Process Information

1 Name of legal owner of facility:

Alabama Power Company

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

3 Address of _X__ legal owner or ____ 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):

Gadsden

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 - 7

5 Complete street address of facility (physical location):

1000 Goodyear Avenue

Gadsden, AL 35903

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) _X__ 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: There are 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.

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 these 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").

3,625.8 tons

Quantity/year

none

2,285.5 gallons used oil was burned; 

no used-oil contaminated waste was 

burned

Other Material

Boiler cleaning wastes that are not 

hazardous wastes 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 (switchgrass, wood chips)

Actually burn

No

Yes

Yes

Permitted to burn

Yes

Yes

Yes
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 68 64 87.55 85.07 850 840 900 903 N/A N/A bituminous 

coal, natural 

gas, used oil, 

biomass

CBI CBI none not 

available

2 bituminous CBI CBI 70 66 87.66 86.12 850 839 900 877 N/A N/A bituminous 

coal, No. 2 

fuel oil, 

natural gas, 

used oil, 

biomass

CBI CBI none not 

available

NOTES

"N/A" means not applicable.

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 Gadsden Units 1 - 2. 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 tangential-fired N/A N/A (1) two cold-side ESPs 

arranged in series (American 

Standard: 1964; Buell: 1975)

N/A

2 tangential-fired N/A N/A (1) two cold-side ESPs 

arranged in series (American 

Standard: 1964; Buell: 1975)

N/A

Note: "N/A" means not applicable.

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

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

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

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

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 E = 1.38H-0.44, where E = 

emission limit (lb/MMBtu) and 

H = heat input (MMBtu/hr), 

between 10 and 250 

MMBtu/hr.

0.12 lb/MMBtu at ≥ 250 

MMBtu/hr

(Title V permit; annual 

Reference Method 5 or 17)

N/A N/A 4.0 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

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

2 E = 1.38H-0.44, where E = 

emission limit (lb/MMBtu) and 

H = heat input (MMBtu/hr), 

between 10 and 250 

MMBtu/hr.

0.12 lb/MMBtu at ≥ 250 

MMBtu/hr

(Title V permit; annual 

Reference Method 5 or 17)

N/A N/A 4.0 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: 97.0% collection 

efficiency guarantee for 

American Standard 

(expired in 1964); 99.6% 

collection efficiency 

guarantee for Buell 

(expired in 1975)

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

2

ESP: 97.0% collection 

efficiency guarantee for 

American Standard 

(expired in 1964); 95.0% 

collection efficiency 

guarantee for Buell 

(expired in 1993)

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

Note: "N/A" means not applicable.

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

Please elaborate.

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

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

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

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

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

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

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

Boiler ID32
24 For each boiler noted in Part I, question 15, 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 testing that will be conducted and 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 and 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 the 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 probably 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 testing that will be conducted and 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 and 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 the 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 probably 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.

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

Boiler ID35
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: 

Gadsden

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

Plant Code - 7

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

500 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 3.36 16.18 12,675

502 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.47 19.00 12,319

348 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.29 11.52 13,433

366 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.69 17.79 12,463

484 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.18 13.98 13,196

856 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.46 14.91 12,593

1,295 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.56 19.29 12,110

1,007 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.62 16.85 12,598

991 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.24 18.79 12,349

1,034 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.50 14.69 13,080

979 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.28 11.16 13,566

1,058 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.36 15.19 12,780

1,076 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.63 14.49 12,924

718 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.77 12.19 13,454

1,261 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.25 25.94 11,106

1,215 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.65 18.18 12,444

1,045 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.28 18.61 12,273

1,047 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.29 18.13 12,331

1,049 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.42 14.84 12,961

839 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.58 19.87 12,197

883 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.39 16.26 12,686

901 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.35 12.74 13,304

978 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.56 15.77 12,842

980 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.75 11.72 13,590

856 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.36 15.88 12,829

898 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.68 12.41 13,354

875 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.35 11.08 13,655

849 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.09 14.95 12,499

1,027 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.00 17.05 12,762

1,026 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.57 13.39 13,232

1,017 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.44 13.96 13,150

1,060 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.61 17.77 12,413

965 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.43 17.59 12,604

1,045 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.65 13.21 13,296

947 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.53 9.77 13,799

861 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.44 10.99 13,631

981 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.43 10.73 13,660

1,103 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.53 11.06 13,606

888 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.78 11.38 13,584

917 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.66 12.31 13,421

894 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.83 14.64 13,021

905 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.79 14.56 13,052

892 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.70 15.51 12,902

857 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.27 11.75 13,568

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

Vendor Analyses
D.B. D.B. D.B.

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

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

Vendor Analyses

919 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.94 15.43 12,949

924 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.89 14.14 13,121

863 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.55 15.06 12,952

893 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.54 16.05 12,799

870 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.94 13.63 13,152

909 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.36 15.97 12,729

901 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.32 14.18 13,034

957 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.94 13.93 13,128

892 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.06 15.44 12,897

885 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.34 16.02 12,827

1,177 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.53 12.74 12,967

1,331 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.58 11.65 13,534

1,576 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.65 10.40 13,763

1,629 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.81 13.46 13,221

1,536 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.48 17.07 12,648

1,175 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.49 13.11 13,248

1,185 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.48 11.07 13,564

1,342 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.35 16.98 12,658

1,096 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.62 11.56 13,547

1,108 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.31 15.23 12,805

1,189 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.25 19.78 12,159

1,203 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.23 15.05 13,002

1,252 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.49 13.98 13,168

1,246 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.57 14.10 13,052

1,234 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.64 13.17 13,182

1,217 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.58 14.45 13,021

1,209 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.47 13.77 13,064

1,246 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.60 13.79 12,868

1,077 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.72 11.41 13,515

1,090 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.58 13.00 13,269

1,117 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.81 13.53 13,166

1,125 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.88 14.78 12,952

1,048 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.07 13.41 13,189

1,082 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.11 14.49 13,021

871 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.53 13.10 13,317

1,147 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.41 14.71 13,046

1,106 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.46 14.81 12,972

1,054 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.36 15.51 12,837

1,083 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.20 15.21 12,954

1,073 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.32 16.09 12,761

1,083 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.10 14.79 12,959

1,081 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.33 15.36 12,846

1,093 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.71 11.19 13,606

1,045 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.44 12.38 13,292

1,096 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.71 12.80 13,307

1,100 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.88 13.62 13,166
D.B. D.B. D.B.

