 - Gaston Report 10 Test Results 

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 5/16/2006 5/16/2006 5/16/2006

Sampling Time -Start Military 0736 0852 1010

Sampling Time -Stop Military 0842 0956 1115

Number of Ports dimensionless 10 10 10

Number of Points per Port dimensionless 3 3 3

Heat Input Million Btu per Hour 8,310 8,353 8,324

Stack Static Pressure Inches Water -21.50 -21.00 -21.00

Barometric Pressure Inches Mercury 29.95 29.95 29.95

Standard Orifice Pressure DH@ Inches Water 1.96 1.96 1.96

Meter Correction Factor dimensionless 1.011 1.011 1.011

Oxygen Concentration Mole Percent O2 5.5 4.0 6.5

Carbon Dioxide Concentration Mole Percent CO2 13.5 13.5 14.5

Volume of Gas Metered Actual Cubic Feet 47.025 42.305 47.600

Volume of Water Collected Milliliters 74.00 65.00 88.00

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.245 0.228 0.245

Weight of Solids Collected Milligrams 20.1 20.6 26.8

Area of Stack Square Feet 812.500 812.500 812.500

Avg. Sqr. Root Velocity Pressure Inches Water 0.9563 0.9945 0.9675

Average Orifice Pressure (DH) Inches Water 2.38 1.92 2.41

Average Stack Temperature Degrees F 269 270 274

Average Meter Temperature Degrees F 54 64 65

Average Generation MW 886 885 884

RUN 1 RUN 2 RUN 3 AVERAGE

Volume of Gas Sampled Standard Dry 49.184 43.392 48.711 47.095

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.38 30.32 30.58 30.43

Water vapor in Stack Gas Percent 6.6 6.6 7.8 7.0

Average Stack Gas Velocity Feet per second 64.0 66.6 64.9 65.2

Stack Gas Flow Rate Actual Cubic 3,119,924 3,248,819 3,163,910 3,177,551

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 2,143,277 2,229,817 2,160,686 2,177,927

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 2,001,529 2,082,949 1,991,350 2,025,276

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 149,915 156,013 149,152 151,693

Per Minute

Particulate Concentration Grains per Standard 0.0063 0.0073 0.0085 0.0074

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0040 0.0047 0.0053 0.0047

 Cubic Foot

Particulate Emission Rate Pounds per Hour 108.0 130.5 144.6 127.7

Particulate Emission Rate Pounds per Million 0.013 0.016 0.017 0.015

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 101.6 99.5 101.2 100.8

Post Test Meter Correction Factor dimensionless 1.01 1.02 1.02 1.02

Percent Difference Allowed 5% 0.23 1.09 0.40 0.57

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 5

Calculations
ATTACHMENT 11 - Gaston Report 11 Test Results 

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 5/8/2007 5/8/2007 5/8/2007 5/8/2007 5/8/2007 5/8/2007

Sampling Time -Start Military 0806 0924 1042 0806 0924 1042

Sampling Time -Stop Military 0906 1024 1144 0906 1024 1142

Number of Ports dimensionless 6 6 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5 5 5

Heat Input Million Btu per Hour 2,523 2,456 2,471 2,523 2,456 2,471

Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.50 -12.50 -12.50

Barometric Pressure Inches Mercury 30.15 30.15 30.15 30.15 30.15 30.15

Standard Orifice Pressure DH@ Inches Water 2.258 2.258 2.258 1.896 1.896 1.896

Meter Correction Factor dimensionless 0.982 0.982 0.982 0.986 0.986 0.986

Oxygen Concentration Mole Percent O2 6.5 6.5 6.5 6.5 6.5 6.5

Carbon Dioxide Concentration Mole Percent CO2 10.0 10.0 10.0 10.0 10.0 10.0

Volume of Gas Metered Actual Cubic Feet 38.800 38.280 38.182 47.690 53.060 56.390

Volume of Water Collected Milliliters 62 60 55 42 77 77

Sampling Time Minutes 60 60 60 60 60 60

Nozzle Diameter Inches 0.276 0.275 0.275 0.273 0.275 0.275

Weight of Solids Collected Milligrams 33.4 52.0 45.0 46.6 49.0 61.0

Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.5974 0.6083 0.6012 0.7388 0.8069 0.8292

Average Orifice Pressure (DH) Inches Water 1.8 1.8 1.8 2.3 2.9 3.0

Average Stack Temperature Degrees F 272 277 279 268 271 277

Average Meter Temperature Degrees F 58 64 67 68 90 101

Average Generation MW 270 270 270 270 270 270

 Side A Side B Weighted

Side A Side A Side A Side A Side B Side B Side B Side B Combined 3 Runs 3 Runs 3 Runs 6 Runs

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average Average AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 39.343 38.373 38.007 38.575 47.661 50.950 53.164 50.591 44.583 38.575 38.575 50.591 45.430

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.86 29.86 29.86 29.86 29.86 29.86 29.86 29.86 29.86 29.86 29.86 29.86 29.860

Water vapor in Stack Gas Percent 6.9 6.9 6.4 6.7 4.0 6.6 6.4 5.7 6.2 6.7 6.7 5.7 6.117

Average Stack Gas Velocity Feet per second 39.8 40.7 40.2 40.2 48.8 53.7 55.4 52.7 46.4 40.2 40.2 52.7 47.317

Stack Gas Flow Rate Actual Cubic 515,946 526,994 520,976 521,305 632,704 696,409 718,179 682,431 1,203,736 521,305 521,305 682,431 1,203,736

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 363,881 369,251 364,128 365,753 448,403 491,254 502,531 480,729 846,483 365,753 365,753 480,729 846,483

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 338,753 343,938 340,907 341,199 430,544 458,629 470,458 453,210 794,410 341,199 341,199 453,210 794,410

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 25,373 25,761 25,534 25,556 32,248 34,351 35,237 33,945 59,501 25,556 25,556 33,945 59,501

Per Minute

Particulate Concentration Grains per Standard 0.013 0.021 0.018 0.017 0.015 0.015 0.018 0.016 0.017 0.017 0.017 0.016 0.017

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.009 0.014 0.012 0.011 0.010 0.010 0.012 0.011 0.011 0.011 0.011 0.011 0.011

 Cubic Foot

Particulate Emission Rate Pounds per Hour 38.0 61.5 53.3 50.9 55.6 58.2 71.3 61.7 112.6 50.9 50.9 61.7 112.6

Particulate Emission Rate Pounds per Million 0.015 0.025 0.022 0.021 0.022 0.024 0.029 0.025 0.045 0.021 0.021 0.025 0.045

 Btu (Heat Input)

Isokinetic Rate Percent 100.6 97.4 97.3 98.4 98.0 96.9 98.6 97.9 98.1 98.4 98.4 97.9

Post Test Meter Correction Factor dimensionless 0.99 1.03 1.02 1.01 1.01 1.05 1.02 1.03 1.02 1.01 1.01 1.03

Percent Difference Allowed 5% 1.0 4.6 4.0 3.2 2.7 6.0 3.1 3.9 3.6 3.2 3.2 3.9

Combined Particulate Emission Rate Pounds per Million 0.037 0.049 0.050 0.045

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 1

Calculations
ATTACHMENT 12 - Gaston Report 12 Test Results 

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 8/23/2007 8/23/2007 8/23/2007 8/23/2007 8/23/2007 8/23/2007

Sampling Time -Start Military 1026 1204 1332 1026 1204 1332

Sampling Time -Stop Military 1130 1308 1436 1130 1308 1436

Number of Ports dimensionless 8 8 8 8 8 8

Number of Points per Port dimensionless 4 4 4 4 4 4

Heat Input Million Btu per Hour 2,542 2,523 2,527 2,542 2,523 2,527

Stack Static Pressure Inches Water -22.00 -22.00 -22.00 -22.00 -22.00 -22.00

Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10 30.10 30.10

Standard Orifice Pressure DH@ Inches Water 1.939 1.939 1.939 2.418 2.418 2.418

Meter Correction Factor dimensionless 0.981 0.981 0.981 0.939 0.939 0.939

Oxygen Concentration Mole Percent O2 8.5 9.0 9.0 8.5 8.5 8.5

Carbon Dioxide Concentration Mole Percent CO2 11.0 11.0 11.0 12.5 12.5 12.5

Volume of Gas Metered Actual Cubic Feet 57.945 48.220 44.860 45.381 43.849 44.800

Volume of Water Collected Milliliters 81 69 55 82 73 77

Sampling Time Minutes 64 64 64 64 64 64

Nozzle Diameter Inches 0.262 0.236 0.225 0.215 0.213 0.213

Weight of Solids Collected Milligrams 9.2 8.8 11.6 16.1 16.4 13.5

Area of Stack Square Feet 135.298 135.298 135.298 135.298 135.298 135.298

Avg. Sqr. Root Velocity Pressure Inches Water 0.9161 0.8952 0.9081 1.0006 0.9774 0.9951

Average Orifice Pressure (DH) Inches Water 2.9 1.9 1.6 2.1 2.0 2.0

Average Stack Temperature Degrees F 287 290 290 263 274 276

Average Meter Temperature Degrees F 99 110 106 94 97 99

Average Generation MW 265 265 265 265 265 265

Side A Side A Side A Side B Side B Side B Side A Side B

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 54.389 44.265 41.492 41.109 39.487 40.210 46.715 40.268

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.10 30.12 30.12 30.34 30.34 30.34 30.11 30.34

