Process Information

1Name of legal owner of facility:

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

3Address of _X__ legal owner or ____ operator:

600 North 18th Street Birmingham, AL 35291-0830 4aPlant Name (as reported on U.S. DOE/EIA Form-860 (2007), "Annual Electric Generator Report", schedule 2, line 1, page 37, question 1) OR Plant Name (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report", schedule 2, page 1, question 1):

Gadsden 4bEIA Plant Code (as reported on U.S. DOE/EIA Form-860 (2007), schedule 2, line 1, page 37, question 2) OR Plant ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), schedule 2, page 1, question 2):

Plant Code - 7 5Complete street address of facility (physical location):

1000 Goodyear Avenue Gadsden, AL 35903 6Provide mailing address if different:

600 North 18th Street Birmingham, AL 35291-0830 7Name and title of contact(s) able to answer technical questions about the completed survey:

Sarah Markham, Engineer II 8Contact(s) telephone number(s):

(205) 257-6780 and e-mail address(es):

sasander@southernco.com 9Is this facility considered to be owned or operated by a small entity as defined by the Regulatory Flexibility Act? ____ Yes

_X__ No____ Don't know

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

_X__ coal

_X__ oil (including pet coke)

_X__ natural gas

_X__ other (specify in question 14 below)

11Which of the following fossil fuel or other material(s) are permitted1to 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.

12If coal or solid fuel, as described below, derived from a fossil source is fired, indicate which rank of coal or solid fuel was utilized during the previous 12 months prior to the receipt of this ICR:2,3 ____ lignite (% _____) ____ subbituminous (% _____)

_X__ bituminous (% _100_) ____ anthracite (% _____) ____ coal refuse (including gob, culm, and subbituminous-derived coal refuse) (% _____) ____ synfuel (including, but not limited to, briquettes, pellets, or extrusions which are formed by binding materials, or processes that recycle materials) (%_____) (please specify the type or form of synfuel used ___________________________________________) ____ petroleum coke (% _____)

1"Permitted" in this context, refers to the fuels that the permit anticipates will be combusted at the facility.
2If the boiler is fired by a blend of coal ranks, please specify percentage (separately, on both a mass and on a Btu basis) of each coal rank (e.g., 85% subbituminuous/15% bituminous).
3In reference to footnote 1, if necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting the reason the fuel type was combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research purposes").13If oil is fired, indicate which type of oil was utilized during the previous 12 months prior to the receipt of this ICR:4

_X__ distillate (% _100__)

_ _ __ other (specify __________) (% _____) ____ residual or bunker C (% _____)

14aIf "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited to, plastics, treated wood, rubber belting or gaskets, whole tires, tire-derived fuel, boiler cleaning solutions, animal wastes, etc.) is either utilized or permitted to be used, please indicate below what materials are combusted in the boiler and in what quantities (specify whether this quantity is on a weight percentage or heat [Btu] basis). Also indicate (yes/no) whether you are permitted5to burn non-fossil fuel(s) or other material(s) even if you do not actually burn them.

14bIf "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited to, plastics, treated wood, rubber belting or gaskets, whole tires, tire-derived fuel, boiler cleaning solutions, animal wastes, etc.) is either utilized or permitted to be used, were such material to be classified as "solid waste" under the Resource Conservation and Recovery Act and, thus make the utilizing unit subject to CAA section 129, would you continue to utilize (i.e., use as a fuel) the material?____ Yes____ No

_X__ Neither Explain:Until the regulations are finalized, we cannot determine with certainty whether we would use these other materials.

4If the boiler is fired by a blend of fuel oil ranks, please specify percentage (separately, on both a volume and on a Btu basis) of each fuel oil rank (e.g., 85% residual oil/15% distillate).
5If necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting the reason the fuel was combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research purposes"). 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 forenergy 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

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

located at this facility.Boiler ID6Original design fuel (i.e.,coal rank or type of oil)Design heat input,(MMBtu/hr)7Present maximum heatinput, (MMBtu/hr)8MWe Gross capacitysummerMWe Net CapacitysummerOriginal design grossefficiency (%, HHV)Present operating grossefficiency (%, HHV)Design steam pressure(psig)Operating steam pressure(psig)Design steam temperature(oF)Operating steamtemperature (oF)Design steam reheattemperature (oF)9Operating steam reheattemperature (oF)10Fuel11Hours/year operated12Average annual capacityfactor for the past 3 yearsApplicable NSPSEstimated year ofretirement13

1 bituminous 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.

6Boiler 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).
7Per fuel burned in the boiler. Report this based on higher heating value (HHV).
8Per fuel burned in the boiler. Report this based on higher heating value (HHV).
9Please indicate if more than one steam reheat cycle is utilized, and, if so, please provide information for both.
10Please indicate if more than one steam reheat cycle is utilized, and, if so, please provide information for both.
11Indicate the fuels utilized for the indicated boiler, and percentages, as indicated in questions 11 - 13.
12The "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.
13This can be treated as CBI and can be submitted through the proper CBI procedure if desired.

