### Process Information

1Name of legal owner of facility:

Alabama Power Company owns Unit 5. Southern Electric Generating Company owns Units 1-4. 2Name of legal operator of facility, if different from legal owner:

Alabama Power Company 3Address of ____ legal owner or _X__ 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):

E C Gaston 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 - 26 5Complete street address of facility (physical location):

31972 Highway 25 N Wilsonville, AL 35186 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) ____ natural gas

_X__ other (specify in question 14 below)

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

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

_X__ coal

_X__ oil (including pet coke)

_X__ natural gas

_X__ other (specify in question 14 below) Note: These are the anticipated fuels; however, the permit and design are not necessarily restricted to these fuels.

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.
2

### If the boiler is fired by a blend of coal ranks, please specify percentage (separately, on both a mass and on a Btu basis) of each coal rank (e.g., 85% subbituminuous/15% bituminous).
3

### In reference to footnote 1, if necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting the reason the fuel type was combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research purposes").

### 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 permitted5

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

1

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



### 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 the other materials.

4

### If the boiler is fired by a blend of fuel oil ranks, please specify percentage (separately, on both a volume and on a Btu basis) of each fuel oil rank (e.g., 85% residual oil/15% distillate).
5

### If necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting the reason the fuel was combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research purposes"). 457.5 tons 

### Quantity/year 110,000 gallons

9,000 gallons used oil-contaminated waste was burned; no used oil was

burned 

### Other Material Boiler cleaning wastes that are not hazardous as defined in 40 CFR Part 261, Subpart B and ADEM Admin. Code R. 335-14-2 may be combusted in these units for energy recovery.

Used oil that is not hazardous waste as defined in 40 CFR Part 279 and ADEM Admin. Code R. 335-14-17, and which is generated at Alabama Power facilities in the state of Alabama may be combusted 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 (wood chips) 

### Actually burn Yes

Yes

Yes 

### Permitted to burn Yes

Yes

No115Identification (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 270 254 89.66 87.9 2000 1954 1000 1000 1000 947 bituminous coal, No. 2 fuel oil, used oil-contaminated waste CBI CBI none not available

2 bituminous CBI CBI 270 256 89.66 88.63 2000 2001 1000 1000 1000 995 bituminous coal, No. 2 fuel oil, used oil-contaminated waste, boiler cleaning waste CBI CBI none not available

3 bituminous CBI CBI 270 254 89.66 N/A 2000 2003 1000 998 1000 992 bituminous coal, No. 2 fuel oil,biomass, used oilcontaminated waste, boiler cleaning waste CBI CBI none not available

4 bituminous CBI CBI 270 256 89.66 88.87 2000 1990 1000 1000 1000 986 bituminous coal, No. 2 fuel oil, used oil-contaminated waste CBI CBI none not available

5 bituminous CBI CBI 884 842 88.7 N/A 3500 3500 1000 1000 1000 986 bituminous coal, No. 2 fuel oil, used oil-contaminated waste CBI CBI none not available

NOTES "N/A" means not available. Original design fuel.Based on the original contract boiler data sheet; only the primary fuel is listed if multiple fuels were included on the data sheet. See also text to previous response (Part I, No. 11), which indicates that the design fuel simply means the fuel for which the boiler is optimized to operate at maximum possible efficiency, but that the boiler was designed to handle and burn a range of fuels. MWe Gross Capacity Summer.Identifies the gross normal full load as of May 2009. Alabama Power does not change unit capacities from season to season. MWe Net Capacity Summer.Identifies the net normal full load as of May 2009; taken directly from the 2009 installed and authorized document. Alabama Power does not change unit capacities from season to season. Original design gross efficiency (%, HHV).Taken directly from the original contract boiler data sheet. Present operating gross efficiency (%, HHV).Based on the most recent actual test of the boiler efficiency, unless no recent boiler efficiency test was available. Where no recent test was available, that status is indicated. Design steam pressure (psig).Based on the thermal design of the unit as represented on the turbine heat balance sheet. Operating steam pressure (psig).Represents the average throttle pressure when the unit operated at gross normal full load over a three year period (January 2007 to December 2009). Design steam temperature.Based on the thermal design of the unit as represented on the turbine heat balance sheet. Operating steam temperature.Represents the average steam temperature when the unit operated at gross normal full load over a three year period (January 2007 to December 2009). Design steam reheat temperature.Based on the thermal design of the unit as represented on the turbine heat balance sheet. Operating steam reheat temperature.Represents the average reheat steam temperature when the unit operated at gross normal full load over a three year period (January 2007 to December 2009). Fuel.Indicates the fuels burned in the previous calendar year (January to December 2009). NSPS.Where no NSPS is identified, the unit is not currently subject to any NSPS. Retirement.Alabama Power has not committed to actual retirement dates for Gaston Units 1 - 5. Alabama Power continually evaluates retirement scenarios with respect to its generating units for a variety of planning purposes, taking into account a wide range of variables. While the company assumes financial "retirement dates" for accounting purposes, for example, for depreciation schedules or for FERC or Public Service Commission uses, these dates are not indicative of the unit's actual retirement date.

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 wall-fired (2) low-NOx burners (11/19/1994) N/A (1) flue gas conditioning - sodium injection1

### (prior to 1994) (3) cold-side ESP was originally installed (05/01/1960) but was de-energized when a hot-side ESP was installed (04/1974) N/A

2 wall-fired (2) low-NOx burners (04/07/1992) N/A (1) flue gas conditioning - sodium injection1

### (prior to 1994) (3) cold-side ESP was originally installed (07/01/1960) but was de-energized when a hot-side ESP was installed (04/1975) (4) baghouse (06/06/1999) N/A

3 wall-fired (2) low-NOx burners (05/23/1993) N/A (1) flue gas conditioning - sodium injection1

### (prior to 1994) (3) cold-side ESP was originally installed (06/01/1961) but was de-energized when a hot-side ESP was installed (12/10/1973) (4) baghouse (12/20/1996) N/A

4 wall-fired (2) low-NOx burners (05/21/1994) N/A (1) flue gas conditioning - sodium injection1

### (prior to 1994) (3) cold-side ESP was originally installed (06/01/1962) but was de-energized when a hot-side ESP was installed (10/15/1972) N/A

## Boiler ID14 

## Type15 

## NOx control16 

## SO2 control17 

## PM control18 

## Other control19


### 5 tangentially-fired (1) low-NOx burners + separated OFA (12/19/1993) (4) SCR (04/29/2006) - the SCR uses a titania-vanadia based ceramic catalyst and anhydrous ammonia as the reductant; the catalyst is designed to minimize SO3 

### formation2 

### (6) calcium-based wet flue gas desulfurization (03/05/2010)(2) dual-injection trona, injection point #1 (03/05/2010) (3) hot-side ESP (08/02/1974)(5) dual-injection trona, injection point #2 [SO3

### ] (03/05/2010)

Note: "N/A" means not applicable.

1

### Sodium injection on Units 1 - 4 has varied between sodium sulfate and sodium carbonate. Units 1 - 4 still have the capability for sodium injection, but the plant has not used it in several years.

2

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

### formation.

14

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

15

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

16

### Examples: low-NOx burners; selective catalytic reduction (SCR); selective non-catalytic reduction (SNCR); over-fire air (OFA). Include specific date that control went online or planned operational date for new installation. If this boiler's control configuration utilizes a SCR, please include the type of material from which the catalyst is manufactured and the type of reductant used in with the SCR (e.g., anhydrous ammonia, urea, other). Also, please note if the catalyst is specifically designed to reduce SO3 formation?

17

### Examples: wet flue gas desulfurization (FGD; any type); dry scrubbing (any type); specify whether calcium- or sodium-based. Include specific date that control went online or planned operational date for new installation.
18

### Examples: fabric filter; cold-side electrostatic precipitator (ESP); hot-side ESP; cyclone or multiclone; venturi scrubber. Include specific date that control went online or planned operational date for new installation.
19

### Please indicate systems installed specifically to control any other pollutants (e.g., Hg, SO3, etc.). Examples: activated carbon injection (ACI); Powerspan ECO®; dry sorbent injection or wet ESP for SO3 control; flue gas conditioning to control opacity (e.g., SO3 injection, ammonia, other); additive use for mercury control (e.g., bromine; scrubber additives). Include specific date that control went online or planned operational date for new installation. Also include any pollutants controlled by this technology (e.g., control technology [pollutant controlled]).

## 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 3 N/A N/A N/A N/A 4 N/A N/A N/A N/A 5 N/A N/A N/A N/A

Note: "N/A" means not applicable.

20

### A control technology demonstration project is defined as a U.S. Government (e.g., U.S. Department of Energy program) sponsored (in whole or in part) project or mandate (e.g., as a result of a consent decree) that adds a HAP control technology to a facility's unit to demonstrate the technology's HAP removal performance.
21

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

## Company (vendor) contact information Boiler ID21 

## Company (vendor) name

## 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 3 N/A N/A N/A N/A N/A N/A 4 N/A N/A N/A N/A N/A N/A 5 N/A N/A N/A N/A N/A N/A
Note: "N/A" means not applicable.

22

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
23

### If additive is used, please indicate injection point.

## 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 3 N/A N/A N/A N/A 4 N/A N/A N/A N/A 5 N/A N/A N/A N/A
Note: "N/A" means not applicable.

24

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

## Company (vendor) contact information Boiler ID24 

## Company (vendor) name

## 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 3 N/A N/A N/A N/A N/A N/A 4 N/A N/A N/A N/A N/A N/A 5 N/A N/A N/A N/A N/A N/A
Note: "N/A" means not applicable.

25

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
26

### If additive is used, please indicate injection point.

## 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 0.12 lb/MMBtu (Title V permit; annual Reference Method 5 or 17) N/A N/A 3.8 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/A N/A

2 0.12 lb/MMBtu (Title V permit; annual Reference Method 5 or 17) N/A N/A 3.8 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/A N/A

3 0.12 lb/MMBtu

(Title V permit; annual Reference Method 5 or 17) N/A N/A 3.8 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/A N/A

4 0.12 lb/MMBtu

(Title V permit; annual Reference Method 5 or 17) N/A N/A 3.8 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/A N/A

5 0.12 lb/MMBtu

(Title V permit; annual Reference Method 5 or 17) N/A N/A 3.8 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

27

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
28

### If the boiler has separate permitted emission limits for filterable and condensable PM, respectively, please indicate those separate limits. Also include the compliance test method utilized.
29

### List the compliance test method utilized.

30

### List the compliance test method utilized.

31

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

## Permitted emission limit (indicate type of permit and format of emission limit)
Boiler ID27

## 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: 99.3% collection efficiency guarantee (expired in 1974) N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

2 baghouse: 0.005 gr/dscf (expired in 1999) N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

3 baghouse: 0.005 gr/dscf (expired in 1997) N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

4 ESP: 0.10 lb/MMBtu, filterable (expired in 2009) N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

5 ESP: 0.06 lb/MMBtu, filterable(expired in 2006); FGD: CBI N/A N/A FGD: 98% instantaneous removal efficiency to meet a 95% 30-day rolling average removal efficiency1 

### N/A N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

1

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



## 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, question15, provide the following information:

PM36 

## PM10 

## PM2.5 

## SO2 HCl and/or HF HCN Metal

HAP37 

## Hg CO Other organics (specify) 1 Emission tests for particulate matter will be conducted annually. Consecutive tests will not be conducted sooner than six months apart or later than eighteen months apart unless approved by the Director. Results will be reported to the Director within thirty days of completion of testing. The Director must be notified at least ten days in advance of all emission tests that will be conducted submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/AThe installed Continuous Sulfur Dioxide Emissions Monitor will be operated, maintained, and certified using 40 CFR Part 75 procedures. Data from this monitor will also be used to provide an indication of the sulfur dioxide emissions from these units, using pounds per million Btu computed on a 24- hour rolling average. A summary emission report will be submitted to ADEM within thirty days of the end of each calendar quarter. Deviations from permit requirements shall be reported within 48 hours or 2 working days of such deviations, including those attributable to upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventative measures that were taken. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A