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

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

Vendor Analyses

981 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.49 17.43 12,523

1,118 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.74 10.68 13,643

1,123 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.78 10.87 13,612

1,183 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.85 15.04 12,863

1,129 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.04 14.87 12,944

1,134 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.81 12.02 13,456

1,083 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.78 10.67 13,701

1,249 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.91 12.72 13,395

1,098 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.85 11.73 13,520

837 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.54 13.79 13,209

862 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.55 12.05 13,546

787 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.67 11.91 13,497

801 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.62 14.17 13,122

802 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.76 10.91 13,573

796 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.87 10.99 13,610

804 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.87 9.82 13,806

777 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.11 11.94 13,402

788 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.99 11.77 13,531

790 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.75 10.89 13,645

1,048 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.74 11.26 13,543

1,063 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.88 11.27 13,575

1,064 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.74 11.87 13,443

1,107 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.73 12.61 13,257

1,039 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.58 14.20 13,029

1,052 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.78 14.91 12,953

1,135 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.16 15.51 12,965

897 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.81 13.83 13,129

1,031 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.22 16.97 12,587

844 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.45 12.89 13,268

829 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.58 15.60 12,791

1,174 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.37 14.28 13,090

1,060 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.37 15.59 12,799

818 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.50 13.75 13,136

814 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.32 12.84 13,301

779 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.43 13.01 13,314

769 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.24 13.12 13,235

769 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.26 14.05 13,098

774 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.44 12.91 13,353

777 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.52 14.59 12,968

796 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.52 15.32 12,872

785 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.55 16.98 12,616

571 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.82 14.08 13,080

628 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.24 13.85 13,181

591 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.22 16.75 12,734

588 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.97 15.66 12,777

582 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.73 13.07 13,289
D.B. D.B. D.B.

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

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

Vendor Analyses

571 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.24 11.37 13,553

804 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.01 13.93 13,099

1,345 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.91 15.57 12,926

679 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.95 12.76 13,329

667 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.96 14.93 12,858

681 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.04 11.17 13,625

671 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.05 11.13 13,583

682 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.91 10.73 13,680

674 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.98 12.29 13,399

683 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.92 13.48 13,246

671 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.96 14.88 13,029

678 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.89 14.80 13,039

681 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.93 12.12 13,452

717 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.99 13.95 13,110

703 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.88 12.30 13,387

698 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.76 12.71 13,359

695 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.95 14.47 13,045

684 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.85 11.52 13,492

80 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.78 7.67 14,173

654 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.93 14.19 13,083

681 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.00 10.94 13,672

689 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.90 13.56 13,167

678 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.98 15.21 12,912

675 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.80 11.15 13,603

1,665 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.41 13.25 13,230

1,647 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.71 14.91 12,864

1,514 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.69 14.76 13,000

1,543 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.62 12.93 13,324

1,364 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.76 9.91 13,739

1,633 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.77 11.19 13,603

1,782 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.37 11.29 13,537

1,688 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.76 14.89 13,042

1,718 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.77 12.11 13,408

1,733 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.22 18.19 12,549

1,722 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.57 7.54 14,285

1,709 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.42 11.26 13,553

1,732 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.54 9.87 13,770

1,373 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.69 11.71 13,458

1,633 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.94 10.09 13,766

1,696 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.90 17.89 12,409

1,726 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.34 11.77 13,499

1,724 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.50 13.60 13,221

1,501 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.48 10.79 13,537

1,531 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.78 13.89 13,205

1,871 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.61 13.64 13,159

25 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.85 10.30 13,932
D.B. D.B. D.B.

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

Amount received, dry Fuel source

basis, short tons40

ID # of boiler(s) 

firing fuel41

Fuel shipment 

method

Vendor Analyses

690 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.67 13.97 12,910

1,434 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.67 13.97 12,910

1,472 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.75 12.57 13,226

1,417 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.74 12.00 13,301

1,396 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.73 14.13 12,964

1,410 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.75 10.67 13,574

1,427 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.68 13.00 13,174

1,438 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.05 16.77 12,452

1,411 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.89 13.17 13,102

1,403 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.24 14.12 12,878

1,205 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.13 13.48 12,983

1,390 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.26 15.25 12,641

905 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.87 11.81 13,374

850 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.05 13.50 13,104

926 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.27 12.16 13,278

894 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.06 12.16 13,254

887 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.87 12.04 13,300

889 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.00 15.23 12,735

916 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.09 13.67 12,936

892 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.05 16.60 12,521

913 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.09 15.92 12,562

756 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.01 15.70 12,681

768 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.80 11.53 13,513

752 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.86 15.91 12,711

737 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.74 13.22 13,235

574 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.85 14.08 13,036

619 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.91 11.25 13,481

632 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.06 12.16 13,261

515 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.10 13.03 13,177

618 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.58 14.71 12,905

622 1, 2 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.38 12.94 13,163

Note: The information being provided is on a shipment by shipment basis. Alabama Power cannot guarantee that what was shipped in the preceding 12 calendar months is what was burned in the preceding 12 calendar months.

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

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

amount fired.

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

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

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

42 If known.

43 If known.
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

09-102 1,071 1.71 13.10 13,316 0.351 100 60 23.0 3.3 74.5 2.4 0.50 20.9 15.2 8.3 17.0 1.8 AL Jefferson, Walker Blue Creek, America #2, Pratt, 

Jefferson Blend, America

Truck

09-622 1,120 1.72 10.52 13,615 0.273 91 67 17.5 3.5 63.1 1.9 0.91 18.9 9.5 5.7 20.5 2.3 AL Jefferson, Walker Mary Lee, Jefferson, America #2, 

America

Truck

09-107 659 2.22 13.89 13,096 0.462 96 52 27.0 5.4 68.2 2.4 0.47 21.8 13.6 11.1 14.8 2.0 AL Jefferson, Walker America # 3, Jefferson-Ream, 

America

Truck

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.

Total amount of 

fuel represented by 

Sample ID # State/Country County Coal Seam

Fuel Shipment 

Method

Nickel, 

ppm

Total Sulfur, Other Trace Metal HAP, ppm

%

Ash 

Content, %

Heating Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

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

09-102 4.21 28.79 13.10 58.11 76.95 4.68 1.50 1.71 2.06 400 29.4 0.068 0.025 44.2 15.3 29.42 10.05 0.48 0.87 0.02048 0.38 2.62 53.52 0.25 0.54 1.49

09-622 6.04 30.68 10.52 58.80 77.58 4.79 1.59 1.72 3.80 390 33.8 0.058 0.026 40.1 13.4 28.19 13.16 1.01 0.91 0.03091 1.16 2.67 49.63 0.34 0.88 1.46

09-107 4.49 28.86 13.89 57.25 73.79 4.31 1.10 2.22 4.69 740 46.6 0.072 0.019 56.1 23.3 26.70 15.41 0.64 0.86 0.01685 0.36 2.62 50.21 0.19 0.92 1.43

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 (March 3, 2005)

Report 2 Unit 2 Particulate Emissions Test (July 7, 2005)

Report 3 Unit 1 Reference Method Particulate Emissions Test (July 7, 2005)

Report 4 Unit 1 Particulate Emissions Test (August 17, 2006)

Report 5 Unit 2 Particulate Emissions Test (August 15, 2006)

Report 6 Unit 1 Particulate Emissions Test (April 19, 2007)

Report 7 Unit 2 Particulate Emissions Test (April 17, 2007)

Report 8 Unit 1 Particulate Emissions Test (September 25, 2008)

Report 9 Unit 2 Particulate Emissions Test (August 13, 2008)

Report 10 Unit 1 Particulate Emissions Test (June 9, 2009)

Report 11 Unit 1 Compliance Assurance Monitoring Test (August 18, 2006)

Report 12 Unit 2 Compliance Assurance Monitoring Test (August 18, 2006)

Report 13 Unit 1 Compliance Assurance Monitoring Test (April 20, 2007)

Report 14 Unit 2 Compliance Assurance Monitoring Test (April 18, 2007)

Report 15 Unit 1 Boiler Tuning Test (January 14-30, 2009)