Water vapor in Stack Gas Percent 6.6 6.8 5.9 8.6 8.0 8.3 6.4 8.3

Average Stack Gas Velocity Feet per second 62.2 60.9 61.7 66.9 65.8 67.1 61.6 66.6

Stack Gas Flow Rate Actual Cubic 505,230 494,756 500,892 543,112 533,782 544,545 500,293 540,480

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 339,718 331,414 335,525 377,296 365,413 371,721 335,552 371,477

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 317,464 308,760 315,819 344,912 336,161 340,985 314,014 340,686

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 23,778 23,126 23,655 25,834 25,178 25,540 23,520 25,517

Per Minute

Particulate Concentration Grains per Standard 0.003 0.003 0.004 0.006 0.006 0.005 0.003 0.006

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.002 0.002 0.003 0.004 0.004 0.003 0.002 0.004

 Cubic Foot

Particulate Emission Rate Pounds per Hour 7.1 8.1 11.7 17.8 18.4 15.1 8.9 17.1

Particulate Emission Rate Pounds per Million 0.003 0.003 0.005 0.007 0.007 0.006 0.004 0.007

 Btu (Heat Input)

Isokinetic Rate Percent 96.7 99.7 100.6 99.9 100.3 100.7 99.0 100.3

Post Test Meter Correction Check (Yqa) dimensionless 1.02 0.99 0.98 0.98 0.98 0.98 1.00 0.98

Percent Difference Allowed 5% Average 3.5 1.3 0.2 4.5 4.3 4.0 1.7 4.3

Combined Particulate Emission Rate Pounds per Million 0.010 0.011 0.011 0.010

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 2

Calculations
ATTACHMENT 13 - Gaston Report 13 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 5 RUN 6 RUN 7

Date Month/Day/Year 2/13/2007 2/13/2007 2/13/2007 2/13/2007 2/13/2007 2/13/2007

Sampling Time -Start Military 0720 1004 1230 0720 1004 1230

Sampling Time -Stop Military 0928 1212 1438 0928 1212 1438

Number of Ports dimensionless 16 16 16 16 16 16

Number of Points per Port dimensionless 4 4 4 4 4 4

Heat Input Million Btu per Hour 2,539 2,567 2,530 2,539 2,567 2,530

Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -20.00 -20.00 -20.00

Barometric Pressure Inches Mercury 29.80 29.80 29.80 29.80 29.80 29.80

Standard Orifice Pressure DH@ Inches Water 1.939 1.939 1.939 2.418 2.418 2.418

Meter Correction Factor dimensionless 0.981 0.981 0.981 0.939 0.939 0.939

Oxygen Concentration Mole Percent O2 8.0 6.0 6.5 8.0 7.0 7.5

Carbon Dioxide Concentration Mole Percent CO2 12.0 12.5 13.0 12.0 12.5 12.0

Volume of Gas Metered Actual Cubic Feet 76.671 74.804 79.309 76.749 80.209 76.082

Volume of Water Collected Milliliters 98 114 121 76 130 112

Sampling Time Minutes 128 128 128 128 128 128

Nozzle Diameter Inches 0.215 0.212 0.215 0.218 0.218 0.213

Weight of Solids Collected Milligrams 35.8 61.6 53.5 32.9 51.4 43.1

Area of Stack Square Feet 134.24 134.24 134.24 134.24 134.24 134.24

Avg. Sqr. Root Velocity Pressure Inches Water 0.8969 0.8941 0.9132 0.8133 0.8541 0.8380

Average Orifice Pressure (DH) Inches Water 1.2 1.2 1.3 1.4 1.5 1.3

Average Stack Temperature Degrees F 263 263 304 257 261 261

Average Meter Temperature Degrees F 63 61 66 70 69 73

Average Generation MW 269 269 269 269 269 269

Side A Side A Side A Side A Side B Side B Side B Side B

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 75.903 74.294 78.046 76.081 71.800 75.184 70.712 72.566

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.24 30.24 30.34 30.273 30.24 30.28 30.22 30.247

Water vapor in Stack Gas Percent 5.7 6.7 6.8 6.4 4.7 7.5 6.9 6.4

Average Stack Gas Velocity Feet per second 59.7 59.6 62.5 60.6 54.0 57.1 56.0 55.7

Stack Gas Flow Rate Actual Cubic 480,831 480,418 503,619 488,289 434,548 459,812 451,221 448,527

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 334,127 333,746 331,161 333,011 302,808 318,829 312,608 311,415

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 314,985 311,265 308,637 311,629 288,437 294,833 290,919 291,396

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 23,592 23,314 23,117 23,341 21,604 22,083 21,790 21,826

Per Minute

Particulate Concentration Grains per Standard 0.007 0.013 0.011 0.010 0.007 0.011 0.009 0.009

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.005 0.008 0.006 0.007 0.005 0.007 0.006 0.006

 Cubic Foot

Particulate Emission Rate Pounds per Hour 19.6 34.1 27.9 27.201 17.4 26.6 23.4 22.486

Particulate Emission Rate Pounds per Million 0.008 0.013 0.011 0.011 0.007 0.010 0.009 0.009

 Btu (Heat Input)

Combined Particulate Emission Rate Pounds per Million 0.015 0.024 0.020 0.020

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 100.2 102.1 105.2 102.494 100.7 103.2 103.0 102.282

Post Test Meter Correction Factor dimensionless 0.98 0.97 0.96 0.97 0.93 0.93 0.92 0.93

Percent Difference Allowed 5% -0.3 -1.1 -1.6 -1.0 -1.2 -0.4 -1.9 -1.2

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 3

Calculations
ATTACHMENT 14 - Gaston Report 14 Test Results

SIDE A SIDE A SIDE A SIDE B SIDE B SIDE B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 4/18/2007 4/18/2007 4/18/2007 4/18/2007 4/18/2007 4/18/2007

Sampling Time -Start Military 0722 0843 0957 0722 0840 0957

Sampling Time -Stop Military 0822 0943 1057 0822 0940 1057

Number of Ports dimensionless 6 6 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5 5 5

Heat Input Million Btu per Hour 2,550 2,566 2,576 2,550 2,566 2,576

Stack Static Pressure Inches Water -9.00 -9.00 -9.00 -9.00 -9.00 -9.00

Barometric Pressure Inches Mercury 30.05 30.05 30.05 30.05 30.05 30.05

Standard Orifice Pressure DH@ Inches Water 2.418 2.418 2.418 1.939 1.939 1.939

Meter Correction Factor dimensionless 0.939 0.939 0.939 0.981 0.981 0.981

Oxygen Concentration Mole Percent O2 9 10 7 6 7 7

Carbon Dioxide Concentration Mole Percent CO2 10 9 12 10 11 11

Volume of Gas Metered Actual Cubic Feet 45.262 45.455 43.270 40.195 40.485 40.810

Volume of Water Collected Milliliters 54 71 58 43 45 43

Sampling Time Minutes 60 60 60 60 60 60

Nozzle Diameter Inches 0.277 0.278 0.272 0.277 0.277 0.277

Weight of Solids Collected Milligrams 62.9 33.2 123.3 59.3 43.4 39.6

Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.6293 0.6240 0.6093 0.5873 0.5879 0.6005

Average Orifice Pressure (DH) Inches Water 2.2 2.2 2.0 1.6 1.6 1.7

Average Stack Temperature Degrees F 254 255 256 255 258 261

Average Meter Temperature Degrees F 67 72 72 59 62 61

Average Generation MW 271 271 271 271 271 271

Side A Side A Side A Side B Side B Side B Side A Side B

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Average Average

Volume of Gas Sampled Standard Dry 42.994 42.783 40.708 40.462 40.526 40.911 42.162 40.633

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.96 29.84 30.20 29.84 30.04 30.04 30.00 29.97

Water vapor in Stack Gas Percent 5.6 7.2 6.3 4.8 5.0 4.7 6.4 4.8

Average Stack Gas Velocity Feet per second 41.2 41.1 39.8 38.4 38.4 39.3 40.7 38.7

Stack Gas Flow Rate Actual Cubic 533,336 532,094 515,663 498,208 498,254 509,645 527,031 502,036

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 387,255 385,668 373,672 361,209 359,866 366,747 382,198 362,607

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 365,639 357,725 350,187 344,001 341,991 349,458 357,850 345,150

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 27,386 26,794 26,229 25,766 25,615 26,174 26,803 25,852

Per Minute

Particulate Concentration Grains per Standard 0.023 0.012 0.047 0.023 0.016 0.015 0.027 0.018

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.015 0.008 0.032 0.016 0.011 0.010 0.018 0.012

 Cubic Foot

Particulate Emission Rate Pounds per Hour 70.6 36.6 140.0 66.5 48.3 44.7 82.4 53.2

Particulate Emission Rate Pounds per Million 0.028 0.014 0.054 0.026 0.019 0.017 0.032 0.021

 Btu (Heat Input)

Combined Particulate Emission Rate Pounds per Million 0.054 0.033 0.072 0.053

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 101.1 102.1 103.7 101.2 101.9 100.7 102.3 101.3

Post Test Meter Correction Factor dimensionless 0.94 0.94 0.92 0.99 0.98 0.99 0.93 0.99

Percent Difference Allowed 5% -0.3 0.0 -1.7 0.8 -0.2 1.2 -0.7 0.6

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 4

Calculations
ATTACHMENT 15 - Gaston Report 15 Test Results 

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 5/10/2007 5/10/2007 5/10/2007