2 Emission tests for particulate matter will be conducted annually. Consecutive tests will not be conducted sooner than six months apart or later than eighteen months apart unless approved by the Director. Results will be reported to the Director within thirty days of completion of testing. The Director must be notified at least ten days in advance of all emission tests that will be conducted submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/AThe installed Continuous Sulfur Dioxide Emissions Monitor will be operated, maintained, and certified using 40 CFR Part 75 procedures. Data from this monitor will also be used to provide an indication of the sulfur dioxide emissions from these units, using pounds per million Btu computed on a 24- hour rolling average. A summary emission report will be submitted to ADEM within thirty days of the end of each calendar quarter. Deviations from permit requirements shall be reported within 48 hours or 2 working days of such deviations, including those attributable to upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventative measures that were taken. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A

3 Emission tests for particulate matter will be conducted annually. Consecutive tests will not be conducted sooner than six months apart or later than eighteen months apart unless approved by the Director. Results will be reported to the Director within thirty days of completion of testing. The Director must be notified at least ten days in advance of all emission tests that will be conducted submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/AThe installed Continuous Sulfur Dioxide Emissions Monitor will be operated, maintained, and certified using 40 CFR Part 75 procedures. Data from this monitor will also be used to provide an indication of the sulfur dioxide emissions from these units, using pounds per million Btu computed on a 24- hour rolling average. A summary emission report will be submitted to ADEM within thirty days of the end of each calendar quarter. Deviations from permit requirements shall be reported within 48 hours or 2 working days of such deviations, including those attributable to upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventative measures that were taken. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A 

## Required monitoring, recordkeeping, and reporting requirements for each pollutant for which there is a permitted emission limit
Boiler ID35

## PM36 

## PM10 

## PM2.5 

## SO2 HCl and/or HF HCN Metal

HAP37 

## Hg CO Other organics (specify) Required monitoring, recordkeeping, and reporting requirements for each pollutant for which there is a permitted emission limit
Boiler ID35



### 4 Emission tests for particulate matter will be conducted annually. Consecutive tests will not be conducted sooner than six months apart or later than eighteen months apart unless approved by the Director. Results will be reported to the Director within thirty days of completion of testing. The Director must be notified at least ten days in advance of all emission tests that will be conducted submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/AThe installed Continuous Sulfur Dioxide Emissions Monitor will be operated, maintained, and certified using 40 CFR Part 75 procedures. Data from this monitor will also be used to provide an indication of the sulfur dioxide emissions from these units, using pounds per million Btu computed on a 24- hour rolling average. A summary emission report will be submitted to ADEM within thirty days of the end of each calendar quarter. Deviations from permit requirements shall be reported within 48 hours or 2 working days of such deviations, including those attributable to upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventative measures that were taken. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A

5 Emission tests for particulate matter will be conducted annually. Consecutive tests will not be conducted sooner than six months apart or later than eighteen months apart unless approved by the Director. Results will be reported to the Director within thirty days of completion of testing. The Director must be notified at least ten days in advance of all emission tests that will be conducted submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/AThe installed Continuous Sulfur Dioxide Emissions Monitor will be operated, maintained, and certified using 40 CFR Part 75 procedures. Data from this monitor will also be used to provide an indication of the sulfur dioxide emissions from these units, using pounds per million Btu computed on a 24- hour rolling average. A summary emission report will be submitted to ADEM within thirty days of the end of each calendar quarter. Deviations from permit requirements shall be reported within 48 hours or 2 working days of such deviations, including those attributable to upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventative measures that were taken. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

35

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
36

### If the boiler's monitoring, recordkeeping, and reporting requirements require your company to monitoring, keep records, and report filterable and condensable PM separately, please describe the separate actions required.
37

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

## 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:

E C Gaston 1bPlant or facility code from Part I, question 4b:

Plant Code - 26

39

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

### 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 % A sh Btu/lb 7,565 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.45 13.30 12,982 7,722 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 12.78 12,972 7,641 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 14.20 12,906 7,514 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 14.05 12,827 7,625 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.89 12,843 7,655 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.61 13,069 7,555 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.57 12.30 13,210 7,544 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.24 12,944 7,773 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.20 13,007 7,526 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.40 12,962 7,575 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.68 12,959 7,394 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 12.38 13,109 7,324 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.27 13,025 7,529 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 12.43 13,117 7,618 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.87 13,056 7,392 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.21 12,898 7,618 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 13.06 13,036 7,483 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.44 12,944 7,597 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.49 12,893 7,440 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 12.89 12,944 7,573 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 12.89 12,951 7,538 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 13.20 12,949 7,621 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.03 13,001 7,442 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 12.83 13,060 7,673 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.23 13.39 12,993 7,501 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 12.32 13,089 7,407 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 12.41 13,122 7,638 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 12.68 13,054 7,579 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.84 13,057 7,687 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 13.01 13,077 7,562 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.04 13,040 7,647 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 13.06 13,018 7,531 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.49 12,975 7,480 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 13.79 12,870 7,594 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 12.78 13,146 7,597 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 12.98 13,028 6,978 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 13.21 12,968 7,559 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.17 12,984 7,608 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 12.10 13,236 7,403 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 12.26 13,151 7,503 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 12.53 13,142 7,149 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 13.26 12,978 7,174 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 12.62 13,063 6,684 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.49 13.20 12,959 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method

### D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 

### % Sulf % A sh Btu/lb 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 7,246 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 12.76 13,090 7,687 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.04 12,846 7,651 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.80 13,083 7,578 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.63 13,069 7,799 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.23 13,159 7,589 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 12.37 13,141 7,542 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.98 13,062 7,535 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.44 12.86 13,042 7,666 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.01 13,058 7,475 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.75 13,114 7,673 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.77 13,069 7,679 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 12.24 13,146 7,640 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 11.92 13,181 7,716 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.24 13,225 7,692 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.02 13,158 7,717 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 11.96 13,232 7,752 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.58 13,133 7,759 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.37 13,078 7,781 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.59 13,118 7,527 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 12.88 13,014 7,611 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 13.06 13,037 7,744 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.02 12,993 7,651 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.08 13,054 7,624 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 13.30 13,007 7,475 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.72 13,096 7,523 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.28 12.49 13,122 7,678 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 12.49 13,100 7,460 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.74 12,944 7,547 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 13.66 12,883 7,548 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.73 12,938 8,105 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 11.52 13,395 7,623 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.73 12,925 7,729 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 13.90 12,894 7,779 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.20 12,969 7,827 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.44 12,999 7,757 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 13.02 13,017 7,650 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 13.27 12,955 7,684 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.52 12,985 7,794 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.31 12,966 7,603 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.76 13,081 7,617 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.33 13,024 7,585 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.48 12.95 13,029 7,830 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.07 13,078 7,692 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.76 13,081 7,727 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 12.95 13,050 7,899 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.93 13,045

### D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 

### % Sulf % A sh Btu/lb 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 7,865 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.62 13,074 7,892 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 13.19 12,972 7,848 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 12.92 13,039 7,775 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.73 12,886 7,831 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.55 14.44 12,808 7,759 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 12.40 13,105 7,838 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.16 13,206 7,850 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.60 13,119 7,608 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 12.39 13,111 7,781 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 13.00 12,972 7,742 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.44 12.79 13,069 7,846 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 12.77 13,089 7,862 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 12.31 13,132 7,776 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.65 13,084 7,676 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 12.78 13,051 7,810 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.31 12,965 7,690 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.50 13.80 12,951 7,803 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 13.09 13,028 7,770 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.47 12.99 13,098 7,710 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.78 13,062 7,743 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 13.13 13,003 7,082 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.56 13,077 7,768 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 12.89 13,115 7,741 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.51 12,996 7,785 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 13.54 12,921 7,813 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.17 12,962 7,678 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.48 13.35 12,925 7,899 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 12.63 13,100 7,787 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.64 13,152 7,764 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.88 13,077 7,790 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.46 12.96 12,987 7,755 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.47 12.51 13,005 7,707 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 12.58 13,087 7,040 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 12.43 13,086 7,902 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.38 12.73 13,044 7,696 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.44 13,139 7,655 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.21 12.46 13,061 7,689 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.47 13.19 12,956 7,697 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.06 13,029 7,816 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 12.10 13,129 7,818 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 12.70 13,114 7,768 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.55 13.09 13,025 7,605 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.31 13.60 12,936 7,736 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 13.72 12,936 7,271 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.40 12,912 7,864 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 14.01 12,903

### D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 

### % Sulf % A sh Btu/lb 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 7,788 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 1.16 13.05 13,003 7,731 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.52 12.88 13,031 7,893 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.42 12.30 13,128 7,725 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.09 13,041 7,884 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 12.94 13,051 7,808 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 13.16 13,009 7,730 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.08 13.10 12,965 7,512 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.11 13.15 12,998 6,918 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 1.99 12.98 13,046 7,497 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.09 12.64 13,100 7,739 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.07 13.19 12,967 7,518 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.04 12.81 13,062 7,784 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.07 12.70 13,062 7,831 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.10 12.99 13,030 7,763 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.11 12.92 13,005 7,663 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 14.01 12,857 7,801 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.33 13.45 12,924 7,480 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.21 12.60 13,097 7,880 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 12.18 12,818 7,646 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.05 13.03 13,050 7,545 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.08 12.92 13,038 7,646 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.14 12.97 13,028 7,661 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 12.67 13,071 7,869 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.28 12.63 13,052 7,492 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 12.62 13,115 7,842 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 13.15 13,018 7,693 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.26 12.95 13,069 7,892 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.32 12.97 13,043 7,790 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 13.15 13,015 7,923 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.73 12,947 7,749 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 0.83 14.98 12,406 7,414 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 12.93 13,046 7,717 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.21 12.73 13,060 7,566 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 12.26 13,212 7,726 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 12.09 13,121 7,591 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 12.07 13,198 7,425 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.02 13,181 7,613 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.17 13.16 12,988 7,292 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.10 12.63 13,215 7,440 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.37 13,136 7,787 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 12.92 13,076 7,630 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 12.85 12,984 7,847 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.17 13.48 12,912 7,697 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 13.74 12,892 7,674 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 12.95 13,010 7,653 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.18 13,001

### D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 

### % Sulf % A sh Btu/lb 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 7,101 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.09 13,046 7,630 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.28 12.55 13,096 7,816 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.16 13,053 7,793 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.29 13.08 13,005 7,822 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 12.70 13,107 7,694 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.36 12.83 13,028 7,728 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 13.07 12,968 7,850 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 13.17 13,098 7,125 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 13.00 13,051 7,916 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 13.33 12,976 7,780 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 12.91 13,057 7,835 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 13.01 13,025 7,505 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 11.67 13,230 7,700 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 12.82 13,095 7,478 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.21 12.66 13,075 7,823 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.23 13.26 12,986 7,683 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.26 13.63 12,935 7,797 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 12.74 13,103 7,771 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.56 12,911 7,824 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.29 12,988 7,879 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.20 13.50 12,975 7,940 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 12.78 13,030 7,734 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.06 13.28 12,908 7,884 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.17 13.90 12,902 7,764 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.04 13.65 12,885 7,748 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.19 14.06 12,847 7,798 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.13 13.28 12,958 7,675 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.13 12.89 13,049 7,840 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.11 13.04 13,032 7,694 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.13 13.82 12,962 7,754 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.10 13.13 13,004 7,739 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.35 13.49 12,962 7,778 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.16 14.29 12,847 7,937 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.24 13.30 13,014 8,087 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.27 13.21 13,044 7,774 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.28 12.58 13,131 7,624 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.30 12.60 13,096 7,823 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.05 14.40 12,807 7,761 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 13.35 12,991 7,741 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.26 13.58 12,955 7,754 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.25 13.22 12,970 7,842 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.23 13.47 12,971 7,661 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.69 13,077 7,628 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.41 12.56 13,162 7,744 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 13.04 13,099 7,779 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 13.36 13,057