Report 16 Unit 2 Boiler Baseline Performance Testing for LNB/SOFA (October 25-27, 2006)

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

air pollutants) sampled for:

Report 1 Date: 3/3/2005 Type: duct Constituents: PM

Report 2 Date: 7/7/2005 Type: duct Constituents: PM

Report 3 Date: 7/7/2005 Type: duct Constituents: PM

Report 4 Date: 8/17/2006 Type: duct Constituents: PM

Report 5 Date: 8/15/2006 Type: duct Constituents: PM

Report 6 Date: 4/19/2007 Type: duct Constituents: PM

Report 7 Date: 4/17/2007 Type: duct Constituents: PM

Report 8 Date: 9/25/2008 Type: duct Constituents: PM

Report 9 Date: 8/13/2008 Type: duct Constituents: PM

Report 10 Date: 6/9/2009 Type: duct Constituents: PM

Report 11 Date: 8/18/2006 Type: duct Constituents: PM

Report 12 Date: 8/18/2006 Type: duct Constituents: PM

Report 13 Date: 4/20/2007 Type: duct Constituents: PM

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

Report 15 Date: 1/14 - 1/30/2009 Type: duct Constituents: CO, NOx, CO2

Report 16 Date: 10/25 - 10/27/2006 Type: duct Constituents: CO, NOx, CO2

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 15 and 16 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 not which reports and identify the other material(s) or non-fossil fuels used.
8e Do any of these test reports reflect testing during periods of startup, shutdown, and malfunction?

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

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

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

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 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 probable cause of said deviations, and any

corrective actions or preventative 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:

Units 1-2: October 21, 2008 - December 31, 2009

COMS data are available for the following periods of time:

Unit 1: 1993 - 2008

Unit 2: 1993 - 2008

Units 1-2: January 1, 2009 - 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 3/3/2005 See Attachment 1 N/A N/A N/A N/A N/A N/A

2 Report 2 7/7/2005 See Attachment 2 N/A N/A N/A N/A N/A N/A

1 Report 3 7/7/2005 See Attachment 3 N/A N/A N/A N/A N/A N/A

1 Report 4 8/17/2006 See Attachment 4 N/A N/A N/A N/A N/A N/A

2 Report 5 8/15/2006 See Attachment 5 N/A N/A N/A N/A N/A N/A

1 Report 6 4/19/2007 See Attachment 6 N/A N/A N/A N/A N/A N/A

2 Report 7 4/17/2007 See Attachment 7 N/A N/A N/A N/A N/A N/A

1 Report 8 9/25/2008 See Attachment 8 N/A N/A N/A N/A N/A N/A

2 Report 9 8/13/2008 See Attachment 9 N/A N/A N/A N/A N/A N/A

1 Report 10 6/9/2009 See Attachment 10 N/A N/A N/A N/A N/A N/A

1 Report 11 8/18/2006 See Attachment 11 N/A N/A N/A N/A N/A N/A

2 Report 12 8/18/2006 See Attachment 12 N/A N/A N/A N/A N/A N/A

1 Report 13 4/20/2007 See Attachment 13 N/A N/A N/A N/A N/A N/A

2 Report 14 4/18/2007 See Attachment 14 N/A N/A N/A N/A N/A N/A

1 Report 15 1/14 - 1/30/2009 N/A N/A N/A N/A N/A See Attachment 15 N/A

2 Report 16 10/25 - 10/27/2006 N/A N/A N/A N/A N/A See Attachment 16 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 - Gadsden Report 1 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 3/3/2005 3/3/2005 3/3/2005

Sampling Time -Start Military 0806 0922 1032

Sampling Time -Stop Military 0908 1022 1132

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 861 860 861

Stack Static Pressure Inches Water -1.10 -1.10 -1.10

Barometric Pressure Inches Mercury 30.10 30.10 30.10

Meter Correction Factor dimensionless 1.0110 1.0110 1.0110

Oxygen Concentration Mole Percent O2 7.0 8.0 7.5

Carbon Dioxide Concentration Mole Percent CO2 13.0 12.5 12.0

Volume of Gas Metered Actual Cubic Feet 40.555 41.150 39.580

Volume of Water Collected Milliliters 46 59 63

Sampling Time Minutes 60.00 60.00 60.00

Nozzle Diameter Inches 0.260 0.260 0.260

Weight of Solids Collected Milligrams 54.0 24.4 41.5

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.8002 0.8147 0.7891

Average Orifice Pressure (DH) Inches Water 1.511 1.6 1.5

Average Stack Temperature Degrees F 389.43 390.1 390.4

Average Meter Temperature Degrees F 46.90 48.8 56.1

Average Generation #/hr 587,000 586,000 583,000

3 Runs

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 43.134 43.611 41.343 42.696

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.77 29.58 29.40 29.58

Water vapor in Stack Gas Percent 4.8 6.0 6.7 5.8

Average Stack Gas Velocity Feet per second 56.0 57.2 55.6 56.3

Stack Gas Flow Rate Actual Cubic 370,545 378,590 367,864 372,333

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 231,036 235,867 229,094 231,999

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 219,993 221,746 213,762 218,500

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0193 0.0086 0.0155 0.0145

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0114 0.0050 0.0090 0.0085

 Cubic Foot

Particulate Emission Rate Pounds per Hour 36.4 16.4 28.3 27.0

Particulate Emission Rate Pounds per Million 0.042 0.019 0.033 0.031

Allowable Particulate Emission Rate Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 97.7 98.0 96.4 97.4

TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT - UNIT 1

3/3/2005

Calculations
ATTACHMENT 2 - Gadsden Report 2 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 7/7/2005 7/7/2005 7/7/2005

Sampling Time -Start Military 1335 1458 1615

Sampling Time -Stop Military 1442 1604 1720

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 760 778 773

Stack Static Pressure Inches Water -0.25 -0.25 -0.25

Barometric Pressure Inches Mercury 29.90 29.90 29.90

Meter Correction Factor dimensionless 1.032 1.032 1.032

Oxygen Concentration Mole Percent O2 8.0 8.0 7.5

Carbon Dioxide Concentration Mole Percent CO2 11.0 11.0 11.0

Volume of Gas Metered Actual Cubic Feet 43.259 39.953 39.197

Volume of Water Collected Milliliters 74.00 79.00 80.00

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.250 0.240 0.240

Weight of Solids Collected Milligrams 51.6 29.4 46.3

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.8453 0.8434 0.8382

Average Orifice Pressure (DH) Inches Water 1.9 1.6 1.6

Average Stack Temperature Degrees F 383 384 384

Average Meter Temperature Degrees F 87 88 88

Average Generation #/hr 560,000 577,000 583,000

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 43.292 39.860 39.079 40.744

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.18 29.05 29.00 29.08

Water vapor in Stack Gas Percent 7.4 8.5 8.8 8.3

Average Stack Gas Velocity Feet per second 59.7 59.7 59.4 59.6

Stack Gas Flow Rate Actual Cubic 394,693 394,940 392,845 394,159

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 246,874 246,755 245,446 246,358

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 228,490 225,700 223,874 226,021

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 17,114 16,905 16,768 16,929