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

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

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]).

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

HAP-specific (e.g., mercury, hydrogen chloride) control technology that you have either contracted for, are installing, or have installed for the purpose of participating in a control technology demonstration project20

### (e.g., U.S. Department of Energy program, consent decree, etc.).

Name Telephone Address 1 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

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

is currently operating), the date of expected or projected start-up, the date the demonstration was completed, the type of HAP control installed (e.g., sorbent and type; pre-combustion boiler chemical additive; combustion boiler chemical additive), the desired HAP emission reduction or rate (if any), and the coal rank(s) upon which the demonstration was conducted. Please specify the format of the target HAP emission reduction rate (e.g., lb/MWh, lb/TBtu, percent reduction, etc.). If the format of the target end-point is percent reduction, provide (1) an estimate of what an equivalent emission rate would be (and specify the format of the equivalent emission rate), and (2) the basis for calculating the percent reduction (i.e., where the "inlet" and "outlet" are).

Boiler ID22 

### Demonstration

activity actual startup date Demonstration

activity projected start-up date Demonstration

activity end-date or projected end-dateType of control (e.g.,

sorbent and type; chemical additive23

### )Desired HAP emission reduction (%) or emission rate Coal rank(s) in use

1 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.

### 19For 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

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

date of expected or projected start-up, the type of HAP control installed (e.g., sorbent and type; pre-construction boiler chemical additive; combustion of boiler chemical additive), the guaranteed HAP emission reduction or emission rate, the sorbent feed rate upon which the guarantee is based, and the coal rank(s) upon which the guarantee is based. Please specify the format of the guarantee (e.g., lb/MWh, lb/TBtu, percent reduction, etc.). If the format of the guarantee is percent reduction, provide (1) an estimate of what an equivalent emission rate would be (and specify the format of the equivalent emission rate), and (2) the basis for calculating the percent reduction (i.e., where the "inlet" and "outlet" are).

Boiler ID25

### Actual start-up dateExpected or projected start-up date Type of control (e.g.,

sorbent and type; chemical additive)26 

### Guaranteed HAP

emission reduction (%) or emission rateSorbent 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.

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

PM28 

### PM10(29)

### PM2.5(30) 

### SO2 HCl and/or HF HCN Metal

HAP31 

### Hg CO Other organics (specify) Other

pollutant (specify) 1 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

### 22For 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.



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

_X__ No Please elaborate.

32

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

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

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

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

### 24For 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

### 25For 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]

26Are any other means of emission control (for any pollutant) employed on any boiler noted in Part I, question 15 (e.g., low-ash coal, coal or oil with low trace constituents, etc.)? Please specify. No.

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



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

Gadsden 1bPlant 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.

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

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

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 

### Fuel source Amount received, dry 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 

### Fuel source Amount received, dry 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 

### Fuel source Amount received, dry 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 

### Fuel source Amount received, dry 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 

### Fuel source Amount received, dry 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.3For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information44, as

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

AntimonyArsenicBerylliumCadmiumChromium Cobalt Lead ManganeseSelenium 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 1.8AL Jefferson, WalkerBlue 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 2.3AL Jefferson, WalkerMary 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 2.0AL Jefferson, WalkerAmerica # 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.

44To 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.
45Metal 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 Other Trace Metal HAP, ppm Total Sulfur, % Ash Content, %Heating Value,

Btu/lb Mercury,

ppm Chlorine,

ppm Fluorine,

ppm4Were the data provided in Part II, question 3 above, acquired pursuant to:

____ permit requirements ____ contractual obligations ____ standard operational procedures

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

5Analyses 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 6Name and address of laboratory performing analyses: Alabama Power Company, General Services Laboratory 744 Highway 87, GSC #8 Calera, AL 35040 7In addition to the analyses required in Part II, question 3 above, for samples for which analyses of chlorine and/or any of the HAP metals were conducted, please provide copies of any analyses conducted over the preceding 12 calendar months for (a) complete proximate and ultimate analyses, (b) additional trace metals, and (c) the mineralogy of the ash that are readily available for the oil(s) or coal(s) listed in Part II, question 2 above. The Agency is requesting these data only as they may already be available; no additional sampling or analyses are required to provide these data.