### D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 

### % Sulf % A sh Btu/lb 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 7,681 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 13.22 13,036 7,130 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.12 13.56 12,953 7,781 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.10 14.63 12,822 7,790 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.18 13.60 12,942 7,710 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.09 12.74 13,059 7,730 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.13 13.54 12,954 7,792 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.34 13.52 12,969 7,753 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.37 12.73 13,046 7,937 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.22 13.74 12,953 7,709 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.39 13.27 12,944 7,630 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.43 12.17 13,124 7,806 1, 2, 3, 4, 5 ALABAMA FAYETTE, TUSCALOOSA PRATT TRAIN 2.40 12.61 13,087 6,396 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.90 16.27 12,617 6,598 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.71 16.32 12,542 6,557 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.71 15.35 12,721 6,825 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.09 15.11 12,691 6,826 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.50 16.08 12,610 6,740 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.75 12.70 13,183 6,619 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.71 12.65 13,066 6,743 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.08 13.58 12,977 6,737 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.80 13.77 13,011 6,296 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.66 13.94 12,971 6,743 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.42 15.76 12,592 6,686 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.29 15.63 12,558 6,612 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.20 15.37 12,715 6,030 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.99 13.38 13,028 6,503 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.51 13.06 12,991 6,588 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.79 11.77 13,286 6,623 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.93 14.53 12,882 6,500 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.60 12.93 13,160 6,570 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.55 13.93 12,911 6,367 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.01 14.43 12,885 6,475 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.74 12.26 13,218 6,595 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.45 12.37 13,265 6,720 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.47 13.59 13,109 6,673 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.64 13.01 13,046 6,738 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.89 14.39 12,869 6,633 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 14.40 12,887 6,659 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 14.28 12,914 6,702 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.77 14.40 12,919 6,694 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.66 13.89 12,910 6,677 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.84 14.86 12,762 6,857 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 2.00 14.28 12,862 6,653 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.75 12.50 13,112 6,643 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 11.37 13,308 6,550 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.79 13.65 13,001

### D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 

### % Sulf % A sh Btu/lb 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 6,500 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 13.86 12,971 6,549 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.80 13.71 12,921 6,644 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.72 13.89 12,913 6,593 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.77 13.56 13,014 6,484 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.80 13.57 13,027 6,722 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.81 14.04 12,977 6,643 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.78 14.35 12,870 6,673 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.76 14.47 12,806 6,688 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.85 14.80 12,721 6,601 1, 2, 3, 4, 5 ALABAMA WALKER AMERICA TRAIN 1.97 14.16 12,904 9,993 1, 2, 3, 4, 5 ALABAMA HARLAN HARLAN, KELLIOKA, SPLINT, HARLAN TRAIN 1.08 9.65 13,518 9,931 1, 2, 3, 4, 5 ALABAMA HARLAN HARLAN, KELLIOKA, SPLINT, HARLAN TRAIN 1.12 11.22 13,224 6,655 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER

### TRAIN 1.86 13.87 12,954 6,580 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER

### TRAIN 1.61 14.73 12,764 6,601 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER

### TRAIN 1.38 14.17 12,786 6,626 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER

### TRAIN 1.59 14.69 12,762 6,598 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER

### TRAIN 1.60 12.32 13,238 6,597 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER

### TRAIN 1.75 13.52 12,999 6,750 1, 2, 3, 4, 5 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK, BLACK CREEK, BROOKWOOD, CARTER, COBB, JAGGER

### TRAIN 1.70 12.85 13,040 8,787 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 17.03 12,648 8,831 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.94 16.29 12,754 8,677 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 16.96 12,632 8,848 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.98 16.49 12,743 9,004 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.10 17.95 12,470 8,951 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.88 17.31 12,484 8,974 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.82 18.55 12,411 8,940 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.90 18.98 12,361 8,872 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.94 18.40 12,492 9,000 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.02 19.06 12,322 8,939 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 17.85 12,431 8,969 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.12 19.41 12,245 8,863 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.17 17.30 12,680 8,741 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.23 17.81 12,621 9,777 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.11 17.15 12,670 9,198 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.11 16.30 12,512 9,261 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.17 13.60 13,319 9,466 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.99 16.90 12,472 8,957 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.94 16.18 12,683 9,443 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.93 15.73 12,841 8,943 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.91 16.67 12,706 8,955 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 16.29 12,755 8,949 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.97 17.52 12,516 8,578 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.86 15.94 12,859 8,688 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.99 15.88 12,828 8,781 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.98 15.78 12,867 8,940 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.08 14.47 13,077

### D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 

### % Sulf % A sh Btu/lb 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 8,508 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.95 15.65 12,961 8,603 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.02 14.13 13,217 7,502 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 13.90 13,184 9,118 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.09 13.66 13,245 9,061 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 14.54 13,105 9,305 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.15 13.56 13,192 9,335 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.07 13.21 13,304 9,826 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.10 14.44 13,062 9,733 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 15.11 12,966 9,850 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.04 14.53 13,006 9,831 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.11 13.00 13,350 9,734 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 14.70 13,019 10,031 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.07 15.66 12,896 9,930 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.02 15.44 12,852 9,524 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 14.71 12,950 9,537 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.06 15.75 12,783 9,787 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.01 14.26 13,001 9,277 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.96 15.65 12,807 9,121 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 15.74 12,753 9,254 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.08 14.90 12,941 9,844 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.96 14.35 13,054 9,912 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.98 14.70 13,029 10,142 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.98 14.61 13,072 9,754 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.86 15.01 12,909 9,805 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.92 14.17 13,075 9,369 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.97 14.45 13,095 9,590 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.02 14.24 13,176 9,635 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.97 14.69 13,083 9,815 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 16.05 12,834 9,042 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.92 15.36 12,913 9,220 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.94 15.90 12,806 9,260 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.93 15.14 13,016 9,171 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.95 16.28 12,813 8,791 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.04 16.34 12,816 8,904 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.17 16.43 12,750 9,037 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.10 14.35 13,048 8,987 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 16.16 12,801 8,787 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.88 16.11 12,730 8,954 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.96 15.73 12,887 8,916 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 15.74 12,805 8,950 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.00 16.49 12,839 9,149 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.08 15.61 12,942 10,132 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.03 16.79 12,717 9,533 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 0.99 15.83 12,883 9,522 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 17.77 12,472 9,190 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.08 16.19 12,775

### D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 

### % Sulf % A sh Btu/lb 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 8,776 1, 2, 3, 4, 5 N/A N/A BLACK CREEK, BLUE CREEK, JAGGER, MARY LEE, NEWCASTLE TRAIN 1.05 15.29 12,863 6,645 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.97 13.76 12,795 6,705 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.15 13.64 12,796 6,718 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.98 12.80 12,937 6,657 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.90 14.31 12,933 6,722 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.92 14.31 12,860 6,612 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.01 13.40 13,008 6,720 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.11 13.78 12,811 0 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN N/A N/A N/A 6,602 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.93 14.00 12,713 6,546 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.97 11.37 13,257 6,467 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.74 14.09 12,834 6,653 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.11 14.54 12,748 6,697 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.02 12.13 12,999 6,468 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.08 11.11 13,318 6,606 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.12 12.51 13,150 6,285 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.05 13.35 12,970 6,216 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 1.03 12.73 12,932 6,302 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.98 13.56 12,934 6,648 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.90 12.61 12,985 6,581 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.88 16.52 12,458 6,546 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.88 16.59 12,436 6,527 1, 2, 3, 4, 5 ALABAMA WALKER BOTTOM AMERICA, NICKEL PLATE, PRATT, TOP AMERICA TRAIN 0.98 14.24 12,800 10,228 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.92 8.85 13,667 9,961 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.89 9.28 13,656 10,197 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.91 8.71 13,712 10,294 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.84 8.36 13,831 10,146 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.88 7.76 13,842 9,929 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.79 7.36 13,958 10,207 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.82 7.47 13,924 10,186 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.90 8.44 13,760 10,516 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.96 7.48 13,945 10,508 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.97 8.51 13,750 10,369 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 1.10 8.37 13,732 10,451 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 1.04 7.59 13,888 10,161 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.99 8.63 13,703 10,107 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.93 7.85 13,861 10,317 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.93 8.87 13,706 10,129 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.90 8.27 13,793 10,399 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.92 7.48 13,931 10,236 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.88 8.56 13,751 10,397 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.91 8.13 13,833 10,257 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.98 7.48 14,024 10,318 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.86 8.13 13,831 10,358 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.94 8.89 13,685 10,394 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD 4 TRAIN 0.86 8.40 13,776

### D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 

### % Sulf % A sh Btu/lb 

### Vendor Analyses Fuel source Amount received, dry basis, short tons40 

### ID # of boiler(s) firing fuel41 

### Fuel shipment method 9,244 1, 2, 3, 4, 5 KENTUCKY HARLAN HARLAN, KELLIOKA, SPLINT TRAIN 1.07 8.81 13,558 9,509 1, 2, 3, 4, 5 KENTUCKY HARLAN HARLAN, KELLIOKA, SPLINT TRAIN 1.16 10.24 13,393 6,559 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 1.05 8.53 13,887 6,740 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.97 8.38 13,909 6,672 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 1.04 10.64 13,538 6,404 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 1.35 10.13 13,578 6,210 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.97 9.00 13,799 6,659 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.97 8.01 13,995 6,301 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.89 8.49 13,964 6,682 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.93 8.44 13,865 6,358 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.94 8.36 13,930 6,259 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.90 9.15 13,792 6,460 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.92 8.86 13,777 6,325 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.95 8.31 13,925 6,198 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.92 9.06 13,744 6,582 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.87 10.53 13,629 6,516 1, 2, 3, 4, 5 ALABAMA WALKER PRATT TRAIN 0.91 8.06 13,879 10,142 1, 2, 3, 4, 5 KENTUCKY FLOYD ONYX TRAIN 1.08 13.95 12,795 10,303 1, 2, 3, 4, 5 KENTUCKY FLOYD ONYX TRAIN 1.16 11.88 13,112 9,717 1, 2, 3, 4, 5 KENTUCKY FLOYD ONYX TRAIN 1.19 11.84 13,131 9,903 1, 2, 3, 4, 5 KENTUCKY FLOYD ONYX TRAIN 1.07 12.75 12,855 9,945 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.80 13.71 12,690 10,120 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.99 14.37 12,544 9,987 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.85 13.76 12,679 10,023 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.01 11.85 13,093 10,123 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.91 12.58 12,900 9,939 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.89 11.88 12,923 9,962 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 13.69 12,786 10,037 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.85 12.85 12,883 10,141 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.88 13.75 12,666 10,210 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.01 12.87 12,827 9,921 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.93 13.46 12,755 9,977 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.92 10.85 13,145 9,978 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 1.06 15.01 12,415 10,196 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.91 10.26 13,243 10,027 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.79 14.08 12,671 10,057 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.86 14.33 12,601 10,280 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.83 12.71 12,880 10,116 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.82 9.79 13,393 10,031 1, 2, 3, 4, 5 KENTUCKY PERRY HAZARD #8, HAZRAD #9 TRAIN 0.94 12.21 12,9613For 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):