Per Minute

Particulate Concentration Grains per Standard 0.0184 0.0114 0.0182 0.0160

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0106 0.0065 0.0104 0.0092

 Cubic Foot

Particulate Emission Rate Pounds per Hour 35.9 22.0 35.0 31.0

Particulate Emission Rate Pounds per Million 0.047 0.028 0.045 0.040

 Btu (Heat Input)

Allowable Particulate Emission Rate Pounds per Million 0.12 0.12 0.12 0.12

 Btu (Heat Input)

Isokinetic Rate Percent 102.1 103.3 102.1 102.5

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 2

Calculations
ATTACHMENT 3 - Gadsden Report 3 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 7/7/2005 7/7/2005 7/7/2005

Sampling Time -Start Military 0833 1013 1140

Sampling Time -Stop Military 0942 1121 1246

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 391 379 385

Stack Static Pressure Inches Water -0.70 -0.70 -0.70

Barometric Pressure Inches Mercury 29.90 29.90 29.90

Meter Correction Factor dimensionless 1.032 1.032 1.032

Oxygen Concentration Mole Percent O2 7.5 7.5 8.0

Carbon Dioxide Concentration Mole Percent CO2 11.0 11.5 11.0

Volume of Gas Metered Actual Cubic Feet 31.045 31.842 33.161

Volume of Water Collected Milliliters 52.00 56.00 60.00

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.250 0.250 0.262

Weight of Solids Collected Milligrams 37.4 41.2 46.3

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.5697 0.5766 0.5684

Average Orifice Pressure (DH) Inches Water 0.9 0.9 1.1

Average Stack Temperature Degrees F 350 351 352

Average Meter Temperature Degrees F 74 81 91

Average Generation #/hr 258,000 242,000 253,000

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 31.729 32.116 32.894 32.246

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.20 29.22 29.12 29.18

Water vapor in Stack Gas Percent 7.2 7.6 7.9 7.6

Average Stack Gas Velocity Feet per second 39.4 39.9 39.4 39.6

Stack Gas Flow Rate Actual Cubic 260,789 264,054 260,953 261,932

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 169,644 171,471 169,193 170,102

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 157,494 158,465 155,815 157,258

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 11,796 11,869 11,671 11,779

Per Minute

Particulate Concentration Grains per Standard 0.0182 0.0198 0.0217 0.0199

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0110 0.0119 0.0129 0.0119

 Cubic Foot

Particulate Emission Rate Pounds per Hour 24.5 26.8 29.0 26.8

Particulate Emission Rate Pounds per Million 0.063 0.071 0.075 0.070

Million Btu

Isokinetic Rate Percent 108.6 109.2 103.6 107.1

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 1

Calculations
ATTACHMENT 4 - Gadsden Report 4 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 8/17/2006 8/17/2006 8/17/2006

Sampling Time -Start Military 0922 1036 1156

Sampling Time -Stop Military 1022 1136 1256

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 810 811 804

Stack Static Pressure Inches Water -0.70 -0.70 -0.70

Barometric Pressure Inches Mercury 30.00 30.00 30.00

Standard Orifice Pressure DH@ Inches Water 2.020 2.020 2.020

Meter Correction Factor dimensionless 0.974 0.974 0.974

Oxygen Concentration Mole Percent O2 9.0 9.0 9.0

Carbon Dioxide Concentration Mole Percent CO2 9.0 9.0 12.0

Volume of Gas Metered Actual Cubic Feet 40.705 41.215 42.015

Volume of Water Collected Milliliters 68 74 70

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.250 0.250 0.250

Weight of Solids Collected Milligrams 27.6 22.9 23.4

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7833 0.7896 0.7927

Average Orifice Pressure (DH) Inches Water 1.7 1.7 1.7

Average Stack Temperature Degrees F 383 384 385

Average Meter Temperature Degrees F 80 82 87

Average Generation #/hr 583,000 582,000 583,000

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 39.036 39.378 39.776 39.397

 Cubic Feet 

Molecular Wt. of Stack Gas (wet) LB/LB-MOLE 28.91 28.84 29.34 29.03

Water vapor in Stack Gas Percent 7.6 8.1 7.6 7.8

Average Stack Gas Velocity Feet per second 55.5 56.0 55.8 55.8

Stack Gas Flow Rate Actual Cubic 367,094 370,662 369,121 368,959

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 230,098 232,114 230,930 231,047

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 212,661 213,251 213,264 213,059

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 15,928 15,973 15,973 15,958

Per Minute

Particulate Concentration Grains per Standard 0.0109 0.0090 0.0091 0.0096

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0063 0.0052 0.0052 0.0056

 Cubic Foot

Particulate Emission Rate Pounds per Hour 19.8 16.4 16.6 17.6

Particulate Emission Rate Pounds per Million 0.025 0.020 0.021 0.022

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 98.9 99.5 100.5 99.7

Post Test Meter Correction Factor dimensionless 1.02 1.02 1.00

Percent Difference Allowed 5% 4.73 4.74 2.80 4.1

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 1

Calculations
ATTACHMENT 5 - Gadsden Report 5 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 8/15/2006 8/15/2006 8/15/2006

Sampling Time -Start Military 0847 1003 1126

Sampling Time -Stop Military 0947 1103 1226

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 815 811 803

Stack Static Pressure Inches Water -0.70 -0.70 -0.70

Barometric Pressure Inches Mercury 30.15 30.15 30.15

Standard Orifice Pressure DH@ Inches Water 2.020 2.020 2.020

Meter Correction Factor dimensionless 0.974 0.974 0.974

Oxygen Concentration Mole Percent O2 6.0 8.0 8.0

Carbon Dioxide Concentration Mole Percent CO2 10.0 11.0 11.0

Volume of Gas Metered Actual Cubic Feet 41.320 41.730 39.930

Volume of Water Collected Milliliters 68 72 79

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.250 0.250 0.250

Weight of Solids Collected Milligrams 32.7 32.6 29.1

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.8163 0.8022 0.7895

Average Orifice Pressure (DH) Inches Water 1.9 1.8 1.7

Average Stack Temperature Degrees F 380 381 381

Average Meter Temperature Degrees F 83 91 98

Average Generation #/hr 600,000 600,000 586,000

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 39.633 39.406 37.280 38.773

 Cubic Feet 

Molecular Wt. of Stack Gas (wet) LB/LB-MOLE 28.96 29.12 28.98 29.02

Water vapor in Stack Gas Percent 7.5 7.9 9.1 8.2

Average Stack Gas Velocity Feet per second 57.6 56.4 55.7 56.5

Stack Gas Flow Rate Actual Cubic 380,747 373,289 368,186 374,074

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 240,565 235,573 232,472 236,203

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 222,589 216,917 211,387 216,964

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 16,672 16,247 15,833 16,251

Per Minute

Particulate Concentration Grains per Standard 0.0127 0.0127 0.0120 0.0125

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0074 0.0074 0.0069 0.0072

 Cubic Foot

Particulate Emission Rate Pounds per Hour 24.2 23.7 21.8 23.2

Particulate Emission Rate Pounds per Million 0.030 0.029 0.027 0.029

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 96.0 97.9 95.0 96.3

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT, UNIT 2

Calculations
ATTACHMENT 6 - Gadsden Report 6 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 4/19/2007 4/19/2007 4/19/2007