Total

MoistureVolatiles Ash Fixed CarbonCarbonHydrogenNitrogen Total Sulfur OxygenBariumCopperMagnesiumSodiumVanadium 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 0.870.02048 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 0.910.03091 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 0.860.01685 0.36 2.62 50.21 0.19 0.92 1.43 Sample ID # Proximate Analyses, % by wt Ultimate Analyses, % by wt Ash Mineralogy, % by wt Other Trace Metals, ppm

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

question 15, for tests conducted since January 1, 2005. Please consider reports prepared for all testing and monitoring programs, for all pollutants, including (but not limited to) those required under Title V, compliance with State or local requirements, fulfillment of contractual obligations, U.S. Department of Energy (DOE) programs, etc. (NOTE: EPA is not requesting copies of the test reports or data at this time; however we may request actual copies in the future.) Use additional pages as necessary.

Report 1Unit 1 Particulate Emissions Test (March 3, 2005) Report 2Unit 2 Particulate Emissions Test (July 7, 2005) Report 3Unit 1 Reference Method Particulate Emissions Test (July 7, 2005) Report 4Unit 1 Particulate Emissions Test (August 17, 2006) Report 5Unit 2 Particulate Emissions Test (August 15, 2006) Report 6Unit 1 Particulate Emissions Test (April 19, 2007) Report 7Unit 2 Particulate Emissions Test (April 17, 2007) Report 8Unit 1 Particulate Emissions Test (September 25, 2008) Report 9Unit 2 Particulate Emissions Test (August 13, 2008) Report 10Unit 1 Particulate Emissions Test (June 9, 2009) Report 11Unit 1 Compliance Assurance Monitoring Test (August 18, 2006) Report 12Unit 2 Compliance Assurance Monitoring Test (August 18, 2006) Report 13Unit 1 Compliance Assurance Monitoring Test (April 20, 2007) Report 14Unit 2 Compliance Assurance Monitoring Test (April 18, 2007) Report 15Unit 1 Boiler Tuning Test (January 14-30, 2009) Report 16Unit 2 Boiler Baseline Performance Testing for LNB/SOFA (October 25-27, 2006)

8bPlease indicate the date(s) and types (e.g., stack, fuel, parametric, etc.) of the test(s) and the constituents (including criteria and hazardous air pollutants) sampled for: Report 1 Date: 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

8cDo 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.

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

___If yes, please not which reports and identify the other material(s) or non-fossil fuels used.

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

Yes ____No _X

___If yes, please note which reports.

8fDid the unit's control configuration differ from that shown in Part I, question 16, at the time of these test results? Yes ____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.
8gDo any of these test reports reflect testing at a location before a post combustion SO2 emission control device (e.g., FGD, SDA, Dry Scrubber)? Yes ____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.

### 9What 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. 10Are deviation reports available for malfunctions or other periods of noncompliance with permit terms and conditions? Yes _X

__No ____If yes, please note which reports.

Deviation 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. 11Are continuous emissions monitoring system (CEMS) data available (e.g., mercury, continuous opacity monitoring systems) that are not already being provided to the U.S. EPA, even if from short-term testing? Yes _X

__No ____If yes46

### , please note for which pollutants CEMS data are available and the period of time (both total period and calendar period) for which the data are available. If CEM data are being provided to EPA, please note to which Office the data are being provided.

Mercury CEMS data are 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.

### 12For 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 3/3/2005See Attachment 1 N/A N/A N/A N/A N/A N/A 2 Report 2 7/7/2005See Attachment 2 N/A N/A N/A N/A N/A N/A 1 Report 3 7/7/2005See Attachment 3 N/A N/A N/A N/A N/A N/A 1 Report 4 8/17/2006See Attachment 4 N/A N/A N/A N/A N/A N/A 2 Report 5 8/15/2006See Attachment 5 N/A N/A N/A N/A N/A N/A 1 Report 6 4/19/2007See Attachment 6 N/A N/A N/A N/A N/A N/A 2 Report 7 4/17/2007See Attachment 7 N/A N/A N/A N/A N/A N/A 1 Report 8 9/25/2008See Attachment 8 N/A N/A N/A N/A N/A N/A 2 Report 9 8/13/2008See Attachment 9 N/A N/A N/A N/A N/A N/A 1 Report 10 6/9/2009See Attachment 10 N/A N/A N/A N/A N/A N/A 1 Report 11 8/18/2006See Attachment 11 N/A N/A N/A N/A N/A N/A 2 Report 12 8/18/2006See Attachment 12 N/A N/A N/A N/A N/A N/A 1 Report 13 4/20/2007See Attachment 13 N/A N/A N/A N/A N/A N/A 2 Report 14 4/18/2007See 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 (o