AntimonyArsenicBerylliumCadmiumChromiumCobalt Lead ManganeseSelenium

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

09-605 7,914 2.22 12.41 13,044 0.096 144 52 16.8 1.5 12.7 1.6 0.12 21.6 8.5 9.5 28.4 2.1AL Fayette Pratt Train 09-606 7,008 1.71 13.19 12,878 0.226 136 61 15.2 3.0 43.5 2.3 0.33 21.2 9.5 9.0 25.0 3.1AL Walker, Tuscaloosa Washed America - Pratt, JWR Blue Creek seam fines, America, Pratt Train

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

09-608 7,123 0.94 14.35 12,829 0.078 435 61 12.4 1.9 12.5 1.7 0.04 18.1 7.6 5.4 38.5 1.3AL Jefferson, Walker Mary Lee, Top American, American #1 Train 09-609 8,133 2.22 13.20 12,939 0.095 169 68 15.9 1.1 13.2 1.6 0.07 21.5 8.2 7.5 62.4 1.8AL Fayette, Marion, Winston Pratt, Butahatchee, Meredyth Train 09-618 6,899 1.57 13.51 13,058 0.187 134 69 15.6 2.2 26.8 1.4 0.13 21.6 8.6 7.4 29.7 2.5AL Walker, Tuscaloosa Washed America - Pratt, JWR Blue Creek, America, Pratt Train

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

09-623 7,557 2.30 13.06 13,035 0.151 151 44 18.3 1.5 13.8 1.7 <0.02 25.6 9.4 6.7 33.8 2.2AL Fayette Pratt Train 09-624 7,108 1.02 10.32 13,609 0.125 143 34 10.0 1.7 26.1 1.6 0.24 16.5 7.0 3.4 32.7 2.0AL Walker Nickel Plate, Top America, Washed Nickel Plate, Washed Top America Train

09-403 10,714 1.02 7.97 13,786 ND 205 66 12.6 <1 8.8 2.1 0.06 10.5 6.9 6.7 17.7 2.3KY Harlan Harlan, Creech, Kellioki, Darby, Splint Train 09-405 11,312 0.95 10.46 13,351 ND 1701 59 24.8 1.8 11.2 4.1 0.06 31.2 13.7 14.9 24.8 6.6KY Perry Elkhorn #3, Elkhorn #2, Hazard #8, Hazard #7Train

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

09-416 10,152 1.17 9.91 13,419 0.089 154 57 15.5 1.6 7.9 2.8 <0.02 15.6 8.0 9.7 19.9 2.1KY Harlan Harlan, Creech, Kellioki, Darby, Splint Train 09-625 8,200 2.38 13.40 12,907 0.130 157 63 16.5 1.7 11.6 1.6 0.05 22.6 8.2 8.5 32.1 2.1AL Fayette, Walker Pratt, Mary Lee Train 09-421 12,722 1.09 8.42 13,760 ND 1956 77 13.1 1.2 5.8 1.8 ND 15.6 7.2 7.3 14.2 3.3KY Perry Elkhorn #3, Elkhorn #2, Hazard #8, Hazard #7Train

09-415 10,500 0.91 10.48 13,340 ND 127 88 13.2 1.2 10.2 1.9 0.68 12.6 7.6 7.4 30.4 2.3KY Harlan Harlan, Creech, Kellioki, Darby, Splint Train 09-409 10,800 0.89 13.05 12,741 ND 567 111 13.1 <1 5.4 2.6 ND 22.8 8.1 10.5 13.8 5.2KY Perry and Breathitt Hazard 5A, Hazard #7, Hazard #8, Hazard #9Train

09-646 10,020 1.01 15.42 12,872 0.078 116 66 20.4 1.9 41.0 2.0 0.20 27.9 12.4 11.5 59.8 1.0AL Jefferson, Shelby, Tuscaloosa, Walker Blue Creek #2, #2 Upper& Lower Mary Lee, Lower Helena #1, Mary Lee, Blue Creek, #3 Fines, Thompson, #2 Upper & Lower New Castle Train

09-641 7,575 2.39 13.06 12,996 0.182 133 68 16.9 1.7 15.2 1.3 0.09 20.9 8.5 9.5 33.7 2.2AL Fayette Pratt Train 09-639 7,116 1.67 13.97 12,948 0.256 108 65 11.6 2.1 33.4 1.5 0.24 20.6 7.6 8.7 31.0 2.7AL Walker, Tuscaloosa Pratt, Bottom & Top America, Nickle Plate, Blue Creek Train

09-637 8,320 2.44 12.97 12,994 0.236 142 47 16.6 1.9 25.5 1.3 0.21 21.3 8.8 9.3 35.5 2.1AL Fayette, Walker Pratt, Mary Lee Train 09-635 6,600 1.00 8.41 13,872 0.209 111 43 9.3 2.3 16.6 1.7 0.10 13.9 6.1 5.7 18.9 2.0AL Walker, Tuscaloosa Top America, Nickle Plate, Blue Creek Train 09-633 8,864 0.90 15.40 12,534 0.105 337 62 17.4 2.2 16.9 2.3 0.04 22.5 11.2 9.9 76.2 1.1AL Jefferson, Walker, Franklin Blue Creek, Bear Creek, Black Creek, America #1, Mary Lee, Top America, Nickle Plate Barge

09-108 8,273 2.02 14.00 12,826 0.124 180 51 18.6 1.6 16.7 1.3 0.09 27.0 10.1 11.0 37.6 2.1AL Fayette, Walker Pratt, Marylee Train 09-110 7,812 2.16 12.63 13,082 0.122 165 35 18.4 1.4 15.6 1.4 0.10 24.9 9.6 11.0 36.2 2.3AL Fayette Pratt Train 09-650 7,113 1.34 13.82 12,842 0.149 430 63 19.5 2.0 27.8 2.4 0.24 25.5 11.9 11.3 55.3 1.6AL Walker, Franklin, Winston Mary Lee (WC), Bear Creek, Black Creek, Jefferson, Blend, Blue Crrek, Parrish America #1, Pratt, Bottom&Top America, Nickel Plate Train

09-652 7,114 1.71 13.44 13,023 0.294 218 46 18.1 2.7 45.8 1.9 0.27 22.6 8.6 8.5 29.5 2.1AL Walker, Franklin, Winston Mary Lee (WC), Bear Creek, Black Creek & HA, Jefferson, Parrish America 1 & 2, Pratt, Blue Creek, Bottom & Top America, Nickle PlateTrain

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

09-660 9,996 0.95 16.10 12,859 0.071 112 69 17.5 2.2 17.0 1.5 0.04 24.6 10.7 9.4 42.9 1.1AL Jefferson, Shelby Blue Creek #2, Lower Helena #1, Blue Creek, #3 fines (WC) Train

09-444 11,080 0.80 12.88 12,797 0.039 743 80 16.5 1.0 5.9 2.5 <0.02 26.4 9.1 12.5 13.6 5.1KY Perry and Breathitt Hazard 5A, Hazard #7, Hazard #8, Hazard #9, Hazard #10 Train

09-426 10,500 1.23 9.28 13,568 ND 159 77 19.4 1.6 13.6 3.0 0.09 15.5 10.7 10.8 33.8 2.3KY Harlan Harlan, Creech, Kellioki, Darby, Splint Train 09-428 12,530 1.07 9.48 13,464 ND 142 73 18.0 1.6 7.2 3.7 0.12 15.8 9.7 10.2 21.5 2.1KY Harlan Harlan, Creech, Kellioki, Darby, Splint Train 09-433 12,680 1.06 8.34 13,737 ND 1999 59 13.8 1.0 7.0 2.1 0.04 13.4 7.4 8.3 16.9 3.0KY Perry Elkhorn #3, Elkhorn #2, Hazard #8, Hazard #7Train

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

09-112 7,121 1.80 14.31 12,843 0.231 127 49 15.1 1.9 40.5 1.9 0.22 26.4 8.1 9.0 23.6 2.7AL Walker Bottom America Seam Washed, # 3 American Seam, JWR Processed Fines (Blue Creek Seam), Pratt Seam Train

09-447 11,310 0.91 9.67 13,446 ND 223 70 15.1 1.3 9.0 2.7 0.03 15.3 8.5 8.1 31.6 2.3KY Harlan Harlan, Creech, Kellioki, Darby, Splint Train 09-448 11,207 0.91 8.24 13,773 ND 1815 64 13.0 1.0 10.3 2.2 0.02 13.1 7.8 7.6 16.3 3.5KY Perry Elkhorn #3, Elkhorn #2, Hazard #8, Hazard #7Train

Note: "ND" means non-detect. Note: Alabama Power collects this information on select coal shipments, but does not have this information available on a shipment by shipment basis. The information Alabama Power provides in this response cannot be linked to the information in Part II, Question 2 because the information comes from two separate databases. Thus, the information provided in this response represents only a very small portion of our actual shipments.

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. Sample ID # State/Country County Coal Seam Fuel Shipment Method Total amount of fuel represented by sample, tons Total Sulfur,

% Ash Content,

% Heating Value,

Btu/lb Mercury,

ppm Chlorine,

ppm Fluorine,

ppm Nickel,

ppm Other Trace Metal HAP, 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 CarbonCarbonHydrogenNitrogenTotal SulfurOxygenBariumCopperMagnesiumSodiumVanadium Zinc Al2O3 Fe2O3 CaO MgO MnO2 P2O5 K2O SiO2 Na2O SO3 TiO2