Sampling Time -Start Military 0758 1024 1203

Sampling Time -Stop Military 1004 1141 1316

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 830 821 810

Stack Static Pressure Inches Water -0.40 -0.40 -0.40

Barometric Pressure Inches Mercury 30.03 30.03 30.03

Standard Orifice Pressure DH@ Inches Water 2.258 2.258 2.258

Meter Correction Factor dimensionless 0.982 0.982 0.982

Oxygen Concentration Mole Percent O2 5 6.5 6

Carbon Dioxide Concentration Mole Percent CO2 12 12 12

Volume of Gas Metered Actual Cubic Feet 40.454 42.158 42.226

Volume of Water Collected Milliliters 62 57 58

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.248 0.250 0.250

Weight of Solids Collected Milligrams 37.6 57.0 47.3

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.8031 0.8089 0.7896

Average Orifice Pressure (DH) Inches Water 1.9 2.0 1.9

Average Stack Temperature Degrees F 366 372 366

Average Meter Temperature Degrees F 71 79 76

Average Generation MW 604,000 602,000 602,000

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 39.851 40.921 41.195 40.656

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.12 30.18 30.16 30.153

Water vapor in Stack Gas Percent 6.8 6.2 6.2 6.397

Average Stack Gas Velocity Feet per second 55.9 56.4 54.9 55.713

Stack Gas Flow Rate Actual Cubic 369,764 372,886 362,966 368,539

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 236,984 237,299 232,505 235,596

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 220,813 222,698 218,054 220,522

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 16,539 16,680 16,332 16,517

Per Minute

Particulate Concentration Grains per Standard 0.015 0.021 0.018 0.018

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.009 0.013 0.011 0.011

 Cubic Foot

Particulate Emission Rate Pounds per Hour 27.5 40.9 33.0 33.8

Particulate Emission Rate Pounds per Million 0.033 0.050 0.041 0.041

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 98.8 99.0 101.8 99.9

Post Test Meter Correction Factor dimensionless 1.01 1.00 0.97 0.99

Percent Difference Allowed 5% 2.8 1.5 -1.3 1.0

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 1

Calculations
ATTACHMENT 7 - Gadsden Report 7 Test Results 

Title of Run RUN 1 RUN 2 RUN 3 RUN 4

Date Month/Day/Year 4/17/2007 4/17/2007 4/17/2007 4/17/2007

Sampling Time -Start Military 0840 1019 1221 1404

Sampling Time -Stop Military 0952 1140 1330 1518

Number of Ports dimensionless 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5

Heat Input Million Btu per Hour 773 774 763 748

Stack Static Pressure Inches Water -0.70 -0.70 -0.70 -0.70

Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10

Standard Orifice Pressure DH@ Inches Water 2.258 2.258 2.258 2.258

Meter Correction Factor dimensionless 0.982 0.982 0.982 0.982

Oxygen Concentration Mole Percent O2 7.5 7.5 6.5 7.0

Carbon Dioxide Concentration Mole Percent CO2 12.5 11.5 11.5 11.0

Volume of Gas Metered Actual Cubic Feet 38.755 39.449 40.602 41.501

Volume of Water Collected Milliliters 50 64 55 62

Sampling Time Minutes 60 60 60 60

Nozzle Diameter Inches 0.255 0.250 0.250 0.250

Weight of Solids Collected Milligrams 43.1 142.9 40.6 48.4

Area of Stack Square Feet 110.250 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7527 0.7801 0.7906 0.7840

Average Orifice Pressure (DH) Inches Water 1.8 1.9 1.9 1.9

Average Stack Temperature Degrees F 375 381 378 381

Average Meter Temperature Degrees F 67 78 84 84

Average Generation #/hr 586,000 587,000 589,000 588,000

RUN 1 RUN 2 RUN 3 RUN 4

Average 

(Runs 1, 3, 

and 4)

Volume of Gas Sampled Standard Dry 38.519 38.450 39.105 39.980 39.201

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.30 30.14 30.10 30.04 30.15

Water vapor in Stack Gas Percent 5.8 7.3 6.2 6.8 6.3

Average Stack Gas Velocity Feet per second 52.4 54.8 55.3 55.1 54.3

Stack Gas Flow Rate Actual Cubic 346,421 362,302 366,046 364,347 358,938

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 219,954 228,468 231,554 229,748 227,085

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 207,288 211,868 217,176 214,118 212,861

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 15,526 15,869 16,266 16,037 15,943

Per Minute

Particulate Concentration Grains per Standard 0.017 0.057 0.016 0.019 0.017

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.010 0.033 0.009 0.011 0.010

 Cubic Foot

Particulate Emission Rate Pounds per Hour 30.6 103.9 29.8 34.2 31.5

Particulate Emission Rate Pounds per Million 0.040 0.134 0.039 0.046 0.041

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 96.3 97.8 97.0 100.6 98.0

Post Test Meter Correction Factor dimensionless 1.01 1.02 1.02 0.99 1.01

Percent Difference Allowed 5% 2.7 4.3 3.8 0.7 2.4

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 2

Calculations
ATTACHMENT 8 - Gadsden Report 8 Test Results 

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 9/25/2008 9/25/2008 9/25/2008

Sampling Time -Start Military 0900 1022 1138

Sampling Time -Stop Military 1000 1124 1242

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 863 850 828

Stack Static Pressure Inches Water -0.40 -0.40 -0.40

Barometric Pressure Inches Mercury 29.60 29.60 29.60

Standard Orifice Pressure DH@ Inches Water 2.211 2.211 2.211

Meter Correction Factor dimensionless 0.927 0.927 0.927

Oxygen Concentration Mole Percent O2 7.0 7.0 7.0

Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 12.0

Volume of Gas Metered Actual Cubic Feet 43.330 44.100 47.135

Volume of Water Collected Milliliters 53 51 70

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.248 0.250 0.252

Weight of Solids Collected Milligrams 35.4 26.6 29.4

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7974 0.7908 0.7879

Average Orifice Pressure (DH) Inches Water 1.8 1.8 1.9

Average Stack Temperature Degrees F 378 375 371

Average Meter Temperature Degrees F 74 84 86

Average Generation #/hr 587,000 587,000 597,000

RUN 1 RUN 2 RUN 3 AVERAGE

Volume of Gas Sampled Standard Dry 39.444 39.410 41.979 40.277

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.20 30.20 30.20 30.20

Water vapor in Stack Gas Percent 5.9 5.7 7.3 6.3

Average Stack Gas Velocity Feet per second 56.1 55.6 55.4 55.7

Stack Gas Flow Rate Actual Cubic 371,429 367,522 366,400 368,450

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 231,121 229,566 230,032 230,240

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 217,372 216,385 213,291 215,683

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 16,281 16,207 15,975 16,155

Per Minute

Particulate Concentration Grains per Standard 0.0138 0.0104 0.0108 0.0117

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0081 0.0061 0.0063 0.0068

 Cubic Foot

Particulate Emission Rate Pounds per Hour 25.8 19.3 19.7 21.6

Particulate Emission Rate Pounds per Million 0.030 0.023 0.024 0.025

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 99.4 98.2 104.4 100.6

Post Test Meter Correction Check dimensionless 0.935 0.930 0.883 0.916

Percent Difference Allowed 5% Average 0.8 0.3 -4.4 -1.1

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 1

Calculations
ATTACHMENT 9 - Gadsden Report 9 Test Results 

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 8/13/2008 8/13/2008 8/13/2008