Sampling Time -Start Military 0726 1456 1618

Sampling Time -Stop Military 1416 1608 1730

Number of Ports dimensionless 10 10 10

Number of Points per Port dimensionless 3 3 3

Heat Input Million Btu per Hour 7,970 7,970 7,970

Stack Static Pressure Inches Water -21.50 -21.50 -21.50

Barometric Pressure Inches Mercury 29.90 29.90 29.90

Standard Orifice Pressure DH@ Inches Water 1.896 1.896 1.896

Meter Correction Factor dimensionless 0.986 0.986 0.986

Oxygen Concentration Mole Percent O2 6.5 6 5.5

Carbon Dioxide Concentration Mole Percent CO2 13 12.5 13.5

Volume of Gas Metered Actual Cubic Feet 48.445 44.633 38.052

Volume of Water Collected Milliliters 77 82 64

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.239 0.230 0.210

Weight of Solids Collected Milligrams 39.4 79.5 47.3

Area of Stack Square Feet 812.500 812.500 812.500

Avg. Sqr. Root Velocity Pressure Inches Water 1.0282 1.0482 1.0370

Average Orifice Pressure (DH) Inches Water 2.5 2.3 1.5

Average Stack Temperature Degrees F 307 324 323

Average Meter Temperature Degrees F 93 115 114

Average Generation MW 886 886 886

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 45.880 40.645 34.654 40.393

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.34 30.24 30.38 30.32

Water vapor in Stack Gas Percent 7.3 8.7 8.0 8.0

Average Stack Gas Velocity Feet per second 70.8 73.3 72.2 72.1

Stack Gas Flow Rate Actual Cubic 3,452,617 3,574,053 3,519,827 3,515,499

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 2,248,476 2,277,181 2,247,026 2,257,561

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 2,083,859 2,079,687 2,067,313 2,076,953

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 156,081 155,769 154,842 155,564

Per Minute

Particulate Concentration Grains per Standard 0.013 0.030 0.021 0.021

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.008 0.018 0.012 0.013

 Cubic Foot

Particulate Emission Rate Pounds per Hour 236.2 537.0 372.5 381.9

Particulate Emission Rate Pounds per Million 0.030 0.067 0.047 0.048

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 95.7 91.7 94.4 93.9

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 5

Calculations
ATTACHMENT 16 - Gaston Report 16 Test Results

Title of Run RUN 1 RUN 2 RUN 3A RUN 3B

Date Month/Day/Year 4/17/2008 4/17/2008 4/17/2008 4/17/2008

Sampling Time -Start Military 0915 0915 1144 1144

Sampling Time -Stop Military 1115 1115 1244 1244

Number of Ports dimensionless 12 12 12 12

Number of Points per Port dimensionless 5 5 5 5

Heat Input Million Btu per Hour 2,854 2,854 2,861 2,861

Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00

Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10

Standard Orifice Pressure DH@ Inches Water 2.206 2.258 2.206 2.258

Meter Correction Factor dimensionless 0.970 0.982 0.970 0.982

Oxygen Concentration Mole Percent O2 7.0 6.0 6.5 8.50

Carbon Dioxide Concentration Mole Percent CO2 12.3 12.5 12.5 13.00

Volume of Gas Metered Actual Cubic Feet 76.445 77.230 36.625 38.125

Volume of Water Collected Milliliters 95.6 101.0 25.6 51.0

Sampling Time Minutes 120 120 60 60

Nozzle Diameter Inches 0.275 0.276 0.275 0.274

Weight of Solids Collected Milligrams 64.9 72.3 52.2 32.6

Area of Stack Square Feet 432.000 432.000 216.000 216.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.5843 0.5804 0.5701 0.6256

Average Orifice Pressure (DH) Inches Water 1.6 1.7 1.5 1.9

Average Stack Temperature Degrees F 249 252 251 263

Average Meter Temperature Degrees F 63 58 69 66

Average Generation MW 271 271 271 271

RUN 1 RUN 2 RUN 3A RUN 3B AVERAGE

Volume of Gas Sampled Standard Dry 75.567 78.076 35.804 37.991 75.8

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.24 30.24 30.26 30.42 30.27

Water vapor in Stack Gas Percent 5.6 5.7 3.3 5.9 5.3

Average Stack Gas Velocity Feet per second 38.0 37.9 36.9 41.0 38.3

Stack Gas Flow Rate Actual Cubic 985,289 981,340 478,818 531,576 992,341

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 716,552 710,105 347,289 378,958 717,635

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 676,281 669,348 335,982 356,436 679,349

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 50,653 50,134 25,165 26,697 50,883

Per Minute

Particulate Concentration Grains per Standard 0.013 0.014 0.022 0.013 0.015

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.009 0.010 0.016 0.009 0.010

 Cubic Foot

Particulate Emission Rate Pounds per Hour 76.7 81.8 64.7 40.4 87.8

Particulate Emission Rate Pounds per Million 0.027 0.029 0.023 0.014 0.031

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 97.5 101.0 93.0 93.7 97.3

Post Test Meter Correction Check dimensionless 0.97 0.97 1.00 1.04 0.99

Percent Difference Allowed 5% Average -0.1 -1.2 2.6 5.9 1.0

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GASTON STEAM PLANT

UNIT 1

Calculations
ATTACHMENT 17 - Gaston Report 17 Test Results

SIDE A SIDE A SIDE A SIDE B SIDE B SIDE B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 7/9/2008 7/9/2008 7/9/2008 7/9/2008 7/9/2008 7/9/2008

Sampling Time -Start Military 0800 0938 1106 0800 0938 1106

Sampling Time -Stop Military 0904 1042 1210 0904 1042 1210

Number of Ports dimensionless 8 8 8 8 8 8

Number of Points per Port dimensionless 4 4 4 4 4 4

Heat Input Million Btu per Hour 2,775 2,778 2,738 2,775 2,778 2,738

Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -21.00 -21.00 -21.00

Barometric Pressure Inches Mercury 29.97 29.97 29.97 29.97 29.97 29.97

Standard Orifice Pressure DH@ Inches Water 2.211 2.211 2.211 1.939 1.939 1.939

Meter Correction Factor dimensionless 0.927 0.927 0.927 0.981 0.981 0.981

Oxygen Concentration Mole Percent O2 9.0 7.5 8.5 7.5 7.5 8.0

Carbon Dioxide Concentration Mole Percent CO2 11.0 9.0 10.0 10.5 10.5 11.0

Volume of Gas Metered Actual Cubic Feet 46.442 45.495 44.692 41.405 46.055 46.460

Volume of Water Collected Milliliters 67.0 62.0 66.0 64.8 78.4 80.1

Sampling Time Minutes 64 64 64 64 64 64

Nozzle Diameter Inches 0.220 0.218 0.215 0.215 0.218 0.218

Weight of Solids Collected Milligrams 157.7 91.9 109.6 21.4 49.7 21.0

Area of Stack Square Feet 135.298 135.298 135.298 135.298 135.298 135.298

Avg. Sqr. Root Velocity Pressure Inches Water 0.9478 0.9541 0.9499 0.8943 1.0134 1.0176

Average Orifice Pressure (DH) Inches Water 1.8 1.8 1.7 1.3 1.7 1.7

Average Stack Temperature Degrees F 281 284 288 264 268 271

Average Meter Temperature Degrees F 82 85 87 85 90 92

Average Generation MW 270 270 270 270 270 270

Combined

Flowrate

Weighted

 Side A Side B TOTAL or

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 42.236 41.099 40.204 39.518 43.673 43.833 41.179 42.341 83.521

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.12 29.74 29.94 29.98 29.98 30.08 29.93 30.01 29.97

Water vapor in Stack Gas Percent 6.9 6.6 7.2 7.2 7.8 7.9 6.9 7.6 7.3

Average Stack Gas Velocity Feet per second 64.0 64.9 64.6 60.0 68.3 68.7 64.5 65.7 65.1

Stack Gas Flow Rate Actual Cubic 519,401 526,640 524,654 487,332 554,725 557,470 523,565 533,175 1,056,741

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 354,059 357,681 354,382 337,729 382,007 382,289 355,374 367,342 722,716

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 329,459 333,967 328,963 313,529 352,243 352,011 330,796 339,261 670,057

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 24,676 25,014 24,639 23,483 26,383 26,366 24,777 25,411 50,187

Per Minute

Particulate Concentration Grains per Standard 0.058 0.034 0.042 0.008 0.018 0.007 0.045 0.011 0.028

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.036 0.022 0.026 0.005 0.011 0.005 0.028 0.007 0.017

 Cubic Foot

Particulate Emission Rate Pounds per Hour 162.4 98.6 118.4 22.4 52.9 22.3 126.4 32.5 159.0

Particulate Emission Rate Pounds per Million 0.059 0.035 0.043 0.008 0.019 0.008 0.046 0.012 0.057

 Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 102.6 100.3 102.5 105.7 101.1 101.5 101.8 102.8

Post Test Meter Correction Check dimensionless 0.92 0.95 0.93 0.93 0.97 0.97 0.93 0.96

Percent Difference Allowed 5% Average -0.9 1.8 0.4 -4.7 -1.0 -1.6 0.4 -2.4

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 2

Calculations
ATTACHMENT 18 - Gaston Report 18 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 5/28/2008 5/28/2008 5/28/2008 5/28/2008 5/28/2008 5/28/2008