09-603 6.38 26.91 19.23 53.86 71.25 4.39 1.30 0.93 2.90 250 27.1 0.131 0.027 52.7 28.4 30.71 7.37 1.05 1.130.04391 0.27 2.79 53.82 0.19 1.11 1.36 09-605 4.99 35.20 12.41 52.39 74.47 4.82 1.60 2.22 4.48 230 32.1 0.097 0.046 49.5 20.6 26.42 14.71 4.78 1.290.03627 0.78 2.31 41.56 0.50 5.91 1.30 09-606 4.16 31.80 13.19 55.01 74.30 4.68 1.54 1.71 4.58 670 36.1 0.073 0.029 50.3 17.7 29.37 11.54 2.50 0.910.02999 1.62 2.07 46.55 0.30 2.67 1.58 09-607 4.33 31.25 7.95 60.80 80.60 4.84 1.76 1.03 3.82 200 15.4 0.062 0.035 21.1 7.6 28.08 9.38 5.70 1.290.05858 0.37 2.04 44.49 0.59 6.32 1.33 09-608 4.50 30.23 14.35 55.42 72.93 4.65 1.72 0.94 5.41 250 17.8 0.11 0.047 34.9 14.9 26.72 6.50 1.88 1.270.04251 0.38 2.94 56.61 0.44 1.77 1.24 09-609 7.07 34.61 13.20 52.19 72.66 4.84 1.69 2.22 5.39 210 28.8 0.104 0.038 50.3 19 25.99 15.60 3.62 1.310.07485 0.71 2.42 44.33 0.39 3.91 1.29 09-618 5.60 31.32 13.51 55.17 73.74 4.70 1.60 1.57 4.88 470 29.4 0.08 0.039 46.7 13.3 27.97 10.71 2.68 0.980.03477 1.19 1.89 49.33 0.39 2.53 1.66 09-619 7.30 31.30 14.49 54.21 72.21 4.60 1.67 0.94 6.09 300 20.4 0.107 0.032 40.7 18.3 27.15 7.12 1.98 1.230.08333 0.71 3.03 55.36 0.30 1.58 1.23 09-623 7.14 34.92 13.06 52.02 73.10 4.92 1.92 2.30 4.70 220 35.3 0.102 0.044 55.8 26.9 26.08 14.67 4.31 1.300.04097 0.68 2.38 43.07 0.46 5.31 1.34 09-624 6.25 30.15 10.32 59.53 77.66 4.77 1.93 1.02 4.30 280 21.4 0.075 0.039 32.2 11.6 27.21 8.99 4.17 1.210.05017 0.44 2.21 48.65 0.51 4.68 1.50 09-403 7.84 36.22 7.97 55.81 78.63 4.98 1.63 1.02 5.78 102 18.7 0.059 0.024 29.2 16 25.60 11.20 2.05 1.11 ND ND 2.69 50.40 0.45 1.30 1.25 09-405 7.99 35.92 10.46 53.62 77.90 4.93 1.61 0.95 4.16 224 37.1 0.118 0.057 63.3 25.3 28.10 6.40 1.80 0.86 ND 0.49 2.26 51.40 0.41 0.96 1.39 09-408 7.46 34.97 13.54 51.50 71.21 4.61 1.43 1.17 8.04 133 19.6 0.049 0.011 32.9 11.1 26.40 6.26 1.14 0.59 ND ND 1.80 58.20 ND ND 1.57 09-416 6.40 35.15 9.91 54.94 76.35 5.06 1.61 1.17 5.90 90 22.8 0.058 0.029 40.7 20.7 28.94 7.36 1.28 0.980.03176 0.28 2.68 55.02 0.39 1.48 1.36 09-625 6.90 35.01 13.40 51.59 72.50 4.93 1.52 2.38 5.27 220 31.4 0.105 0.044 50.9 21.9 26.04 14.16 4.10 1.300.03795 0.7 2.35 44.26 0.44 4.81 1.39 09-421 6.84 36.29 8.42 55.29 75.08 4.91 1.68 1.09 8.82 112 18.9 0.046 0.030 32.8 12.0 28.50 8.31 2.47 0.92 ND 0.69 1.99 47.30 0.63 1.79 1.59 09-415 8.61 34.91 10.48 54.61 73.16 4.79 1.48 0.91 9.19 123 19.3 0.089 0.033 30.7 16.0 25.20 8.30 1.56 1.42 ND ND 3.19 53.80 0.49 1.07 1.15 09-409 8.39 34.31 13.05 52.46 70.77 4.53 1.48 0.89 9.28 143 21.4 0.052 0.013 32.4 9.4 27.50 4.26 1.19 0.62 ND 0.47 1.72 55.40 0.18 0.43 1.89 09-646 7.02 28.09 15.42 56.49 74.03 4.49 1.45 1.01 3.60 300 28.3 0.136 0.028 51.7 34.8 24.82 8.90 1.40 1.460.06132 0.27 3.47 56.34 0.24 1.60 1.20 09-641 6.91 34.91 13.06 52.03 73.10 4.78 1.10 2.39 5.57 220 32.1 0.099 0.039 51.0 22.2 25.07 14.91 5.41 1.260.04078 0.64 2.38 42.44 0.41 5.79 1.24 09-639 5.90 30.40 13.97 55.63 73.71 4.68 1.67 1.67 4.30 520 30.1 0.077 0.039 40.8 11.8 27.56 10.09 3.37 0.910.03515 1.39 1.89 48.42 0.38 3.63 1.65 09-637 6.61 34.93 12.97 52.10 72.82 4.93 1.68 2.44 5.16 230 31.6 0.099 0.043 50.5 22.2 25.86 15.73 4.27 1.260.04328 0.71 2.33 42.36 0.45 5.36 1.31 09-635 5.76 30.40 8.41 61.19 79.36 4.89 1.59 1.00 4.75 200 22.2 0.049 0.029 29.8 8.7 28.22 8.56 3.12 0.960.03551 0.42 2.12 50.97 0.46 3.24 1.58 09-633 6.39 30.25 15.40 54.35 71.39 4.55 1.55 0.90 6.21 250 21.3 0.117 0.034 41.5 22.3 26.33 6.69 1.54 1.260.07830 0.45 2.93 57.39 0.30 1.64 1.22 09-108 7.18 34.21 14.00 51.79 71.67 4.86 1.79 2.02 5.66 260 33.7 0.116 0.048 59.6 23.4 26.31 12.72 4.13 1.370.04252 0.71 2.49 45.85 0.46 4.19 1.36 09-110 6.66 34.78 12.63 52.59 72.71 4.97 1.80 2.16 5.73 230 36.6 0.101 0.042 59.8 42.3 26.37 14.37 4.18 1.320.04537 0.81 2.34 43.59 0.45 4.76 1.37 09-650 7.03 32.31 13.82 53.87 70.84 4.59 1.63 1.34 7.78 300 34.5 0.098 0.028 47.5 19.1 26.41 9.62 1.74 1.180.06332 0.5 2.65 54.07 0.27 1.89 1.35 09-652 7.14 30.81 13.44 55.75 73.35 4.83 1.76 1.71 4.91 410 33.7 0.089 0.030 45.5 16.1 27.09 11.82 1.26 1.100.03475 0.54 2.74 51.97 0.29 1.37 1.42 09-655 7.59 30.26 8.53 61.21 79.28 4.96 2.01 1.01 4.21 210 17.2 0.055 0.027 27.2 10.8 25.46 9.99 4.45 1.070.05418 0.35 2.25 49.93 0.43 4.29 1.40 09-660 8.29 26.24 16.10 57.66 72.97 4.55 1.47 0.95 3.96 370 21.7 0.145 0.034 48.6 24.3 28.57 6.64 1.00 1.490.04217 0.27 3.58 55.52 0.28 1.08 1.23 09-444 7.05 33.46 12.88 53.66 72.72 4.83 1.54 0.80 7.23 160 24.7 0.048 0.018 39.1 9.1 26.38 3.61 1.04 0.610.01673 0.38 1.84 62.66 0.19 0.87 2.22 09-426 7.44 34.50 9.28 56.21 75.38 4.81 1.50 1.23 7.81 143 28.2 0.077 0.027 42.9 23.8 23.40 11.90 1.55 1.25 ND ND 2.70 52.40 0.60 1.38 1.17 09-428 6.51 36.36 9.48 54.17 74.68 4.87 1.57 1.07 8.33 61 28.6 0.042 0.014 44.3 23.0 27.50 7.37 1.26 0.88 ND ND 2.17 54.00 0.42 0.98 1.38 09-433 6.62 35.69 8.34 55.97 76.07 4.84 1.60 1.06 8.09 92 21.5 0.046 0.032 30.8 13.1 28.10 7.94 2.27 0.93 ND ND 2.08 50.80 0.56 1.93 1.46 09-434 6.23 33.69 12.87 53.44 71.73 4.46 1.46 1.01 8.46 102 20.1 0.044 0.013 34.0 8.7 25.40 4.28 1.17 0.53 ND 0.53 1.43 55.20 0.16 ND 1.88 09-112 8.25 31.24 14.31 54.45 72.57 4.77 1.85 1.80 4.70 540 36.5 0.073 0.034 52.1 13.0 27.91 11.05 1.94 0.850.02613 1.42 1.83 50.31 0.33 2.00 1.68 09-447 8.22 35.99 9.67 54.33 74.45 4.77 1.73 0.91 8.48 113 21.2 0.068 0.034 35.8 22.2 27.10 7.87 2.12 1.11 ND ND 2.49 53.80 0.51 1.25 1.24 09-448 6.88 35.96 8.24 55.80 76.49 4.88 1.61 0.91 7.87 92 19.7 0.040 0.030 28.3 10.4 28.60 6.94 2.32 0.80 ND 0.44 1.81 53.30 0.58 1.56 1.59

Note: "ND" means non-detect. Sample ID # Proximate Analyses, % by wt Ultimate Analyses, % by wt 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 (May 12, 2005) Report 2Unit 2 Particulate Emissions Test (May 11, 2005) Report 3Unit 3 Particulate Emissions Test (April 15, 2005) Report 4Unit 4 Particulate Emissions Test (March 29, 2005) Report 5Unit 5 Particulate Emissions Test (June 23, 2005) Report 6Unit 1 Particulate Emissions Test (June 1, 2006) Report 7Unit 2 Particulate Emissions Test (June 9, 2006) Report 8Unit 3 Particulate Emissions Test (April 26, 2006) Report 9Unit 4 Particulate Emissions Test (February 9, 2006) Report 10Unit 5 Particulate Emissions Test (May 16, 2006) Report 11Unit 1 Particulate Emissions Test (May 8, 2007) Report 12Unit 2 Particulate Emissions Test (August 23, 2007) Report 13Unit 3 Particulate Emissions Test (February 13, 2007) Report 14Unit 4 Particulate Emissions Test (April 18, 2007) Report 15Unit 5 Particulate Emissions Test (May 10, 2007) Report 16Unit 1 Particulate Emissions Test (April 17, 2008) Report 17Unit 2 Particulate Emissions Test (July 9, 2008) Report 18Unit 3 Particulate Emissions Test (May 28, 2008) Report 19Unit 4 Particulate Emissions Test (May 29, 2008) Report 20Unit 5 Particulate Emissions Test (May 1, 2008) Report 21Unit 1 Particulate Emissions Test (July 29 and 30, 2009) Report 22Unit 2 Particulate Emissions Test (March 25, 2009) Report 23Unit 3 Particulate Emissions Test (June 2, 2009) Report 24Unit 4 Particulate Emissions Test (July 8, 2009) Report 25Unit 5 Particulate Emissions Test (April 16, 2009) Report 26Unit 1 Compliance Assurance Monitoring Test (June 2, 2006) Report 27Unit 4 Compliance Assurance Monitoring Test (February 10, 2006) Report 28Unit 5 Compliance Assurance Monitoring Test (May 17, 2006) Report 29Unit 5 SO3 Test (March 2009) Report 30Unit 5 SO3 Test (October - November 2009) Report 31Unit 1 Boiler Baseline Performance Test for SCR (August 13-20, 2008) Report 32Unit 2 SCR Baseline Test (July 9 -29, 2008) Report 33Unit 3 Flue Gas Analyzer Verification Performance Test (February 2-9, 2005) Report 34Unit 4 Flame Doctor Test (September 11-18, 2009)

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: 5/12/2005 Type: duct Constituents: PM Report 2 Date: 5/11/2005 Type: duct Constituents: PM Report 3 Date: 4/15/2005 Type: duct Constituents: PM Report 4 Date: 3/29/2005 Type: duct Constituents: PM Report 5 Date: 6/23/2005 Type: duct Constituents: PM Report 6 Date: 6/1/2006 Type: duct Constituents: PM Report 7 Date: 6/9/2006 Type: duct Constituents: PM Report 8 Date: 4/26/2006 Type: duct Constituents: PM Report 9 Date: 2/9/2006 Type: duct Constituents: PM

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

Report 11 Date: 5/8/2007 Type: duct Constituents: PM Report 12 Date: 8/23/2007 Type: duct Constituents: PM Report 13 Date: 2/13/2007 Type: duct Constituents: PM Report 14 Date: 4/18/2007 Type: duct Constituents: PM Report 15 Date: 5/10/2007 Type: duct Constituents: PM Report 16 Date: 4/17/2007 Type: duct Constituents: PM Report 17 Date: 7/9/2008 Type: duct Constituents: PM Report 18 Date: 5/28/2008 Type: duct Constituents: PM Report 19 Date: 5/29/2008 Type: duct Constituents: PM Report 20 Date: 5/1/2008 Type: duct Constituents: PM Report 21 Date: 7/29-7/30/2009 Type: duct Constituents: PM Report 22 Date: 3/25/2009 Type: duct Constituents: PM Report 23 Date: 6/2/2009 Type: duct Constituents: PM Report 24 Date: 7/8/2009 Type: duct Constituents: PM Report 25 Date: 4/16/2009 Type: duct Constituents: PM Report 26 Date: 6/2/2006 Type: duct Constituents: PM Report 27 Date: 2/10/2006 Type: duct Constituents: PM Report 28 Date: 5/17/2006 Type: duct Constituents: PM Report 29 Date: 3/1-3/31/2009 Type: duct Constituents: SO3 Report 30 Date: 10/1-11/30/2009 Type: duct Constituents: SO3 Report 31 Date: 8/13-8/20/2009 Type: duct Constituents: CO, NOx, CO2 Report 32 Date: 7/9-7/29/2008 Type: duct Constituents: CO, NOx, CO2 Report 33 Date: 2/2-2/9/2005 Type: duct Constituents: CO, NOx, CO2 Report 34 Date: 9/11-9/18/2009 Type: duct Constituents: CO, NOx, CO2, unburned carbon

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 29 and 30 contain SO3 data that was collected at the economizer outlet, SCR outlet, and air heater outlet. Reports 31, 32, 33, and 34 tests for CO were conducted at the economizer outlet.