Sampling Time -Start Military 0833 1001 1258

Sampling Time -Stop Military 0937 1113 1405

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 770 773 786

Stack Static Pressure Inches Water -0.40 -0.40 -0.40

Barometric Pressure Inches Mercury 29.85 29.85 29.85

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 7.5 6.0 6.0

Carbon Dioxide Concentration Mole Percent CO2 11.5 11.0 10.0

Volume of Gas Metered Actual Cubic Feet 41.755 40.959 41.714

Volume of Water Collected Milliliters 67 62 68

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.260 0.253 0.253

Weight of Solids Collected Milligrams 26.0 29.2 32.6

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7327 0.7527 0.7575

Average Orifice Pressure (DH) Inches Water 1.6 1.5 1.6

Average Stack Temperature Degrees F 381 384 386

Average Meter Temperature Degrees F 76 83 84

Average Generation #/hr 589,000 589,000 595,000

RUN 1 RUN 2 RUN 3 AVERAGE

Volume of Gas Sampled Standard Dry 40.286 39.015 39.647 39.650

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.14 30.00 29.84 29.99

Water vapor in Stack Gas Percent 7.3 7.0 7.5 7.2

Average Stack Gas Velocity Feet per second 51.6 53.2 53.8 52.9

Stack Gas Flow Rate Actual Cubic 341,561 352,181 356,193 349,978

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 213,788 219,512 221,427 218,242

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 198,267 204,235 204,886 202,463

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 14,850 15,297 15,346 15,164

Per Minute

Particulate Concentration Grains per Standard 0.0099 0.0115 0.0127 0.0114

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0058 0.0067 0.0073 0.0066

 Cubic Foot

Particulate Emission Rate Pounds per Hour 16.9 20.2 22.2 19.8

Particulate Emission Rate Pounds per Million 0.0219 0.0261 0.0283 0.0254

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 101.2 100.5 101.8 101.2

Post Test Meter Correction Check dimensionless 0.985 0.979 0.990 0.985

Percent Difference Allowed 5% Average 0.7 0.1 1.2 0.7

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 2

Calculations
ATTACHMENT 10 - Gadsden Report 10 Test Results 

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/9/2009 6/9/2009 6/9/2009

Sampling Time -Start Military 0830 1000 1122

Sampling Time -Stop Military 0940 1108 1228

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 729 729 730

Stack Static Pressure Inches Water -1.05 -1.05 -1.05

Barometric Pressure Inches Mercury 29.95 29.95 29.95

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 6.00 5.00 6.00

Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 13.0

Volume of Gas Metered Actual Cubic Feet 42.479 44.873 42.238

Volume of Water Collected Milliliters 54.1 71.7 66.8

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.251 0.254 0.248

Weight of Solids Collected Milligrams 31.1 29.3 33.1

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7788 0.7961 0.7740

Average Orifice Pressure (DH) Inches Water 1.6 1.8 1.6

Average Stack Temperature Degrees F 354 355 355

Average Meter Temperature Degrees F 82 97 102

Average Generation #/hr 588,000 588,000 587,000

RUN 1 RUN 2 RUN 3 AVERAGE

Volume of Gas Sampled Standard Dry 40.679 41.846 39.027 40.517

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.16 30.12 30.32 30.20

Water vapor in Stack Gas Percent 5.9 7.5 7.5 6.9

Average Stack Gas Velocity Feet per second 53.8 55.2 53.5 54.2

Stack Gas Flow Rate Actual Cubic 355,769 365,368 354,189 358,442

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 230,439 236,269 228,956 231,888

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 216,864 218,636 211,885 215,795

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 16,243 16,376 15,870 16,163

Per Minute

Particulate Concentration Grains per Standard 0.012 0.011 0.013 0.012

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.007 0.006 0.008 0.007

 Cubic Foot

Particulate Emission Rate Pounds per Hour 21.9 20.2 23.7 21.9

Particulate Emission Rate Pounds per Million 0.030 0.028 0.032 0.030

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 100.3 99.9 100.9 100.4

Post Test Meter Correction Check dimensionless 0.97 0.99 0.98 0.98

Percent Difference Allowed 5% Average -0.7 1.1 0.2 0.2

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 1

Calculations
ATTACHMENT 11 - Gadsden Report 11 Test Results 

Title of Run RUN 1 RUN 2

Date Month/Day/Year 8/18/2006 8/18/2006

Sampling Time -Start Military 0935 1243

Sampling Time -Stop Military 1035 0143

Number of Ports dimensionless 6 6

Number of Points per Port dimensionless 5 5

Heat Input Million Btu per Hour 817 817

Stack Static Pressure Inches Water -0.70 -0.70

Barometric Pressure Inches Mercury 30.00 30.00

Standard Orifice Pressure DH@ Inches Water 2.020 2.020

Meter Correction Factor dimensionless 0.947 0.947

Oxygen Concentration Mole Percent O2 7.0 7.0

Carbon Dioxide Concentration Mole Percent CO2 10.0 10.0

Volume of Gas Metered Actual Cubic Feet 39.435 44.365

Volume of Water Collected Milliliters 70 60

Sampling Time Minutes 60 60

Nozzle Diameter Inches 0.250 0.250

Weight of Solids Collected Milligrams 368.5 178.2

Area of Stack Square Feet 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7832 0.8612

Average Orifice Pressure (DH) Inches Water 1.7 2.0

Average Stack Temperature Degrees F 375 384

Average Meter Temperature Degrees F 95 94

RUN 1 RUN 2

Volume of Gas Sampled Standard Dry 35.810 40.334

 Cubic Feet 

Molecular Wt. of Stack Gas (wet) LB/LB-MOLE 28.88 29.10

Water vapor in Stack Gas Percent 8.4 6.5

Average Stack Gas Velocity Feet per second 55.2 60.8

Stack Gas Flow Rate Actual Cubic 365,479 402,433

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 231,263 252,040

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 211,777 235,547

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 15,862 17,642

Per Minute

Particulate Concentration Grains per Standard 0.1585 0.0680

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0918 0.0398

 Cubic Foot

Particulate Emission Rate Pounds per Hour 287.7 137.4

Particulate Emission Rate Pounds per Million 0.352 0.168

 Btu (Heat Input)

Isokinetic Rate Percent 91.1 92.3

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT, UNIT 1 CAM

Calculations
ATTACHMENT 12 - Gadsden Report 12 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 8/16/2006 8/16/2006 8/16/2006

Sampling Time -Start Military 1027 1224 0222

Sampling Time -Stop Military 1127 0124 0322

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 816 804 787

Stack Static Pressure Inches Water -0.70 -0.70 -0.70

Barometric Pressure Inches Mercury 30.00 30.00 30.00

Standard Orifice Pressure DH@ Inches Water 2.020 2.020 2.020

Meter Correction Factor dimensionless 0.947 0.947 0.947

Oxygen Concentration Mole Percent O2 7.0 7.0 7.0

Carbon Dioxide Concentration Mole Percent CO2 10.0 10.0 8.0

Volume of Gas Metered Actual Cubic Feet 39.355 41.465 42.350

Volume of Water Collected Milliliters 70 73 66

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.250 0.250 0.250

Weight of Solids Collected Milligrams 111.2 136.3 143.2

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7610 0.7989 0.8201

Average Orifice Pressure (DH) Inches Water 1.6 1.8 1.9

Average Stack Temperature Degrees F 377 383 389

Average Meter Temperature Degrees F 87 95 99

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 36.235 37.650 38.186 37.357