Sampling Time -Start Military 0829 0958 1122 0829 0958 1122

Sampling Time -Stop Military 0933 1102 1226 0933 1102 1226

Number of Ports dimensionless 8 8 8 8 8 8

Number of Points per Port dimensionless 4 4 4 4 4 4

Heat Input Million Btu per Hour 2,623 2,681 2,559 2,623 2,681 2,559

Stack Static Pressure Inches Water -19.0 -19.0 -19.0 -18.0 -18.0 -18.0

Barometric Pressure Inches Mercury 30.05 30.05 30.05 30.05 30.05 30.05

Standard Orifice Pressure DH@ Inches Water 1.939 1.939 1.939 2.211 2.211 2.211

Meter Correction Factor dimensionless 0.981 0.981 0.981 0.927 0.927 0.927

Oxygen Concentration Mole Percent O2 8.5 7.5 6.5 8.0 9.0 5.5

Carbon Dioxide Concentration Mole Percent CO2 12.5 12.0 12.5 13.0 12.5 12.5

Volume of Gas Metered Actual Cubic Feet 41.788 41.575 42.078 42.592 42.640 52.026

Volume of Water Collected Milliliters 66.1 69.8 78.1 55.0 74.0 88.0

Sampling Time Minutes 64 64 64 64 64 64

Nozzle Diameter Inches 0.221 0.218 0.216 0.221 0.217 0.220

Weight of Solids Collected Milligrams 7.3 15.7 17.1 8.9 10.0 17.1

Area of Stack Square Feet 134.240 134.240 134.240 134.240 134.240 134.240

Avg. Sqr. Root Velocity Pressure Inches Water 0.896 0.916 0.943 0.877 0.926 1.085

Average Orifice Pressure (DH) Inches Water 1.37 1.39 1.42 1.51 1.58 2.28

Average Stack Temperature Degrees F 262 264 270 270 271 271

Average Meter Temperature Degrees F 78 82 84 76 79 81

Average Generation MW 270 268 270 270 268 270

 Sides A & B

Combined

Side A Side A Side A Side B Side B Side B Side A Side B TOTAL or

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 40.586 40.053 40.387 39.229 39.070 47.569 40.342 41.956 82.298

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.34 30.22 30.26 30.40 30.36 30.22 30.27 30.33 30.30

Water vapor in Stack Gas Percent 7.1 7.6 8.3 6.2 8.2 8.0 7.7 7.5 7.6

Average Stack Gas Velocity Feet per second 59.5 61.1 63.2 58.3 61.9 72.7 61.2 64.3 62.8

Stack Gas Flow Rate Actual Cubic 479,040 491,966 508,862 469,274 498,374 585,155 493,289 517,601 1,010,890

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 335,271 343,352 352,376 325,992 345,688 405,986 343,666 359,222 702,888

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 311,399 317,323 322,977 305,810 317,392 373,466 317,233 332,223 649,456

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 23,324 23,767 24,191 22,905 23,773 27,973 23,761 24,883 48,644

Per Minute

Particulate Concentration Grains per Standard 0.0028 0.0060 0.0065 0.0035 0.0039 0.0055 0.0051 0.0043 0.0047

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0018 0.0039 0.0041 0.0023 0.0025 0.0035 0.0033 0.0028 0.0030

 Cubic Foot

Particulate Emission Rate Pounds per Hour 7.4 16.4 18.1 9.2 10.7 17.7 14.0 12.5 26.5

Particulate Emission Rate Pounds per Million 0.0028 0.0061 0.0071 0.0035 0.0040 0.0069 0.0053 0.0048 0.0101

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 102.6 102.1 103.1 101.0 100.5 101.2 102.6 100.9

Post Test Meter Correction Check dimensionless 0.949 0.968 0.968 0.913 0.935 0.924 0.962 0.924

Percent Difference Allowed 5% Average -3.2 -1.3 -1.3 -1.4 0.8 -0.3 -1.9 -0.3

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 3

Calculations
ATTACHMENT 19 - Gaston Report 19 Test Results 

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 5/29/2008 5/29/2008 5/29/2008 5/29/2008 5/29/2008 5/29/2008

Sampling Time -Start Military 0734 0850 1024 0734 0850 1024

Sampling Time -Stop Military 0834 0950 1124 0834 0950 1124

Number of Ports dimensionless 6 6 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5 5 5

Heat Input Million Btu per Hour 2,579 2,585 2,583 2,579 2,585 2,583

Stack Static Pressure Inches Water -9.00 -9.00 -9.00 -9.00 -9.00 -9.00

Barometric Pressure Inches Mercury 29.80 29.80 29.80 29.80 29.80 29.80

Standard Orifice Pressure DH@ Inches Water 2.211 2.211 2.211 1.939 1.939 1.939

Meter Correction Factor dimensionless 0.927 0.927 0.927 0.981 0.981 0.981

Oxygen Concentration Mole Percent O2 6.0 5.5 6.0 6.0 5.0 5.0

Carbon Dioxide Concentration Mole Percent CO2 12.0 14.0 13.0 13.5 14.0 14.0

Volume of Gas Metered Actual Cubic Feet 40.695 43.485 41.385 39.660 39.531 38.816

Volume of Water Collected Milliliters 72.0 72.0 75.0 66.9 71.2 79.4

Sampling Time Minutes 60 60 60 60 60 60

Nozzle Diameter Inches 0.272 0.275 0.272 0.276 0.274 0.275

Weight of Solids Collected Milligrams 64.1 66.5 69.5 26.3 54.0 61.4

Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.596 0.618 0.600 0.569 0.577 0.582

Average Orifice Pressure (DH) Inches Water 1.64 1.83 1.67 1.44 1.40 1.37

Average Stack Temperature Degrees F 269 268 270 276 277 279

Average Meter Temperature Degrees F 70 75 78 74 79 81

Average Generation MW 271 271 271 271 271 271

 Sides A & B

Combined

 Side A Side B TOTAL or

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 37.593 39.796 37.643 38.457 37.985 37.138 38.344 37.860 76.204

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.16 30.46 30.32 30.40 30.44 30.44 30.31 30.43 30.37

Water vapor in Stack Gas Percent 8.3 7.8 8.6 7.6 8.1 9.1 8.2 8.3 8.3

Average Stack Gas Velocity Feet per second 39.6 40.8 39.8 37.8 38.4 38.9 40.1 38.4 39.2

Stack Gas Flow Rate Actual Cubic 513,473 529,400 516,172 490,226 498,041 503,837 519,682 497,368 1,017,050

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 362,351 373,744 363,523 342,248 347,264 350,402 366,539 346,638 713,177

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 332,386 344,414 332,354 316,345 319,109 318,364 336,385 317,939 654,324

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 24,896 25,797 24,893 23,694 23,901 23,845 25,195 23,814 49,009

Per Minute

Particulate Concentration Grains per Standard 0.0263 0.0257 0.0284 0.0105 0.0219 0.0255 0.0268 0.0193 0.0232

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0170 0.0167 0.0183 0.0068 0.0140 0.0161 0.0173 0.0123 0.0149

 Cubic Foot

Particulate Emission Rate Pounds per Hour 74.8 76.0 81.0 28.6 59.9 69.5 77.3 52.6 129.9

Particulate Emission Rate Pounds per Million 0.0290 0.0294 0.0314 0.0111 0.0232 0.0269 0.0299 0.0204 0.0503

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 100.9 100.8 101.0 105.3 104.6 101.8 100.9 103.9

Post Test Meter Correction Check dimensionless 0.935 0.925 0.932 0.962 0.956 0.964 0.931 0.961

Percent Difference Allowed 5% Average 0.8 -0.2 0.5 -1.9 -2.5 -1.7 0.4 -2.0

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 4

Calculations
ATTACHMENT 20 - Gaston Report 20 Test Results

Title of Run RUN 2 RUN 3 RUN 4

Date Month/Day/Year 5/1/2008 5/1/2008 5/1/2008

Sampling Time -Start Military 1002 1122 1245

Sampling Time -Stop Military 1110 1231 1354

Number of Ports dimensionless 10 10 10

Number of Points per Port dimensionless 3 3 3

Heat Input Million Btu per Hour 8,146 8,199 8,367

Stack Static Pressure Inches Water -22.00 -22.00 -22.00

Barometric Pressure Inches Mercury 30.00 30.00 30.00

Standard Orifice Pressure DH@ Inches Water 2.139 2.139 2.139

Meter Correction Factor dimensionless 0.988 0.988 0.988

Oxygen Concentration Mole Percent O2 6.0 6.0 5.5

Carbon Dioxide Concentration Mole Percent CO2 13.0 13.0 13.0

Volume of Gas Metered Actual Cubic Feet 37.142 40.035 36.155

Volume of Water Collected Milliliters 68.0 75.0 64.0

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.219 0.219 0.219

Weight of Solids Collected Milligrams 19.7 5.8 29.1

Area of Stack Square Feet 812.500 812.500 812.500

Avg. Sqr. Root Velocity Pressure Inches Water 0.9253 0.9718 0.9531

Average Orifice Pressure (DH) Inches Water 1.5 1.6 1.4

Average Stack Temperature Degrees F 302 295 300

Average Meter Temperature Degrees F 69 75 78

Average Generation MW 896 890 878

AVERAGE

RUN 2 RUN 3 RUN 4 Runs 2, 3, and 4

Volume of Gas Sampled Standard Dry 36.855 39.337 35.265 37.152

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.32 30.32 30.30 30.31

Water vapor in Stack Gas Percent 8.0 8.2 7.9 8.0

Average Stack Gas Velocity Feet per second 63.5 66.5 65.4 65.1

Stack Gas Flow Rate Actual Cubic 3,097,368 3,239,977 3,187,549 3,174,964

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 2,036,588 2,150,033 2,100,022 2,095,548

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 1,873,848 1,972,972 1,934,750 1,927,190