### F), Flue gas pressure at sampling point (atm), Standard temperature (o

### F), 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 3Average Volume of Gas Sampled Standard Dry 43.134 43.611 41.34342.696 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 370,545 378,590 367,864372,333 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 231,036 235,867 229,094231,999 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 219,993 221,746 213,762218,500 Feet Per Minute Particulate Concentration Grains per Standard 0.0193 0.0086 0.01550.0145 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0114 0.0050 0.00900.0085 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 3Average Volume of Gas Sampled Standard Dry 43.292 39.860 39.07940.744 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 394,693 394,940 392,845394,159 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 246,874 246,755 245,446246,358 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 228,490 225,700 223,874226,021 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 17,114 16,905 16,76816,929 Per Minute Particulate Concentration Grains per Standard 0.0184 0.0114 0.01820.0160 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0106 0.0065 0.01040.0092 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 RatePounds 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 PressureInches 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 3Average
Volume of Gas Sampled Standard Dry 31.729 32.116 32.89432.246 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 260,789 264,054 260,953261,932 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 169,644 171,471 169,193170,102 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 157,494 158,465 155,815157,258 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 11,796 11,869 11,67111,779 Per Minute Particulate Concentration Grains per Standard 0.0182 0.0198 0.02170.0199 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0110 0.0119 0.01290.0119 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 PressureDH@ 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 3Average
Volume of Gas Sampled Standard Dry 39.036 39.378 39.77639.397 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 367,094 370,662 369,121368,959 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 230,098 232,114 230,930231,047 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 212,661 213,251 213,264213,059 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 15,928 15,973 15,97315,958 Per Minute Particulate Concentration Grains per Standard 0.0109 0.0090 0.00910.0096 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0063 0.0052 0.00520.0056 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 PressureDH@ 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 3Average
Volume of Gas Sampled Standard Dry 39.633 39.406 37.28038.773 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 380,747 373,289 368,186374,074 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 240,565 235,573 232,472236,203 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 222,589 216,917 211,387216,964 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 16,672 16,247 15,83316,251 Per Minute Particulate Concentration Grains per Standard 0.0127 0.0127 0.01200.0125 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0074 0.0074 0.00690.0072 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 4/19/20074/19/20074/19/2007 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 PressureDH@ 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 3Average
Volume of Gas Sampled Standard Dry 39.851 40.921 41.19540.656 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.12 30.18 30.1630.153
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 54.955.713

Stack Gas Flow Rate Actual Cubic 369,764 372,886 362,966368,539 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 236,984 237,299 232,505235,596 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 220,813 222,698 218,054220,522 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 16,539 16,680 16,33216,517 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 4/17/20074/17/20074/17/20074/17/2007 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 PressureDH@ 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 4Average (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 Factordimensionless 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 3AVERAGE
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 371,429 367,522 366,400368,450 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 231,121 229,566 230,032230,240 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 217,372 216,385 213,291215,683 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 Checkdimensionless 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 3AVERAGE
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 341,561 352,181 356,193349,978 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 213,788 219,512 221,427218,242 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 198,267 204,235 204,886202,463 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 Checkdimensionless 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 6/9/20096/9/20096/9/2009 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 110.250110.250110.250 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 588,000588,000587,000

RUN 1 RUN 2 RUN 3AVERAGE
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 355,769365,368354,189358,442 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 230,439236,269228,956231,888 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 216,864218,636211,885215,795 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 Checkdimensionless 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 8/18/20068/18/2006 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 PressureDH@ 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 8/16/20068/16/20068/16/2006 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 PressureDH@ 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 3Average
Volume of Gas Sampled Standard Dry 36.235 37.650 38.18637.357 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 355,407 374,566 387,152372,375 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 224,469 234,726 240,983233,393 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 205,759 215,095 222,853214,569 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 15,411 16,111 16,69216,071 Per Minute Particulate Concentration Grains per Standard 0.0473 0.0558 0.05780.0536 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0274 0.0320 0.03320.0309 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 4/20/20074/20/20074/20/20074/20/2007 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 PressureDH@ 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 4Average
Volume of Gas Sampled Standard Dry 38.774 38.310 40.473 36.87638.608 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.10 29.94 29.90 29.98029.980
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 355,068 356,387 351,861 350,146353,366 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 229,686 229,181 226,920 225,595227,846 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 216,790 215,169 212,581 210,797213,834 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 16,238 16,116 15,922 15,78916,016 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 4/18/20074/18/20074/18/2007 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 PressureDH@ 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 3Average
Volume of Gas Sampled Standard Dry 39.570 38.795 41.78440.050 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 347,930 352,889 353,258351,359 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 220,600 223,208 223,002222,270 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 204,316 208,533 208,224207,025 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 15,303 15,619 15,59615,506 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 TimeEnd TimeTest LoadAvg. 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 TimeEnd Time Gross GenerationAvg. 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 SG0233 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 SG0333 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 SG0433 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 SG0733 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 SG0833 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 SG1333 MW, #5 Mill out, 4.0%, Tilts +7 11/6/2006 16:49 17:07 34 112 5.34 12.99 585.4 SG1733 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 SG2733 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 SG3133 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 SG3233 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