 Cubic Feet 

Molecular Wt. of Stack Gas (wet) LB/LB-MOLE 28.89 28.89 28.69 28.82

Water vapor in Stack Gas Percent 8.3 8.4 7.5 8.1

Average Stack Gas Velocity Feet per second 53.7 56.6 58.5 56.3

Stack Gas Flow Rate Actual Cubic 355,407 374,566 387,152 372,375

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 224,469 234,726 240,983 233,393

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 205,759 215,095 222,853 214,569

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 15,411 16,111 16,692 16,071

Per Minute

Particulate Concentration Grains per Standard 0.0473 0.0558 0.0578 0.0536

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0274 0.0320 0.0332 0.0309

 Cubic Foot

Particulate Emission Rate Pounds per Hour 83.4 102.8 110.3 98.8

Particulate Emission Rate Pounds per Million 0.102 0.128 0.140 0.123

 Btu (Heat Input)

Isokinetic Rate Percent 94.9 94.3 92.3 93.9

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT, UNIT 2 CAM

Calculations
ATTACHMENT 13 - Gadsden Report 13 Test Results

Title of Run RUN 1 RUN 2 RUN 3 RUN 4

Date Month/Day/Year 4/20/2007 4/20/2007 4/20/2007 4/20/2007

Sampling Time -Start Military 0849 1104 1308 1505

Sampling Time -Stop Military 1000 1216 1419 1616

Number of Ports dimensionless 6 6 6 6

Number of Points per Port dimensionless 5 5 5 5

Heat Input Million Btu per Hour 843 830 824 816

Stack Static Pressure Inches Water -0.70 -0.70 -0.70 -0.70

Barometric Pressure Inches Mercury 30.18 30.18 30.18 30.18

Standard Orifice Pressure DH@ Inches Water 2.258 2.258 2.258 2.258

Meter Correction Factor dimensionless 0.982 0.982 0.982 0.982

Oxygen Concentration Mole Percent O2 6.5 6.5 5.5 5.0

Carbon Dioxide Concentration Mole Percent CO2 11.5 10.5 10.5 11.0

Volume of Gas Metered Actual Cubic Feet 38.328 38.536 41.020 37.595

Volume of Water Collected Milliliters 49 53 58 55

Sampling Time Minutes 60 60 60 60

Nozzle Diameter Inches 0.249 0.250 0.256 0.246

Weight of Solids Collected Milligrams 206.7 148.8 110.1 96.0

Area of Stack Square Feet 110.250 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7765 0.7743 0.7647 0.7610

Average Orifice Pressure (DH) Inches Water 1.8 1.8 2.0 1.7

Average Stack Temperature Degrees F 362 367 364 365

Average Meter Temperature Degrees F 59 69 73 76

RUN 1 RUN 2 RUN 3 RUN 4 Average

Volume of Gas Sampled Standard Dry 38.774 38.310 40.473 36.876 38.608

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.10 29.94 29.90 29.980 29.980

Water vapor in Stack Gas Percent 5.6 6.1 6.3 6.6 6.2

Average Stack Gas Velocity Feet per second 53.7 53.9 53.2 52.9 53.4

Stack Gas Flow Rate Actual Cubic 355,068 356,387 351,861 350,146 353,366

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 229,686 229,181 226,920 225,595 227,846

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 216,790 215,169 212,581 210,797 213,834

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 16,238 16,116 15,922 15,789 16,016

Per Minute

Particulate Concentration Grains per Standard 0.082 0.060 0.042 0.040 0.056

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.050 0.036 0.025 0.024 0.034

 Cubic Foot

Particulate Emission Rate Pounds per Hour 152.5 110.3 76.3 72.4 102.9

Particulate Emission Rate Pounds per Million 0.181 0.133 0.093 0.089 0.124

 Btu (Heat Input)

Isokinetic Rate Percent 97.2 96.0 97.9 97.4 97.1

Post Test Meter Correction Factor dimensionless 1.01 1.03 1.01 1.03 1.02

Percent Difference Allowed 5% 2.3 5.0 3.2 4.3 3.7

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT - UNIT 1

COMPLIANCE ASSURANCE MONITORING

Calculations
ATTACHMENT 14 - Gadsden Report 14 Test Results 

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 4/18/2007 4/18/2007 4/18/2007

Sampling Time -Start Military 0938 1244 1456

Sampling Time -Stop Military 1050 1357 1609

Number of Ports dimensionless 6 6 6

Number of Points per Port dimensionless 5 5 5

Heat Input Million Btu per Hour 761 756 745

Stack Static Pressure Inches Water -0.65 -0.40 -0.40

Barometric Pressure Inches Mercury 29.77 29.77 29.77

Standard Orifice Pressure DH@ Inches Water 2.258 2.258 2.258

Meter Correction Factor dimensionless 0.982 0.982 0.982

Oxygen Concentration Mole Percent O2 6 6 5

Carbon Dioxide Concentration Mole Percent CO2 12 12 12

Volume of Gas Metered Actual Cubic Feet 39.847 39.871 43.504

Volume of Water Collected Milliliters 67 58 63

Sampling Time Minutes 60 60 60

Nozzle Diameter Inches 0.253 0.250 0.260

Weight of Solids Collected Milligrams 157.5 131.5 96.6

Area of Stack Square Feet 110.250 110.250 110.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7512 0.7623 0.7618

Average Orifice Pressure (DH) Inches Water 1.8 1.8 2.1

Average Stack Temperature Degrees F 367 370 371

Average Meter Temperature Degrees F 62 73 80

RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 39.570 38.795 41.784 40.050

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.16 30.16 30.12 30.15

Water vapor in Stack Gas Percent 7.4 6.6 6.6 6.9

Average Stack Gas Velocity Feet per second 52.6 53.3 53.4 53.1

Stack Gas Flow Rate Actual Cubic 347,930 352,889 353,258 351,359

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 220,600 223,208 223,002 222,270

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 204,316 208,533 208,224 207,025

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 15,303 15,619 15,596 15,506

Per Minute

Particulate Concentration Grains per Standard 0.061 0.052 0.036 0.050

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.036 0.031 0.021 0.029

 Cubic Foot

Particulate Emission Rate Pounds per Hour 107.3 93.3 63.5 88.1

Particulate Emission Rate Pounds per Million 0.141 0.123 0.085 0.117

 Btu (Heat Input)

Isokinetic Rate Percent 101.9 100.3 100.0 100.7

Post Test Meter Correction Factor dimensionless 0.98 0.99 1.00 0.99

Percent Difference Allowed 5% -0.1 0.9 1.4 0.7

TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT - UNIT 2

COMPLIANCE ASSURANCE MONITORING

Calculations
ATTACHMENT 15 - Gadsden Report 15 Test Results

Title of Run Date Start Time End Time Test Load

Avg. Econ. 

Gas Outlet 

CO 

Avg. Econ. 

Gas Outlet 

O2 

Avg. Econ. 

Gas Outlet 

CO2

Avg. Econ. 