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 140,351 147,776 144,913 144,347

Per Minute

Particulate Concentration Grains per Standard 0.008 0.002 0.013 0.008

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.005 0.001 0.008 0.005

 Cubic Foot

Particulate Emission Rate Pounds per Hour 132.2 38.4 210.7 127.1

Particulate Emission Rate Pounds per Million 0.016 0.005 0.025 0.015

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 101.8 103.2 94.3 99.8

Post Test Meter Correction Check dimensionless 1.00 0.96 1.01 0.99

Percent Difference Allowed 5% Average 1.2 -2.9 2.0 0.1

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 5

Calculations
ATTACHMENT 21 - Gaston Report 21 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 4 RUN 1 RUN 2 RUN 4

Date Month/Day/Year 7/29/2009 7/29/2009 7/30/2009 7/29/2009 7/29/2009 7/30/2009

Sampling Time -Start Military 0716 0836 1710 0001 0836 1710

Sampling Time -Stop Military 0816 0936 1810 0816 0936 1810

Number of Ports dimensionless 6 6 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5 5 5

Heat Input Million Btu per Hour 2,533 2,480 2,557 2,533 2,480 2,557

Stack Static Pressure Inches Water -10.00 -10.00 -11.00 -10.00 -10.00 -12.00

Barometric Pressure Inches Mercury 29.88 29.80 29.82 29.80 29.80 29.82

Standard Orifice Pressure DH@ Inches Water 1.907 1.907 1.907 2.080 2.080 2.040

Meter Correction Factor dimensionless 0.98 0.98 0.98 1.051 1.051 0.975

Oxygen Concentration Mole Percent O2 7.5 5.5 10.0 8.0 8.5 10.0

Carbon Dioxide Concentration Mole Percent CO2 12.0 12.5 9.0 12.0 11.0 9.0

Volume of Gas Metered Actual Cubic Feet 41.690 40.116 40.150 37.605 37.353 39.880

Volume of Water Collected Milliliters 84.7 55.4 67.1 61.5 69.3 69.8

Sampling Time Minutes 60 60 60 60 60 60

Nozzle Diameter Inches 0.273 0.277 0.278 0.276 0.277 0.277

Weight of Solids Collected Milligrams 105.7 96.5 74.6 88.0 117.4 118.7

Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.6228 0.5955 0.5754 0.5943 0.5999 0.5798

Average Orifice Pressure (DH) Inches Water 1.7 1.5 1.5 1.7 1.7 1.7

Average Stack Temperature Degrees F 266 269 267 268 272 271

Average Meter Temperature Degrees F 77 79 80 74 76 81

Average Generation MW 270 264 263 270 264 263

Weighted

Side A Side B TOTAL or

RUN 1 RUN 2 RUN 4 RUN 1 RUN 2 RUN 4 AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 40.218 38.488 38.457 39.086 38.704 37.972 39.054 38.588 77.642

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.22 30.22 29.84 30.24 30.10 29.84 30.09 30.06 30.08

Water vapor in Stack Gas Percent 9.0 6.3 7.6 6.9 7.8 8.0 7.7 7.5 7.6

Average Stack Gas Velocity Feet per second 41.4 39.5 38.4 39.4 40.0 38.9 39.8 39.4 39.6

Stack Gas Flow Rate Actual Cubic 536,583 511,519 498,163 510,315 518,613 504,317 515,422 511,082 1,026,503

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 379,179 359,699 350,784 359,609 363,490 352,407 363,220 358,502 721,722

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 344,980 336,874 324,161 334,812 335,237 324,344 335,339 331,464 66,803

 Feet Per Minute

Particulate Concentration Grains per Standard 0.040 0.039 0.030 0.035 0.047 0.048 0.036 0.043 0.040

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.026 0.025 0.019 0.023 0.030 0.031 0.024 0.028 0.026

 Cubic Foot

Particulate Emission Rate Pounds per Hour 119.7 111.5 83.0 99.5 134.2 133.8 104.7 122.5 227.2

Particulate Emission Rate Pounds per Million 0.047 0.045 0.032 0.039 0.054 0.052 0.042 0.049 0.090

Allowable Btu (Heat Input) 0.120

Isokinetic Rate Percent 103.2 98.3 101.3 101.1 99.3 100.7 100.9 100.4

Post Test Meter Correction Check dimensionless 1.00 0.99 0.98 1.08 1.09 1.01 0.99 1.06

Percent Difference Allowed 5% Average 2.2 1.2 -0.1 3.0 3.6 3.8 1.1 3.5

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GASTON STEAM PLANT

UNIT 1

Calculations
ATTACHMENT 22 - Gaston Report 22 Test Results

Title of Run RUN 1A RUN 2A RUN 3A RUN 1B RUN 2B RUN 3B

Date Month/Day/Year 3/25/2009 3/25/2009 3/25/2009 3/25/2009 3/25/2009 3/25/2009

Sampling Time -Start Military 0756 0915 1038 0756 0915 1038

Sampling Time -Stop Military 0900 1019 1142 0900 1019 1142

Number of Ports dimensionless 8 8 8 8 8 8

Number of Points per Port dimensionless 4 4 4 4 4 4

Heat Input Million Btu per Hour 2,634 2,632 2,603 2,634 2,632 2,603

Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -18.00 -18.00 -18.00

Barometric Pressure Inches Mercury 30.03 30.03 30.03 30.03 30.03 30.03

Standard Orifice Pressure DH@ Inches Water 2.088 2.088 2.088 1.858 1.858 1.858

Meter Correction Factor dimensionless 0.999 0.999 0.999 0.978 0.978 0.978

Oxygen Concentration Mole Percent O2 7.5 6.5 6.0 6.5 7.5 6.0

Carbon Dioxide Concentration Mole Percent CO2 13.0 13.0 12.0 12.0 11.5 10.5

Volume of Gas Metered Actual Cubic Feet 36.870 36.045 36.610 39.077 37.118 38.502

Volume of Water Collected Milliliters 52.0 51.0 44.0 43.2 57.2 47.0

Sampling Time Minutes 64 64 64 64 64 64

Nozzle Diameter Inches 0.223 0.221 0.224 0.223 0.220 0.219

Weight of Solids Collected Milligrams 20.3 49.2 84.1 5.7 5.5 11.1

Area of Stack Square Feet 135.298 135.298 135.298 135.298 135.298 135.298

Avg. Sqr. Root Velocity Pressure Inches Water 0.8195 0.8129 0.8060 0.8700 0.8318 0.8600

Average Orifice Pressure (DH) Inches Water 1.3 1.2 1.3 1.3 1.2 1.2

Average Stack Temperature Degrees F 270 269 270 260 258 257

Average Meter Temperature Degrees F 70 72 73 70 70 71

Average Generation MW 257 258 257 257 258 257

Flowrate

Weighted

 Side A Side B TOTAL or

RUN 1A RUN 2A RUN 3A RUN 1B RUN 2B RUN 3B AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 36.949 36.004 36.517 38.358 36.382 37.702 36.490 37.480 73.970

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.38 30.34 30.16 30.18 30.14 29.92 30.29 30.08 30.19

Water vapor in Stack Gas Percent 6.2 6.3 5.4 5.0 6.9 5.5 5.9 5.8 5.9

Average Stack Gas Velocity Feet per second 54.5 54.1 53.7 57.5 55.2 57.1 54.1 56.6 55.4

Stack Gas Flow Rate Actual Cubic 442,561 439,112 436,028 467,171 447,958 463,205 439,234 459,445 898,678

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 307,142 305,062 302,647 328,428 315,922 327,073 304,950 323,808 628,758

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 288,060 285,993 286,403 311,894 294,154 308,945 286,819 304,997 591,816

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 21,576 21,421 21,452 23,361 22,032 23,140 21,483 22,844 44,327

Per Minute

Particulate Concentration Grains per Standard 0.008 0.021 0.035 0.002 0.002 0.005 0.022 0.003 0.012

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.006 0.014 0.023 0.002 0.002 0.003 0.014 0.002 0.008

 Cubic Foot

Particulate Emission Rate Pounds per Hour 20.9 51.6 87.1 6.1 5.9 12.0 53.2 8.0 61.2

Particulate Emission Rate Pounds per Million 0.008 0.020 0.033 0.002 0.002 0.005 0.020 0.003 0.023

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 100.0 99.9 98.5 95.8 99.0 98.6 99.4 97.8

Post Test Meter Correction Check dimensionless 1.01 1.01 1.01 1.02 1.02 1.00 1.01 1.01

Percent Difference Allowed 5% Average 0.8 0.8 1.5 4.0 4.1 2.2 1.0 3.4

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 2

Calculations
ATTACHMENT 23 - Gaston Report 23 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/2/2009 6/2/2009 6/2/2009 6/2/2009 6/2/2009 6/2/2009

Sampling Time -Start Military 0834 0958 1120 0834 0958 1120

Sampling Time -Stop Military 0938 1102 1224 0938 1102 1224

Number of Ports dimensionless 8 8 8 8 8 8

Number of Points per Port dimensionless 4 4 4 4 4 4

Heat Input Million Btu per Hour 2,902 2,846 2,956 2,902 2,846 2,956

Stack Static Pressure Inches Water -17.00 -17.00 -17.00 -17.00 -17.00 -17.00

Barometric Pressure Inches Mercury 30.05 30.05 30.05 30.05 30.05 30.05

Standard Orifice Pressure DH@ Inches Water 1.858 1.858 1.858 2.088 2.088 2.088

Meter Correction Factor dimensionless 0.978 0.978 0.978 0.999 0.999 0.999

Oxygen Concentration Mole Percent O2 8.00 7.00 7.50 8.00 8.00 8.00

Carbon Dioxide Concentration Mole Percent CO2 14.0 12.5 13.5 13.0 13.0 13.0

Volume of Gas Metered Actual Cubic Feet 44.350 42.045 40.970 37.634 37.328 39.184

Volume of Water Collected Milliliters 71.0 82.0 65.0 57 50 63

Sampling Time Minutes 64 64 64 64 64 64

Nozzle Diameter Inches 0.220 0.213 0.211 0.219 0.218 0.224

Weight of Solids Collected Milligrams 14.0 18.4 20.3 18.5 8.3 9.7

Area of Stack Square Feet 134.240 134.240 134.240 134.240 134.240 134.240

Avg. Sqr. Root Velocity Pressure Inches Water 0.9588 0.9585 0.9453 0.8716 0.8705 0.8614

Average Orifice Pressure (DH) Inches Water 1.5 1.3 1.3 1.4 1.3 1.5

Average Stack Temperature Degrees F 279 285 287 288 298 296

Average Meter Temperature Degrees F 84 88 93 89 96 106

Average Generation MW 270 270 270 270 270 270

Flowrate

Weighted

Side A Side A Side A Side B Side B Side B Side A Side B TOTAL or

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 42.449 39.932 38.536 36.427 35.696 36.843 40.306 36.322 76.628

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.56 30.28 30.46 30.40 30.40 30.40 30.43 30.40 30.42

Water vapor in Stack Gas Percent 7.3 8.8 7.4 6.9 6.2 7.4 7.8 6.8 7.3

Average Stack Gas Velocity Feet per second 64.0 64.8 63.6 58.7 58.9 58.4 64.1 58.6 61.4

Stack Gas Flow Rate Actual Cubic 515,785 521,671 512,068 472,451 474,371 470,157 516,508 472,326 988,834

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 354,764 355,877 348,506 321,073 318,108 315,881 353,049 318,354 671,403

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 328,873 324,510 322,872 299,011 298,358 292,454 325,418 296,608 622,026

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 24,633 24,306 24,183 22,396 22,347 21,905 24,374 22,216 46,590

Per Minute

Particulate Concentration Grains per Standard 0.005 0.007 0.008 0.008 0.004 0.004 0.007 0.005 0.006

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.003 0.004 0.005 0.005 0.002 0.003 0.004 0.003 0.004

 Cubic Foot

Particulate Emission Rate Pounds per Hour 14.3 19.7 22.5 20.0 9.2 10.2 18.8 13.1 32.0

Particulate Emission Rate Pounds per Million 0.005 0.007 0.008 0.007 0.003 0.003 0.006 0.005 0.011

Allowable Btu (Heat Input) 0.12

Isokinetic Rate Percent 102.5 104.3 103.1 97.7 96.8 96.5 103.3 97.0

Post Test Meter Correction Check dimensionless 0.97 0.96 0.96 1.02 1.03 1.04 0.96 1.03

Percent Difference Allowed 5% Average -0.9 -1.6 -2.0 2.4 3.1 3.7 -1.5 3.0

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 3

Calculations
ATTACHMENT 24 - Gaston Report 24 Test Results 

SIDE A SIDE A SIDE A SIDE B SIDE B SIDE B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 7/8/2009 7/8/2009 7/8/2009 7/8/2009 7/8/2009 7/8/2009

Sampling Time -Start Military 0820 0934 1048 0820 0934 1048

Sampling Time -Stop Military 0920 1034 1148 0920 1034 1148

Number of Ports dimensionless 6 6 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5 5 5

Heat Input Million Btu per Hour 2,260 2,270 2,268 2,260 2,270 2,268

Stack Static Pressure Inches Water -12.50 -12.00 -12.50 -12.50 -12.50 -12.50

Barometric Pressure Inches Mercury 29.89 29.89 29.89 29.89 29.89 29.89

Standard Orifice Pressure DH@ Inches Water 1.858 1.858 1.858 2.088 2.088 2.088

Meter Correction Factor dimensionless 0.978 0.978 0.978 0.999 0.999 0.999

Oxygen Concentration Mole Percent O2 6.0 6.5 6.0 8.0 6.0 6.0

Carbon Dioxide Concentration Mole Percent CO2 13.0 12.5 13.0 11.5 13.5 13.5

Volume of Gas Metered Actual Cubic Feet 41.853 41.791 41.720 40.015 42.690 41.250

Volume of Water Collected Milliliters 56.3 70.4 64.7 50.0 79.0 71.0

Sampling Time Minutes 60 60 60 60 60 60

Nozzle Diameter Inches 0.274 0.274 0.275 0.277 0.278 0.278

Weight of Solids Collected Milligrams 48.8 52.4 138.8 27.3 42.8 73.6

Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.6172 0.6001 0.6035 0.6223 0.6334 0.6134

Average Orifice Pressure (DH) Inches Water 1.5 1.5 1.5 1.8 2.0 1.9

Average Stack Temperature Degrees F 277 276 277 267 268 270

Average Meter Temperature Degrees F 77 81 82 72 76 79

Average Generation MW 270 270 270 270 270 270

Flowrate

Weighted

 Side A Side B TOTAL or

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 40.333 40.027 39.882 39.840 42.168 40.541 40.081 40.850 80.930

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.32 30.26 30.32 30.16 30.40 30.40 30.30 30.32 30.31

Water vapor in Stack Gas Percent 6.2 7.6 7.1 5.6 8.1 7.6 7.0 7.1 7.0

Average Stack Gas Velocity Feet per second 41.1 40.1 40.3 41.2 42.0 40.7 40.5 41.3 40.9

Stack Gas Flow Rate Actual Cubic 532,917 519,360 521,968 534,127 544,901 527,861 524,749 535,630 1,060,378

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 369,414 361,208 362,005 375,724 382,618 369,654 364,209 375,999 740,208

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 346,639 333,591 336,323 354,767 351,612 341,502 338,851 349,294 688,144

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 25,963 24,986 25,191 26,572 26,336 25,579 25,380 26,162 51,542

Per Minute

Particulate Concentration Grains per Standard 0.019 0.020 0.054 0.011 0.016 0.028 0.031 0.018 0.024

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.012 0.013 0.035 0.007 0.010 0.018 0.020 0.012 0.016

 Cubic Foot

Particulate Emission Rate Pounds per Hour 55.4 57.6 154.5 32.1 47.1 81.8 89.2 53.7 142.8

Particulate Emission Rate Pounds per Million 0.024 0.025 0.068 0.014 0.021 0.036 0.039 0.024 0.063

Allowable Btu (Heat Input) 0.120

Isokinetic Rate Percent 102.3 105.5 103.5 96.6 102.4 101.4 103.7 100.1

Post Test Meter Correction Check dimensionless 0.95 0.96 0.96 1.04 1.01 1.02 0.96 1.02

Percent Difference Allowed 5% Average -2.4 -2.2 -2.2 3.7 1.4 1.6 -2.3 2.2

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 4 OUTLET

Calculations
ATTACHMENT 25 - Gaston Report 25 Test Results 

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 4/16/2009 4/16/2009 4/16/2009

Sampling Time -Start Military 0750 0930 1050

Sampling Time -Stop Military 0910 1036 1204

Number of Ports dimensionless 10 10 10

Number of Points per Port dimensionless 3 3 3

Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780

Stack Static Pressure Inches Water -22.50 -22.50 -22.50

Barometric Pressure Inches Mercury 30.10 30.10 30.10

Standard Orifice Pressure DH@ Inches Water 1.858 1.858 1.858

Meter Correction Factor dimensionless 0.978 0.978 0.978

Oxygen Concentration Mole Percent O2 5.5 5.5 7.0

Carbon Dioxide Concentration Mole Percent CO2 14.5 14.5 14.0

Volume of Gas Metered Actual Cubic Feet 35.510 36.865 37.895

Volume of Water Collected Milliliters 54.8 56.0 57.1

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.220 0.220 0.220

Weight of Solids Collected Milligrams 29.3 32.0 48.1

Area of Stack Square Feet 812.500 812.500 812.500

Avg. Sqr. Root Velocity Pressure Inches Water 0.8693 0.8772 0.9008

Average Orifice Pressure (DH) Inches Water 1.2 1.2 1.3

Average Stack Temperature Degrees F 273 281 289

Average Meter Temperature Degrees F 52 57 61

Average Generation MW 886 886 886

RUN 1 RUN 2 RUN 3 AVERAGE

Volume of Gas Sampled Standard Dry 36.157 37.192 37.894 37.081

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.54 30.54 30.52 30.53

Water vapor in Stack Gas Percent 6.7 6.6 6.6 6.6

Average Stack Gas Velocity Feet per second 58.1 59.0 60.9 59.3

Stack Gas Flow Rate Actual Cubic 2,832,949 2,874,802 2,968,491 2,892,081

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 1,940,723 1,947,235 1,989,918 1,959,292

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 1,811,491 1,818,360 1,858,128 1,829,327

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 135,681 136,195 139,174 137,017