Gas Outlet 

Temp

Military Military MW ppm % Dry % Dry Deg F 

Test 1 1/14/2009 11:10 12:10 66 133 2.96 15.80 688

Test 2 1/14/2009 14:42 15:19 66 112 2.81 15.84 662

Test 3 1/15/2009 8:00 8:36 66 81 3.09 15.81 694

Test 4 1/15/2009 10:21 10:57 66 140 3.22 15.73 679

Test 5 1/15/2009 12:27 13:03 66 336 3.55 15.41 688

Test 6 1/15/2009 14:50 13:26 66 94 3.69 15.33 673

Test 7 1/16/2009 8:08 8:44 67 48 3.62 15.3 693

Test 8 1/16/2009 10:08 10:44 67 56 3.42 15.54 714

Test 9 1/19/2009 9:43 10:19 33 15 5.38 13.59 622

Test 10 1/19/2009 11:11 11:47 33 13 4.84 14.12 618

Test 11 1/19/2009 12:54 13:30 33 15 4.67 14.27 627

Test 12 1/19/2009 14:25 15:01 33 12 4.16 14.74 621

Test 13 1/20/2009 9:47 10:23 66 190 3.53 15.47 735

Test 14 1/20/2009 2:02 2:36 66 101 3.74 15.28 729

Test 15 1/21/2009 8:55 9:30 66 67 3.27 15.68 711

Test 16 1/21/2009 13:57 14:33 68 78 3.26 15.56 705

Test 17 1/21/2009 17:02 17:38 68 34 4.11 14.83 702

Test 18 1/22/2009 9:04 9:40 49 19 4.78 14.31 633

Test 19 1/22/2009 10:39 11:15 49 21 4.7 14.35 634

Test 20 1/22/2009 13:16 13:52 49 16 4.7 14.26 634

Test 21 1/22/2009 15:02 15:38 49 20 4.4 14.48 658

Test 22 1/23/2009 9:21 9:57 35 11 4.94 14.16 580

Test 24 1/26/2009 15:47 16:23 36 12 4.67 14.26 612

Test 25 1/27/2009 9:58 10:34 36 12 4.93 14.08 625

Test 26 1/27/2009 13:31 14:07 36 13 4.76 14.09 629

Test 27 1/28/2009 9:08 9:44 32 11 4.85 14.1 595

Test 28 1/29/2009 11:14 11:50 66 50 3.83 15.02 751

Test 29 1/29/2009 17:45 18:31 34 10 5 14.01 577

Test 30 1/30/2009 10:02 10:38 34 14 4.93 14.2 622

Test 31 1/30/2009 11:10 11:46 55 26 4.28 14.73 699

Test 32 1/30/2009 13:10 13:46 67 35 3.8 15.14 738

BOILER TUNING TEST RESULTS

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 1
ATTACHMENT 16 - Gadsden Report 16 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 

2 As Found, 30 MW, 5.0% O2 SP, Tilts +10 deg. 10/25/2006 13:49 14:25 30 87 6.01 13 559.5

3 60 MW, Burner Tilts +3, 3.8% O2 SP 10/26/2006 8:49 9:31 60 63 4.96 14.14 664.1

4 60 MW, Tilts +18, 3.8% O2 SP 10/26/2006 11:04 11:51 60.5 162 4.8 14.08 675.6

5 60 MW, Tilts -14, 3.8% O2 10/26/2006 13:32 14:19 59.9 115 4.88 14.04 668.4

6 32 MW, Top Mill (#4) Off, Aux & Fuel closed, 5% O2 10/27/2006 8:45 9:31 32 32 6.25 12.98 574.1

7 30 MW, Top Mill (#4) Off, Fuel & 2 Aux Airs Open, 5% O2 10/27/2006 11:04 11:40 30.3 72 6.35 12.74 569.8

SG02 33 MW, #5 Mill out, 5.0% O2 SP, Tilts +11 10/31/2006 11:34 11:52 32 18 7.11 11.95 605.4

SG03 33 MW, #5 Mill out, 3.5% O2 SP, Tilts +11 10/31/2006 13:07 13:25 33 189 5.48 13.12 575.3

SG04 33 MW, #5 Mill out, 4.0% O2 SP, Tilts +11 10/31/2006 14:14 14:32 32 91 5.78 12.69 582.9

SG07 33 MW, #5 Mill out, 5.0% O2 SP, Tilts +7 11/6/2006 11:50 12:08 33 30 6.86 12.29 597.8

SG08 33 MW, #5 Mill out, 4.0% O2 SP, Tilts +7 11/6/2006 13:11 13:29 33 95 5.74 13.24 584.5

SG13 33 MW, #5 Mill out, 4.0%, Tilts +7 11/6/2006 16:49 17:07 34 112 5.34 12.99 585.4

SG17 33 MW, #5 Mill out, 5.0% O2 SP, Tilts +9 11/7/2006 12:34 12:52 32 40 6.26 12.18 585.4

SG27 33 MW, #5 Mill out, 5.0% O2 SP, Tilts +4 11/8/2006 16:25 16:43 32.5 31 6.93 12.55 603.8

SG31 33 MW, #5 Mill out, 5.0% O2 SP, Tilts +10 11/9/2006 11:15 11:33 330 60 6.64 12.77 588.6

SG32 33 MW, #5 Mill out, 5.0% O2 SP, Tilts +10 11/9/2006 12:58 13:16 32.4 58 6.84 12.55 583.8

SG42 60 MW, 3.5% O2 SP, Tilts +5 11/13/2006 8:49 9:07 59.6 54 4.6 14.89 667.1

SG44 60 MW, 5.5% O2 SP, Tilts +5 deg. 11/13/2006 13:38 13:56 61.3 28 6.85 12.7 692.2

SG47 60 MW, 4.5% O2 SP, Tilts +5 deg. 11/13/2006 16:29 16:47 62.4 30 5.7 13.66 681.5

SG48 63 MW, 3.5% O2 SP, Tilts +6 deg. 11/14/2006 8:07 8:25 60.6 132 4.79 14.31 657.1

SG50 63 MW, 3.5% O2 SP, Tilts +6 deg. 11/14/2006 10:15 10:33 61 152 4.77 14.3 658.7

SG58 63 MW, 3.5% O2 SP, Tilts +3 deg. 11/15/2006 11:26 11:44 62 129 4.7 14.25 660

SG62 63 MW, 3.5% O2 SP, Tilts +11 deg. 11/16/2006 8:04 8:22 61.2 152 4.78 14.25 665.5

SG65 63 MW, 4.5% O2 SP, Tilts +11 11/16/2006 10:58 11:17 61.2 125 5.89 13.31 685.9

SG66 63 MW, 3.5% O2 SP, Tilts +11 11/16/2006 12:38 12:56 61 172 4.85 14.15 665.7

SG70 63 MW, 4.5% O2 SP, Tilts +11 11/16/2006 16:33 16:51 62.1 145 6.1 13.05 686.3

SG71 61 MW, 4.0% O2 SP, Tilts +9 11/17/2006 8:24 8:42 60 118 5.29 13.82 668

BOILER BASELINE PERFORMANCE TESTING FOR LNB/SOFA

ALABAMA POWER COMPANY

GADSDEN STEAM PLANT

UNIT 2