Per Minute

Particulate Concentration Grains per Standard 0.0125 0.0133 0.0195 0.0151

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0080 0.0084 0.0122 0.0095

 Cubic Foot

Particulate Emission Rate Pounds per Hour 193.8 206.5 311.3 237.2

Particulate Emission Rate Pounds per Million 0.024 0.025 0.041 0.030

Allowable Btu (O2 F Factor) 0.12 0.12 0.12 0.12

Heat Input (O2 F Factor) Million Btu per Hour 8,189 8,220 7,582 7,996.8

Isokinetic Rate Percent 102.4 104.9 104.6 104.0

Post Test Meter Correction Check dimensionless 0.968 0.953 0.957 0.959

Percent Difference Allowed 5% Average -1.0 -2.5 -2.1 -1.9

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 5

Calculations
ATTACHMENT 26 - Gaston Report 26 Test Results

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/1/2006 6/1/2006 6/1/2006 6/1/2006 6/1/2006 6/1/2006

Sampling Time -Start Military 0857 1043 1234 0857 1043 1234

Sampling Time -Stop Military 0957 1143 1334 0957 1143 1334

Number of Ports dimensionless 6 6 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5 5 5

Heat Input Million Btu per Hour 2,614 2,605 2,593 2,614 2,605 2,593

Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00 -12.00 -12.00

Barometric Pressure Inches Mercury 29.96 29.96 29.96 29.96 29.96 29.96

Standard Orifice Pressure DH@ Inches Water 2.008 2.008 2.008 2.378 2.378 2.378

Meter Correction Factor dimensionless 0.967 0.967 0.967 0.938 0.938 0.938

Oxygen Concentration Mole Percent O2 7 6.5 7 7.5 8 7.5

Carbon Dioxide Concentration Mole Percent CO2 11.5 12 12 11.5 11 11.5

Volume of Gas Metered Actual Cubic Feet 41.680 39.342 40.185 40.397 40.315 40.225

Volume of Water Collected Milliliters 65.00 59.00 62.00 62.00 63.00 60.00

Sampling Time Minutes 60 60 60 60 60 60

Nozzle Diameter Inches 0.275 0.275 0.275 0.275 0.275 0.275

Weight of Solids Collected Milligrams 126.0 156.3 127.7 154.8 119.6 114.1

Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.6046 0.6088 0.6121 0.5765 0.5779 0.5790

Average Orifice Pressure (DH) Inches Water 1.668 1.716 1.741 1.852 1.847 1.834

Average Stack Temperature Degrees F 257 260 263 266 269 271

Average Meter Temperature Degrees F 77 81 85 74 78 82

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 39.883 37.355 37.878 38.372 37.679 37.343 36.963 37.328

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.12 30.18 30.20 30.17 30.14 30.08 30.14 30.12

Water vapor in Stack Gas Percent 7.1 6.9 7.2 7.1 7.2 7.4 7.1 7.2

Average Stack Gas Velocity Feet per second 39.7 40.0 40.4 40.0 38.1 38.4 38.4 38.3

Stack Gas Flow Rate Actual Cubic 515,127 518,938 522,942 519,002 494,248 497,082 497,882 496,404

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 368,651 369,933 371,171 369,918 349,177 349,734 349,450 349,454

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 342,386 344,334 344,619 343,780 324,077 324,005 324,645 324,242

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0487 0.0644 0.0519 0.0550 0.0633 0.0493 0.0475 0.0534

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0323 0.0428 0.0342 0.0364 0.0415 0.0321 0.0310 0.0349

 Cubic Foot

Particulate Emission Rate Pounds per Hour 142.8 190.2 153.4 162.1 175.7 137.0 132.3 148.3

Particulate Emission Rate Pounds per Million 0.055 0.073 0.059 0.062 0.067 0.053 0.051 0.057

 Btu (Heat Input)

Isokinetic Rate Percent 101.6 94.7 95.9 97.4 101.5 100.6 99.4 100.5

Post Test Meter Correction Factor dimensionless 0.97 1.05 1.04 1.02 0.97 0.97 0.97 0.97

Percent Difference Allowed 5% 0.40 7.96 6.84 5.07 2.94 3.46 3.62 3.34

Run 1 Run 2 Run 3 Average

Combined Particulate Emission Pounds per Million 0.122 0.126 0.110 0.119

Rate Btu (Heat Input)

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT, UNIT 1

COMPLIANCE ASSURANCE MONITORING

Calculations
ATTACHMENT 27 - Gaston Report 27 Test Results

Condition I Condition I Condition II Condition II Condition II Condition II Condition II Condition II

Side A Side B Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 1 RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 2/10/2006 2/10/2006 2/10/2006 2/10/2006 2/10/2006 2/10/2006 2/10/2006 2/10/2006

Sampling Time -Start Military 0825 0825 1032 1218 1323 1032 1218 1322

Sampling Time -Stop Military 0925 0925 1042 1318 1423 1042 1318 1422

Number of Ports dimensionless 6 6 6 6 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5 5 5 5 5

Heat Input Million Btu per Hour 2,666 2,666 2,699 2,701 2,701 2,699 2,701 2,701

Stack Static Pressure Inches Water -9.00 -9.00 -9.00 -9.00 -9.00 -9.00 -9.00 -9.00

Barometric Pressure Inches Mercury 30.25 30.25 30.25 30.25 30.25 30.25 30.25 30.25

Standard Orifice Pressure DH@ Inches Water 2.03 2.35 1.004 1.004 1.004 0.988 0.988 0.988

Meter Correction Factor dimensionless 1.004 0.988 7.0 7.0 7.0 7.0 7.5 7.5

Oxygen Concentration Mole Percent O2 7.0 7.0 12.0 12.0 12.0 11.5 11.0 11.0

Carbon Dioxide Concentration Mole Percent CO2 11.0 11.5 37.150 37.800 37.700 35.117 35.790 36.795

Volume of Gas Metered Actual Cubic Feet 40.900 32.905 59.00 62.00 60.00 55.00 59.00 62.00

Volume of Water Collected Milliliters 65.00 53.00 60 60 60 60 60 60

Sampling Time Minutes 60 60 0.270 0.275 0.275 0.275 0.275 0.275

Nozzle Diameter Inches 0.285 0.275 149.6 144.8 157.6 108.7 101.9 111.9

Weight of Solids Collected Milligrams 76.0 46.7 216.000 216.000 216.000 216.000 216.000 216.000

Area of Stack Square Feet 216.000 216.000 0.5930 0.5791 0.5775 0.5646 0.5693 0.5783

Avg. Sqr. Root Velocity Pressure Inches Water 0.5771 0.5568 1.3 1.4 1.4 1.7 1.8 1.8

Average Orifice Pressure (DH) Inches Water 1.4 1.6 231 234 234 225 231 232

Average Stack Temperature Degrees F 223 225 52 57 58 46 53 56

Average Meter Temperature Degrees F 41 39

Side A Side A Side A Side B Side B Side B

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Side A Side B

RUN 1 RUN 1 39.026 39.325 39.140 36.786 36.968 37.821

Volume of Gas Sampled Standard Dry 43.945 34.960 29.39 29.36 29.38 29.32 29.22 29.20

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.26 29.31 6.6 6.9 6.7 6.6 7.0 7.2

Water vapor in Stack Gas Percent 6.5 6.7 38.0 37.2 37.0 36.0 36.5 37.2

Average Stack Gas Velocity Feet per second 36.8 35.5 491,834 481,554 479,947 466,811 473,466 481,666

Stack Gas Flow Rate Actual Cubic 476,901 460,339 371,557 362,357 361,287 355,761 357,854 363,227

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 364,587 351,017 346,873 337,324 336,972 332,370 332,849 337,207

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 340,856 327,637 25,981 25,266 25,239 24,895 24,930 25,257

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 25,530 24,540 0.0590 0.0567 0.0620 0.0455 0.0424 0.0456

Per Minute

Particulate Concentration Grains per Standard 0.0266 0.0206 0.0416 0.0397 0.0435 0.0324 0.0298 0.0319

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0190 0.0146 175.5 164.0 179.1 129.6 121.1 131.7

 Cubic Foot

Particulate Emission Rate Pounds per Hour 77.8 57.8 0.065 0.061 0.066 0.048 0.045 0.049

Particulate Emission Rate Pounds per Million 0.029 0.022 101.8 101.7 101.4 96.6 96.9 97.9

 Btu (Heat Input)

Isokinetic Rate Percent 104.7 93.1 Run 1 Run 2 Run 3 AVERAGE

0.113 0.106 0.115 0.111

Particulate Emission Rate Pounds per Million Btu

 (Heat Input) (A&B Combined) 0.0509

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT - UNIT 4

COMPLIANCE ASSURANCE MONITORING

Calculations
ATTACHMENT 28 - Gaston Report 28 Test Results 

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 5/17/2006 5/17/2006 5/17/2006

Sampling Time -Start Military 0906 1034 1200

Sampling Time -Stop Military 1007 1137 1302

Number of Ports dimensionless 10 10 10

Number of Points per Port dimensionless 3 3 3

Heat Input Million Btu per Hour 8,375 8,354 8,447

Stack Static Pressure Inches Water -21.50 -21.50 -21.50

Barometric Pressure Inches Mercury 30.00 30.00 30.00

Standard Orifice Pressure DH@ Inches Water 1.96 1.96 1.96

Meter Correction Factor dimensionless 1.011 1.011 1.011

Oxygen Concentration Mole Percent O2 4.0 4.0 4.0

Carbon Dioxide Concentration Mole Percent CO2 14.5 14.5 14.5

Volume of Gas Metered Actual Cubic Feet 43.775 45.825 46.880

Volume of Water Collected Milliliters 74.00 73.00 77.00

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.235 0.228 0.248

Weight of Solids Collected Milligrams 44.0 62.1 62.9

Area of Stack Square Feet 812.500 812.500 812.500

Avg. Sqr. Root Velocity Pressure Inches Water 0.9774 1.0023 0.9487

Average Orifice Pressure (DH) Inches Water 2.098 2.210 2.444

Average Stack Temperature Degrees F 280 282 282

Average Meter Temperature Degrees F 60 69 70

RUN 1 RUN 2 RUN 3 AVERAGE

Volume of Gas Sampled Standard Dry 45.343 46.650 47.595 46.530

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.48 30.48 30.48 30.48

Water vapor in Stack Gas Percent 7.1 6.9 7.1 7.0

Average Stack Gas Velocity Feet per second 65.6 67.4 63.8 65.6

Stack Gas Flow Rate Actual Cubic 3,199,880 3,283,622 3,110,542 3,198,015

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 2,167,750 2,219,681 2,100,698 2,162,710

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 2,013,108 2,067,403 1,952,049 2,010,853

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 150,782 154,848 146,208 150,613

Per Minute

Particulate Concentration Grains per Standard 0.0149 0.0205 0.0204 0.0186

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0094 0.0129 0.0128 0.0117

 Cubic Foot

Particulate Emission Rate Pounds per Hour 257.9 363.3 340.5 320.6

Particulate Emission Rate Pounds per Million 0.031 0.043 0.040 0.038

 Btu (Heat Input)

Isokinetic Rate Percent 101.2 107.7 98.4 102.5

Post Test Meter Correction Factor dimensionless 1.03 1.01 1.04 1.03

Percent Difference Allowed 5% 1.43 0.32 3.28 1.68

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

E.C. GASTON STEAM PLANT - UNIT 5

COMPLIANCE ASSURANCE MONITORING

Calculations
ATTACHMENT 29 - Gaston Report 31 Test Results

Title of Run Description Date Start Time End Time GROSS 

GENERATION

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 

3 GRF Off 2000 Thrott 8/13/2008 10:00 10:50 265.7 55 3.78 14.96 660

4 GRF On 2000 Thrott 8/13/2008 12:50 13:40 267.1 93 3.83 14.92 662

5 High O2 8/14/2008 11:10 12:10 265.7 36 4.41 14.35 660

6 Mid O2 8/14/2008 14:15 15:15 265.3 54 3.86 14.8 642

7 Low O2 8/14/2008 16:40 17:40 264.8 173 3.5 15.11 655

8 GRF On 2015 Thrott 8/15/2008 10:00 11:00 268.5 34 4 14.77 652

9 GRF Off 2015 Thrott 8/15/2008 12:40 13:40 266.3 37 3.92 14.86 646

10 Precip In Traverse 8/18/2008 9:45 11:45 264.3 51 4.05 14.76 653

11 Mid Load/ Temp at 608 8/18/2008 23:00 0:00 173.7 62 4.89 13.97 625

12 Min Load 8/19/2008 1:50 2:50 69.1 59 8.87 10.42 580

13 Precip Out Traverse 8/20/2008 9:46 11:46 265.4 48 4.21 14.66 655

BOILER BASELINE PERFORMANCE FOR SCR TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 1
ATTACHMENT 30 - Gaston Report 32 Test Results

Title of Run Load Description Description Date Start Time End Time GROSS 

GENERATION

Avg. Econ. 

Gas Outlet 

CO 

Avg. Econ. 

Gas Outlet 

O2 

Avg. Econ. 

Gas Outlet 

CO2

Avg. Econ. 

Gas Outlet 

Temp

Military Military MW ppm % Dry % Dry Deg F 

1 Turbine Test Data - Mid Load O2 Bias set at +0.7 7/9/2008 14:32 15:00 223 37 4.12 14.59 651

2 SCR Baseline Efficiency Test O2 Bias set at +0.4 7/10/2008 9:33 10:01 270 36 4.17 14.66 680

3 SCR Baseline Efficiency Test O2 Bias set at +0.4 7/10/2008 11:34 12:02 274 36 4.08 14.73 677

4 SCR Baseline Efficiency Test O2 Bias set at +0.4 7/10/2008 14:26 14:52 270 57 3.92 14.74 671

5 SCR Baseline 250 MW Test O2 Bias set at +0.4 7/10/2008 15:16 15:42 250 133 3.95 14.72 656

6 SCR Baseline 230 MW Test O2 Bias set at +0.4 7/10/2008 16:05 16:33 230 277 3.89 14.71 650

7 SCR Baseline 200 MW Test O2 Bias set at +0.4 7/10/2008 17:06 17:33 200 70 4.73 13.97 646

9 Full Load O2 Bias set at +0.9 7/15/2008 8:18 8:45 270 28 4.34 14.3 674

10 Full Load O2 Bias set at +0.9 7/15/2008 11:02 11:29 270 54 4.48 14.21 672

18a Full Load O2 Bias +0.1 7/24/2008 8:26 8:53 270 103 3.59 15.08 673

19 Full Load O2 Bias +0.3 7/24/2008 10:04 10:31 270 100 3.71 14.94 673

20 Full Load O2 Bias +0.3 7/24/2008 11:47 12:14 270 102 3.77 14.84 674

21 Full Load O2 Bias +0.1 7/24/2008 13:18 13:45 270 183 3.58 15.05 673

22 Low Load O2 Bias +0.8 7/29/2008 3:14 3:41 70 54 9.44 9.9 587

23 Temp vs. Load O2 Bias +0.9 7/29/2008 6:22 6:49 150 315 6.23 12.82 641

24 Temp vs. Load O2 Bias +0.2 7/29/2008 8:19 8:46 155 166 5.4 13.56 635

25 182 MW Load Test O2 Bias +0.3 7/29/2008 10:19 10:46 182 131 4.69 14.19 646

SCR BASELINE TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 2
ATTACHMENT 31 - Gaston Report 33 Test Results

Title of Run Date Start Time End Time Unit Load

Avg. Econ. 

Gas Outlet 

CO 

Avg. Econ. 

Gas Outlet 

O2 

Avg. Econ. 

Gas Outlet 

CO2

Military Military MW ppm % Dry % Dry

FGA Test02 2/2/2005 12:31 13:31 270 140 2.9 15.28

FGA Test03 2/2/2005 13:38 14:48 270 143 2.92 15.28

FGA Test05 2/3/2005 9:55 10:55 270 417 2.98 15.3

Test06 2/8/2005 8:25 175 37 4.21 14.02

Test12 2/9/2005 7:57 75 84 9.13 9.6

FLUE GAS ANALYZER VERIFICATION PERFORMANCE TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 3
ATTACHMENT 32 - Gaston Report 34 Test Results

Title of Run Description Date Start Time End Time GROSS 

GENERATION

Avg. Econ. 

Gas Outlet 

CO 

Avg. Econ. 

Gas Outlet 

O2 

Avg. Econ. 

Gas Outlet 

CO2

Avg. Econ. 

Gas Outlet 

Temp

Military Military MW ppm % Dry % Dry Deg F 

Test 1 As Found 9/11/2009 11:41 12:17 269.9 25 4.17 14.55 675.7

Test 2 Load Decreased During Test (Opacity) 9/14/2009 13:44 14:20 243.7 255 4.38 14.36 656.4

Test 3 As Found Baseline @ 240 MW 9/15/2009 11:53 12:29 240 87 4.5 14.25 650.1

Test 4 As Found Baseline @ 255 MW 9/15/2009 13:21 13:57 254.9 44 4.36 14.37 659.3

Test 5 Changed "C" Mill PA Damper Bias from -4 to 0. 9/15/2009 14:35 15:11 255 40 4.38 14.36 661.3

Test 6 As Found Baseline for the Day @ 255 MW 9/16/2009 9:04 9:39 255 144 4.18 14.6 668.4

Test 7 "C" Feeder Bias Changed from -2 to +2 9/16/2009 10:17 10:53 254.9 87 4.3 14.49 668.5

Test 8 "A" Feeder Bias Changed from +5 to +2 9/16/2009 12:45 13:21 255 154 4.31 14.47 669.3

Test 9 "D" Feeder Bias Changed from -2 to +2 9/16/2009 14:39 15:13 255.2 107 4.14 14.64 668

Test 10 Lowered O2 Bias from +.6 to +.35, (.25 % pts lower) 9/16/2009 15:51 16:27 255 112 4.12 14.57 668.5

Test 11 "As Found" Baseline for the Day @ 255 MW 9/17/2009 9:10 9:46 255 42 4.2 14.6 661.7

Test 12 "A" Burner on "C" Mill, Sleeve Closed to Lightoff 9/17/2009 11:15 11:51 255.1 79 4.11 14.68 659.9

Test 13 "C" Burner on "C" Mill, Sleeve Closed to Lightoff 9/17/2009 13:20 13:56 255.1 92 3.91 14.81 660

Test 14 Throttled Inner Spin Vanes on "B" Burner on "A" Mill from 6 1/4 to 7 1/4 9/17/2009 15:44 16:20 255 130 3.85 14.89 660

Test 15 "As Found" Baseline for the Day @ 255 MW 9/18/2009 8:45 9:21 255.1 25 4.14 14.73 650.5

Test 16 Throttled "B" Burner Inner Register on "F" Mill, from 6" to 7 1/4" 9/18/2009 9:58 10:34 255 27 4.09 14.81 651.3

Test 17 Opened "A" Burner Inner Register on "C" Mill, from 7" to 5" 9/18/2009 11:27 12:03 255 44 4.28 14.66 652.9

FLAME DOCTOR TEST RESULTS

ALABAMA POWER COMPANY

E. C. GASTON STEAM PLANT

UNIT 4