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 note 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 _X

__No ____If yes, please list the unit's complete control configuration at time of testing in a similar format to Part I, question 16. The control configuration shown below is representative of the Units 1-5 conditions present during Reports 1, 2, 3, 4, 5, 6, 7, 8, 9, 11, 12, 13, 14, 16, 17, 18, 19, 21, 22, 23, 24, 26, 27, 31, 32, 33, and 34 (no sodium injection operating on Units 1-4; no SCR, FGD, or trona installed on Unit 5).

Boiler ID 1

2

3

4

5

Note: "N/A" means not applicable.


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

Boiler ID 5

Note: "N/A" means not applicable.

tangentially-fired (1) low-NOx burners + separated OFA (12/19/1993) (3) SCR (04/29/2006) - the SCR uses a titania-vanadia based ceramic catalyst and anhydrous ammonia as the reductant; the catalyst is designed to minimize SO3

### formation1 

### N/A (2) hot-side ESP (08/02/1974) N/A 

### Type NOx control SO2 control PM control Other control

NOx control SO2 control PM control Other control

tangentially-fired (1) low-NOx burners + separated OFA (12/19/1993) N/A (2) hot-side ESP (08/02/1974) N/A wall-fired

wall-fired

wall-fired

wall-fired

### Type

N/A N/A

(1) low-NOx burners (05/21/1994) N/A

N/A

N/A

N/A (2) cold-side ESP was originally installed (05/01/1960) but was de-energized when a hot-side ESP was installed (04/1974) (2) cold-side ESP was originally installed (07/01/1960) but was de-energized when a hot-side ESP was installed (04/1975) (3) baghouse (06/06/1999) (2) cold-side ESP was originally installed (06/01/1961) but was de-energized when a hot-side ESP was installed (12/10/1973) (3) baghouse (12/20/1996)

(2) cold-side ESP was originally installed (06/01/1962) but was de-energized when a hot-side ESP was installed (10/15/1972) N/A N/A (1) low-NOx burners (11/19/1994)

(1) low-NOx burners (04/07/1992)

(1) low-NOx burners (05/23/1993)1

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

### formation.

### 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 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 probably cause of said deviations, and any corrective actions or preventive measures that were taken. The date, time, duration, magnitude, cause and corrective action taken for each excess emission are also included in the quarterly reports submitted to ADEM. Note: Not all reported deviations are considered violations of permit requirements. 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:

Unit 1-2:June 26, 2008 - December 31, 2009 Units 3-4:May 19, 2009 - December 31, 2009 Unit 5: June 10, 2008 - September 3, 2009

COMS data are available for the following time periods:

Unit 1-2:April 1, 1993 - December 31, 2009 Units 3-4:April 1, 1993 - December 31, 2009 Unit 5: November 15, 1993 - December 31, 2009

1

## Alabama Power considers CEMS data "available" only if it is maintained and subject to quality assurance/quality control procedures that meet the requirements of 40 CFR Part 75.

46

### Where units are monitored by CEMS (either following CAMR, State, or NIST QA/QC procedures), and where data are available, EPA requests that this CEMS data be submitted by the respondent. The respondent should also mark the periods of start up, shut down and malfunction events (SSM) in the data sets.

## 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 5/12/2005See Attachment 1 N/A N/A N/A N/A N/A N/A 2 Report 2 5/11/2005See Attachment 2 N/A N/A N/A N/A N/A N/A 3 Report 3 4/15/2005See Attachment 3 N/A N/A N/A N/A N/A N/A 4 Report 4 3/29/2005See Attachment 4 N/A N/A N/A N/A N/A N/A 5 Report 5 6/23/2005See Attachment 5 N/A N/A N/A N/A N/A N/A 1 Report 6 6/1/2006See Attachment 6 N/A N/A N/A N/A N/A N/A 2 Report 7 6/9/2006See Attachment 7 N/A N/A N/A N/A N/A N/A 3 Report 8 4/26/2006See Attachment 8 N/A N/A N/A N/A N/A N/A 4 Report 9 2/9/2006See Attachment 9 N/A N/A N/A N/A N/A N/A 5 Report 10 5/16/2006See Attachment 10 N/A N/A N/A N/A N/A N/A 1 Report 11 5/8/2007See Attachment 11 N/A N/A N/A N/A N/A N/A 2 Report 12 8/23/2007See Attachment 12 N/A N/A N/A N/A N/A N/A 3 Report 13 2/13/2007See Attachment 13 N/A N/A N/A N/A N/A N/A 4 Report 14 4/18/2007See Attachment 14 N/A N/A N/A N/A N/A N/A 5 Report 15 5/10/2007See Attachment 15 N/A N/A N/A N/A N/A N/A 1 Report 16 4/17/2007See Attachment 16 N/A N/A N/A N/A N/A N/A 2 Report 17 7/9/2008See Attachment 17 N/A N/A N/A N/A N/A N/A 3 Report 18 5/28/2008See Attachment 18 N/A N/A N/A N/A N/A N/A 4 Report 19 5/29/2008See Attachment 19 N/A N/A N/A N/A N/A N/A 5 Report 20 5/1/2008See Attachment 20 N/A N/A N/A N/A N/A N/A 1 Report 21 7/29-7/30/2009See Attachment 21 N/A N/A N/A N/A N/A N/A 2 Report 22 3/25/2009See Attachment 22 N/A N/A N/A N/A N/A N/A 3 Report 23 6/2/2009See Attachment 23 N/A N/A N/A N/A N/A N/A 4 Report 24 7/8/2009See Attachment 24 N/A N/A N/A N/A N/A N/A 5 Report 25 4/16/2009See Attachment 25 N/A N/A N/A N/A N/A N/A 1 Report 26 6/2/2006See Attachment 26 N/A N/A N/A N/A N/A N/A 4 Report 27 2/10/2006See Attachment 27 N/A N/A N/A N/A N/A N/A 5 Report 28 5/17/2006See Attachment 28 N/A N/A N/A N/A N/A N/A 1 Report 31 8/13-8/20/2008 N/A N/A N/A N/A N/A See Attachment 29 N/A 2 Report 32 7/9-7/29/2008 N/A N/A N/A N/A N/A See Attachment 30 N/A 3 Report 33 2/2-2/9/2005 N/A N/A N/A N/A N/A See Attachment 31 N/A 4 Report 34 9/11-9/18/2009 N/A N/A N/A N/A N/A See Attachment 32 N/A
Note: "N/A" means not applicable.

47

### Provide emission test data for all tests conducted since January 1, 2005. Please indicate test data acquired both before and after any control device. Use additional pages as necessary. EPA may, at some future date, request a copy of one or more emission test reports. Data generated to fulfill both Federal and State requirements must be provided. Note that data generated pursuant to CAA Title V must be maintained and available for 5 years. Also include averaging times and measurement units for all pollutants.
48

### For each emissions test run the respondent should provide the following process information: Unit Load (MW), Net generation during run (MWh net), Flue gas moisture content (%), Flue gas flow rate (dscfm or Nm3

### /hr), Flue gas oxygen content (%, dry), Flue gas carbon dioxide content (%, dry), Flue gas temperature at sampling point (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 - Gaston Report 1 Test Results

Title of Run RUN 1 RUN 2 RUN 3a RUN 3b Date Month/Day/Year 5/12/20055/12/20055/12/20055/12/2005 Sampling Time -Start Military 0744 0744 1020 1020 Sampling Time -Stop Military 0952 0950 1120 1120 Number of Ports dimensionless 12 12 6 6 Number of Points per Port dimensionless 5 5 5 5 Heat Input Million Btu per Hour 2503 2403 2524 2524 Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00 Barometric Pressure Inches Mercury 30.30 30.30 30.30 30.30 Meter Correction Factor dimensionless 1.011 1.051 1.051 1.011 Oxygen Concentration Mole Percent O2 6.0 6.0 5.5 6.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 11.0 13.0 13.0 Volume of Gas Metered Actual Cubic Feet 75.995 79.655 37.153 36.425 Volume of Water Collected Milliliters 141.0 122.0 63.0 68.0 Sampling Time Minutes 120 120 60 60 Nozzle Diameter Inches 0.272 0.272 0.272 0.272 Weight of Solids Collected Milligrams 52.0 54.6 30.5 22.2 Area of Stack Square Feet 432.0000432.0000216.0000216.0000 Avg. Sqr. Root Velocity Pressure Inches Water 0.5965 0.6007 0.5654 0.5804 Average Orifice Pressure(DH) Inches Water 1.4 1.8 1.7 1.3 Average Stack Temperature Degrees F 258 259 264 268 Average Meter Temperature Degrees F 73 76 84 82 Average Generation MW 270 270 271 271

RUN 1 RUN 2 RUN 3a RUN 3bAverage
Volume of Gas Sampled Standard Dry 77.350 83.847 38.549 36.487 78.744 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.20 29.23 29.42 29.34 39.07
Water vapor in Stack Gas Percent 7.9 6.4 7.1 8.1 9.8
Average Stack Gas Velocity Feet per second 39.1 39.4 37.1 38.3 38.8

Stack Gas Flow Rate Actual Cubic 1,014,5481,022,514481,166495,7671,004,665 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 733,852 737,729 344,892 353,680723,384 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 675,862 690,442 320,256 325,156670,572 Feet Per Minute Particulate Concentration Grains per Standard 0.0104 0.0100 0.0122 0.0094 0.0104 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0069 0.0068 0.0081 0.0061 0.0069 Cubic Foot Particulate Emission Rate Pounds per Hour 60.0 59.3 33.4 26.1 49.7

Particulate Emission Rate Pounds per Million 0.0240 0.0247 0.0133 0.0103 0.0241 Allowable Particulate Emission RateBtu (Heat Input) 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 102.1 108.3 107.4 100.1 104.7



## TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY E.C. GASTON STEAM PLANT, UNIT 1

5/12/2005

Calculations

# ATTACHMENT 2 - Gaston Report 2 Test Results

Side A Side A Side A Side B Side B Side B Unit

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Average Date Month/Day/Year 5/11/20055/11/20055/11/2005 5/11/20055/11/20055/11/2005 Sampling Time -Start Military 0810 1034 1300 0810 1034 1300 Sampling Time -Stop Military 1018 1250 1510 1018 1242 1508 Number of Ports dimensionless 16 16 16 16 16 16 Number of Points per Port dimensionless 4 4 4 4 4 4 Heat Input Million Btu per Hour 2,811 2,718 2,711 2,811 2,718 2,711 Stack Static Pressure Inches Water -22.00 -22.00 -22.00 -22.00 -22.00 -22.00 Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10 30.10 30.10 Meter Correction Factor dimensionless 1.051 1.051 1.051 1.011 1.011 1.011 Oxygen Concentration Mole Percent O2 4.0 3.6 4.0 7.8 7.3 7.5 Carbon Dioxide Concentration Mole Percent CO2 11.3 12.0 12.0 11.5 12.3 12.0 Volume of Gas Metered Actual Cubic Feet 77.854 81.175 84.369 81.700 81.910 81.830 Volume of Water Collected Milliliters 91 142 126 104 126 133 Sampling Time Minutes 128.00 128.00 128.00 128.00 128.00 128.00 Nozzle Diameter Inches 0.215 0.205 0.216 0.215 0.215 0.215 Weight of Solids Collected Milligrams 4.9 15.2 14.2 8.5 11.0 13.7 Area of Stack Square Feet 135.298 135.298 135.298 135.298 135.298 135.298 Avg. Sqr. Root Velocity PressureInches Water 0.8889 0.9219 0.9210 0.9728 0.9690 0.9643 Average Orifice Pressure(DH) Inches Water 1.4 1.4 1.6 1.4 1.4 1.4 Average Stack Temperature Degrees F 282 286 291 247 254 254 269 Average Meter Temperature Degrees F 82 90 96 77 84 89 Average Generation MW 270 268 269 270 268 269

Side A Side A Side ASide A Side B Side B Side BSide BUnit RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3AverageAverage
Volume of Gas Sampled Standard Dry 80.483 82.621 85.11282.738 82.047 81.173 80.34481.188 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.36 29.16 29.2929.27 29.47 29.42 29.3429.41
Water vapor in Stack Gas Percent 5.1 7.5 6.5 6.4 5.6 6.8 7.2 6.6
Average Stack Gas Velocity Feet per second 60.1 62.8 62.7 61.9 64.1 64.2 64.0 64.1

Stack Gas Flow Rate Actual Cubic 488,008 509,398 509,363502,256 520,545 521,189 519,699520,4781,022,734 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 330,593 342,930 340,723338,082 369,769 367,095 365,565367,477705,558 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 313,887 317,264 318,527316,559 348,949 342,100 339,140343,396659,956 Feet Per Minute Particulate Concentration Grains per Standard 0.0009 0.0028 0.00260.0021 0.0016 0.0021 0.00260.00210.0021 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0006 0.0018 0.00160.0013 0.0011 0.0014 0.00170.00140.0014 Cubic Foot Particulate Emission Rate Pounds per Hour 2.5 7.7 7.0 5.7 4.8 6.1 7.6 6.211.9

Particulate Emission Rate Pounds per Million 0.001 0.003 0.0030.0021 0.002 0.002 0.0030.00230.004 Isokinetic Corrected Btu (Heat Input) 0.001 0.003 0.0030.0024 0.002 0.002 0.0030.00230.005

Isokinetic Rate Percent 107.5 120.1 111.0 98.6 99.5 99.3 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY E.C. GASTON STEAM PLANT, UNIT 2

5/11/2005

Calculations

# ATTACHMENT 3 - Gaston Report 3 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 4/14/20054/14/20054/14/2005 4/14/20054/14/20054/14/2005 Sampling Time -Start Military 0723 0945 1204 0723 0945 1204 Sampling Time -Stop Military 0931 1153 1412 0929 1151 1410 Heat Input Million Btu per Hour 2610 2604 2596 2610 2604 2596 Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -18.00 -18.00 -18.00 Barometric Pressure Inches Mercury 29.95 29.95 29.95 29.95 29.95 29.95 Meter Correction Factor dimensionless 1.051 1.051 1.051 0.999 0.999 0.999 Oxygen Concentration Mole Percent O2 7.0 7.0 7.3 5.8 5.8 5.8 Carbon Dioxide Concentration Mole Percent CO2 11.8 11.5 11.3 11.5 12.3 12.0 Volume of Gas Metered Actual Cubic Feet 67.524 70.000 70.805 81.010 80.239 83.039 Volume of Water Collected Milliliters 94.00 100.0 108.0 124.00 121.0 139.0 Sampling Time Minutes 128 128 128 128 128 128 Nozzle Diameter Inches 0.215 0.215 0.215 0.210 0.210 0.210 Weight of Solids Collected Milligrams 5.5 12.0 2.4 4.5 3.5 2.7 Area of Stack Square Feet 134.24 134.24 134.24 134.24 134.24 134.24 Avg. Sqr. Root Velocity Pressure Inches Water 0.8048 0.8216 0.8310 0.9732 0.9660 0.9852 Average Orifice Pressure(DH) Inches Water 1.1 1.1 1.1 1.5 1.5 1.5 Average Stack Temperature Degrees F 254 257 260 229 234 240 Average Meter Temperature Degrees F 61 63 70 59 62 68 Average Generation MW 271 271 271 271 271 271

Side A Side A Side A3 Runs Side B Side B Side B3 Runs RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 72.146 74.517 74.36573.676 82.739 81.514 83.43182.561 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.457 29.400 29.31629.391 29.275 29.394 29.26629.312
Water vapor in Stack Gas Percent 5.8 5.9 6.4 6.0 6.6 6.5 7.3 6.8
Average Stack Gas Velocity Feet per second 53.18 54.46 55.2654.30 63.37 62.99 64.6663.68

Stack Gas Flow Rate Actual Cubic 428,339 438,603 445,119437,354 510,447 507,383 520,778512,869 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 302,885 308,879 312,209307,991 373,974 369,168 375,758372,967 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 285,383 290,527 292,232289,381 349,331 345,058 348,433347,608 Feet Per Minute Particulate Concentration Grains per Standard 0.00117 0.00248 0.000500.00138 0.00084 0.00066 0.000500.00067 Dry Cubic Foot Particulate Concentration Grains per Actual 0.00078 0.00164 0.000330.00092 0.00057 0.00045 0.000330.00045 Cubic Foot Particulate Emission Rate Pounds per Hour 2.87 6.18 1.24 3.43 2.51 1.96 1.49 1.98

Particulate Emission Rate Pounds per Million 0.00110 0.00237 0.000480.00132 0.00096 0.00075 0.000570.00076 Btu (Heat Input) Combined Particulate Emission RatePounds per Million 0.002060.00312 0.001050.00208 Allowable Particulate Emission Rate Btu (Heat Input) 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 105.1 106.7 105.8105.9 103.2 103.0 104.4103.5 

## TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY UNIT 3 E.C. GASTON STEAM PLANT

4/14/2005

Calculations

# ATTACHMENT 4 - Gaston Report 4 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Date Month/Day/Year 3/29/20053/29/20053/29/2005 Sampling Time -Start Military 0710 0930 1140 Sampling Time -Stop Military 0910 1130 1340 Number of Ports dimensionless 12 12 12 Number of Points per Port dimensionless 5 5 5 Heat Input Million Btu per Hour 2,505 2,450 2,473 Stack Static Pressure Inches Water -8.50 -8.50 -8.50 Barometric Pressure Inches Mercury 29.60 29.60 29.60 Meter Correction Factor dimensionless 1.0510 1.0510 1.0510 Oxygen Concentration Mole Percent O2 5.5 5.5 6.0 Carbon Dioxide Concentration Mole Percent CO2 13.0 13.5 13.0 Volume of Gas Metered Actual Cubic Feet 66.585 80.300 85.458 Volume of Water Collected Milliliters 149 134 147 Sampling Time Minutes 120.00 120.00 120.00 Nozzle Diameter Inches 0.266 0.288 0.293 Weight of Solids Collected Milligrams 37.5 34.6 14.2 Area of Stack Square Feet 432.000432.000432.000 Avg. Sqr. Root Velocity PressureInches Water 0.5855 0.5863 0.5917 Average Orifice Pressure(DH) Inches Water 1.303 1.8 1.9 Average Stack Temperature Degrees F 233.45 240.6 240.2 Average Meter Temperature Degrees F 54.72 68.1 74.9 Average Generation MW 271 271 271

RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 71.266 83.860 88.14981.092 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.20 29.51 29.4229.38
Water vapor in Stack Gas Percent 9.0 7.0 7.3 7.7
Average Stack Gas Velocity Feet per second 38.1 38.1 38.5 38.2

Stack Gas Flow Rate Actual Cubic 986,503 987,477 997,956990,645 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 727,301 720,586 728,614725,500 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 662,139 670,180 675,584669,301 Feet Per Minute Particulate Concentration Grains per Standard 0.0081 0.0064 0.00250.0056 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0054 0.0043 0.00170.0038 Cubic Foot Particulate Emission Rate Pounds per Hour 46.0 36.5 14.4 32.3

Particulate Emission Rate Pounds per Million 0.018 0.015 0.0060.013 Btu (Heat Input) Isokinetic Rate Percent 100.4 99.6 100.3100.1



## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 4

Calculations

## ATTACHMENT 5 - Gaston Report 5 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/23/20056/23/20056/23/2005 Sampling Time -Start Military 0808 0936 1054 Sampling Time -Stop Military 0928 1050 1207 Number of Ports dimensionless 10 10 10 Number of Points per Port dimensionless 3 3 3 Heat Input Million Btu per Hour 8,540 8,495 8,048 Stack Static Pressure Inches Water -1.50 -1.50 -1.50 Barometric Pressure Inches Mercury 30.20 30.20 30.20 Meter Correction Factor dimensionless 1.051 1.051 1.051 Oxygen Concentration Mole Percent O2 6.0 4.5 5.0 Carbon Dioxide Concentration Mole Percent CO2 15.0 15.0 14.0 Volume of Gas Metered Actual Cubic Feet 44.280 43.230 43.220 Volume of Water Collected Milliliters 65.00 81.00 100.00 Sampling Time Minutes 60 60 60 Nozzle Diameter Inches 0.245 0.248 0.249 Weight of Solids Collected Milligrams 16.2 17.0 19.4 Area of Stack Square Feet 812.500812.500812.500 Avg. Sqr. Root Velocity Pressure Inches Water 0.9000 0.8676 0.8668 Average Orifice Pressure(DH) Inches Water 2.2 2.0 2.0 Average Stack Temperature Degrees F 286 287 291 Average Meter Temperature Degrees F 76 85 89 Average Generation MW 879 878 876

3 Runs RUN 1 RUN 2 RUN 3Average

Volume of Gas Sampled Standard Dry 46.496 44.620 44.308 45.141 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.86 29.59 29.25 29.56

Water vapor in Stack Gas Percent 6.2 7.9 9.6 7.9

Average Stack Gas Velocity Feet per second 58.9 57.1 57.5 57.8

Stack Gas Flow Rate Actual Cubic 2,870,9322,781,1902,802,2632,818,128 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 2,042,2131,977,1391,981,6772,000,343 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 1,916,1281,821,4971,791,3721,842,999 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 143,518 136,430 134,174138,041 Per Minute Particulate Concentration Grains per Standard 0.0054 0.0059 0.0067 0.0060 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0036 0.0038 0.0043 0.0039 Cubic Foot Particulate Emission Rate Pounds per Hour 88.1 91.6 103.5 94.4

Particulate Emission Rate Pounds per Million 0.010 0.011 0.013 0.011 Btu (Heat Input) Allowable Particulate Emission RatePounds per Million 0.12 0.12 0.12 0.12 Btu (Heat Input) Isokinetic Rate Percent 100.3 98.9 99.0 99.4



### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 5

Calculations

## ATTACHMENT 6 - Gaston Report 6 Test Results

A Side A Side A Side B Side B Side B Side

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/1/20066/1/20066/1/2006 6/1/20066/1/20066/1/2006 Sampling Time -Start Military 1050 1203 1315 1050 1203 1315 Sampling Time -Stop Military 1150 1303 1415 1150 1303 1415 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Heat Input Million Btu per Hour 2,572 2,571 2,571 2,572 2,571 2,571 Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00 -12.00 -12.00 Barometric Pressure Inches Mercury 29.98 29.98 29.98 29.98 29.98 29.98 Standard Orifice PressureDH@ Inches Water 2.008 2.008 2.008 2.378 2.378 2.378 Meter Correction Factor dimensionless 0.967 0.967 0.967 0.938 0.938 0.938 Oxygen Concentration Mole Percent O2 8.0 8.0 7.0 6.5 6.0 7.0 Carbon Dioxide Concentration Mole Percent CO2 11.5 11.0 12.0 11.5 11.5 11.0 Volume of Gas Metered Actual Cubic Feet 38.71442.49042.455 43.49942.59342.200 Volume of Water Collected Milliliters 66 72 71 65 64 62 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.275 0.275 0.275 0.275 0.275 0.275 Weight of Solids Collected Milligrams 90.5 76.1 86.3 65.5 61.2 48.6 Area of Stack Square Feet 216.000216.000216.000 216.000216.000216.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.61210.61110.6110 0.61630.60670.5977 Average Orifice Pressure(DH) Inches Water 1.4433 1.7423 1.7420 2.13002.0713 2.0020 Average Stack Temperature Degrees F 265 267 269 271 271 272 Average Meter Temperature Degrees F 83 86 87 81 82 83 Average Generation MW 269 269 269 269 269 269

A Side A Side A SideA Side B Side B Side B SideB Side RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 36.58540.01839.89038.83140.10139.183 38.76039.348 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.16 30.08 30.2030.147 30.10 30.08 30.0430.073
Water vapor in Stack Gas Percent 7.8 7.8 7.7 7.8 7.1 7.1 7.0 7.1
Average Stack Gas Velocity Feet per second 40.5 40.5 40.540.487 40.9 40.3 39.740.313

Stack Gas Flow Rate Actual Cubic 524,600525,030524,502524,711530,313522,218514,831522,454 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 371,336370,805369,483370,541372,248366,683361,265366,732 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 342,272341,854340,921341,682345,860340,504335,969340,778 Feet Per Minute Particulate Concentration Grains per Standard 0.03810.02930.03330.0340.02520.02410.01930.023 Dry Cubic Foot Particulate Concentration Grains per Actual 0.02490.01910.02170.0220.01640.01570.01260.015 Cubic Foot Particulate Emission Rate Pounds per Hour 111.8 85.8 97.498.310 74.6 70.2 55.666.793

Particulate Emission Rate Pounds per Million 0.043 0.033 0.0380.038 0.029 0.027 0.0220.026 Btu (Heat Input) Isokinetic Rate Percent 93.3 102.1 102.199.174 101.2 100.4 100.7100.753

Post Test Meter Correction Factor dimensionless 0.98 0.98 0.980.981 0.97 0.98 0.970.973

Percent Difference Allowed 5% 1.10 1.50 1.49 1.36 3.19 4.01 3.40 3.53

Combined Particulate Emission RatePounds per Million 0.072 0.061 0.0590.064 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 1

Calculations

## ATTACHMENT 7 - Gaston Report 7 Test Results

A Side A Side A Side B Side B Side B Side

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/9/20066/9/20066/9/2006 6/9/20066/9/20066/9/2006 Sampling Time -Start Military 0744 0950 1154 0744 0950 1154 Sampling Time -Stop Military 0936 1142 1346 0936 1142 1346 Number of Ports dimensionless 16 16 16 16 16 16 Number of Points per Port dimensionless 4 4 4 4 4 4 Heat Input Million Btu per Hour 2,769 2,833 2,659 2,769 2,833 2,659 Stack Static Pressure Inches Water -22.00 -22.00 -22.00 -22.00 -22.00 -22.00 Barometric Pressure Inches Mercury 29.92 29.92 29.92 29.92 29.92 29.92 Standard Orifice PressureDH@ Inches Water 2.008 2.008 2.008 2.378 2.378 2.378 Meter Correction Factor dimensionless 0.967 0.967 0.967 0.938 0.938 0.938 Oxygen Concentration Mole Percent O2 8.5 7.0 7.0 7.5 7.0 5.5 Carbon Dioxide Concentration Mole Percent CO2 10.5 11.5 11.5 11.5 10.5 11.0 Volume of Gas Metered Actual Cubic Feet 71.483 73.08773.458 73.91074.45076.500 Volume of Water Collected Milliliters 133 119 114 120 111 118 Sampling Time Minutes 112 112 112 112 112 112 Nozzle Diameter Inches 0.215 0.215 0.215 0.215 0.215 0.215 Weight of Solids Collected Milligrams 14.0 15.6 20.7 11.0 18.1 22.0 Area of Stack Square Feet 135.298135.298135.298 135.298135.298135.298 Avg. Sqr. Root Velocity Pressure Inches Water 0.89660.91260.9148 0.92500.94160.9706 Average Orifice Pressure(DH) Inches Water 1.3371 1.3857 1.3911 1.6568 1.6961 1.7758 Average Stack Temperature Degrees F 281 286 289 273 275 281 Average Meter Temperature Degrees F 76 81 85 87 92 96 Average Generation MW 269 269 269 269 269 269

A Side A Side A SideA Side B Side B Side B SideB Side RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 68.36769.19469.05468.872 67.14667.14468.47267.587 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.02 30.12 30.1230.09 30.14 29.96 29.9830.03
Water vapor in Stack Gas Percent 8.4 7.5 7.2 7.7 7.8 7.2 7.5 7.5
Average Stack Gas Velocity Feet per second 61.0 62.1 62.3 61.8 62.4 63.7 65.9 64.0

Stack Gas Flow Rate Actual Cubic 495,081503,884506,039501,668506,244517,182535,298519,575 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 333,493337,253337,177335,974344,953351,438360,888352,426 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 305,517311,996312,865310,126318,187326,065333,810326,021 Feet Per Minute Particulate Concentration Grains per Standard 0.00320.00350.00460.00370.00250.00420.00490.0039 Dry Cubic Foot Particulate Concentration Grains per Actual 0.00190.00210.00290.00230.00160.00260.00310.0024 Cubic Foot Particulate Emission Rate Pounds per Hour 8.3 9.3 12.4 10.0 6.9 11.6 14.2 10.9

Particulate Emission Rate Pounds per Million 0.003 0.003 0.0050.004 0.002 0.004 0.0050.004 Btu (Heat Input) Isokinetic Rate Percent 107.2 106.2 105.7106.4 101.1 98.6 98.3 99.3

Post Test Meter Correction Factor dimensionless 0.95 0.95 0.95 0.95 0.95 0.96 0.96 0.95

Percent Difference Allowed 5% -1.88 -1.97 -1.93 -1.93 0.80 1.85 1.78 1.48

Combined Particulate Emission RatePounds per Million 0.005 0.007 0.0100.008 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 2

Calculations

## ATTACHMENT 8 - Gaston Report 8 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 4/26/20064/26/20064/26/2006 4/26/20064/26/20064/26/2006 Sampling Time -Start Military 0750 1015 1234 0750 1015 1234 Sampling Time -Stop Military 0958 1223 1442 0958 1233 1442 Number of Ports dimensionless 16 16 16 16 16 16 Number of Points per Port dimensionless 4 4 4 4 4 4 Heat Input Million Btu per Hour 2,575 2,618 2,616 2,575 2,618 2,616 Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -20.00 -20.00 -20.00 Barometric Pressure Inches Mercury 29.97 29.97 29.97 29.97 29.97 29.97 Standard Orifice PressureDH@ Inches Water 1.960 1.960 1.960 2.311 2.311 2.311 Meter Correction Factor dimensionless 1.011 1.011 1.011 0.978 0.978 0.978 Oxygen Concentration Mole Percent O2 7.5 7 7.25 7.25 7.5 7 Carbon Dioxide Concentration Mole Percent CO2 12.25 12 12 11.75 11.25 11.5 Volume of Gas Metered Actual Cubic Feet 75.900 78.200 76.050 79.008 77.372 76.975 Volume of Water Collected Milliliters 126 135 124 117 127 122 Sampling Time Minutes 128 128 128 128 128 128 Nozzle Diameter Inches 0.215 0.216 0.210 0.215 0.215 0.215 Weight of Solids Collected Milligrams 16.40 15.80 17.90 20.50 14.20 18.20 Area of Stack Square Feet 134.24 134.24 134.24 134.24 134.24 134.24 Avg. Sqr. Root Velocity Pressure Inches Water 0.9437 0.9246 0.9386 0.9122 0.8901 0.8986 Average Orifice Pressure(DH) Inches Water 1.3 1.4 1.3 1.6 1.5 1.5 Average Stack Temperature Degrees F 261 264 265 254 250 250 Average Meter Temperature Degrees F 76 75 74 74 73 72 Average Generation MW 271 271 271 271 271 271

Side A Side A Side ASide A Side B Side B Side BSide B RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 76.019 78.448 76.44176.969 76.895 75.405 75.13775.812 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.37 29.29 29.3429.33 29.36 29.21 29.2629.28
Water vapor in Stack Gas Percent 7.2 7.5 7.1 7.3 6.7 7.3 7.1 7.0
Average Stack Gas Velocity Feet per second 62.7 61.7 62.6 62.3 60.5 59.0 59.5 59.7

Stack Gas Flow Rate Actual Cubic 505,247 496,759 503,998502,002 487,469 475,218 479,477480,721 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 354,077 346,739 351,473350,763 343,085 336,702 339,592339,793 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 328,452 320,757 326,540325,250 320,155 311,970 315,480315,868 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 24,601 24,025 24,45824,361 23,980 23,367 23,62923,659 Per Minute Particulate Concentration Grains per Standard 0.0033 0.0031 0.00360.0033 0.0041 0.0029 0.00370.0036 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0022 0.0020 0.00230.0022 0.0027 0.0019 0.00250.0024 Cubic Foot Particulate Emission Rate Pounds per Hour 9.4 8.5 10.1 9.3 11.3 7.8 10.1 9.7

Particulate Emission Rate Pounds per Million 0.0036 0.0033 0.00390.0036 0.0044 0.0030 0.00390.0037 Btu (Heat Input) Combined Particulate Emission RatePounds per Million 0.0080 0.0062 0.00770.0073 Allowable 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 96.3 100.8 102.0 99.7 99.9 100.5 99.1 99.8

Post Test Meter Correction Factor dimensionless 1.04 1.03 1.01 1.03 1.00 1.00 1.01 1.00

Percent Difference Allowed 5% 2.84 1.70 0.01 1.52 2.45 2.11 3.15 2.57 

### Calculations TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 3

## ATTACHMENT 9 - Gaston Report 9 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 2/9/20062/9/20062/9/2006 2/9/20062/9/20062/9/2006 Sampling Time -Start Military 0756 0917 1041 0756 0917 1041 Sampling Time -Stop Military 0856 1017 1141 0856 1017 1141 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Heat Input Million Btu per Hour 2,663 2,656 2,658 2,663 2,656 2,658 Stack Static Pressure Inches Water -9.00 -9.00 -9.00 -9.00 -9.00 -9.00 Barometric Pressure Inches Mercury 30.20 30.20 30.20 30.20 30.20 30.20 Standard Orifice PressureDH@ Inches Water 2.03 2.03 2.03 2.35 2.35 2.35 Meter Correction Factor dimensionless 1.004 1.004 1.004 0.988 0.988 0.988 Oxygen Concentration Mole Percent O2 7.0 7.5 7.0 7.5 7.5 7.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 11.5 12.0 12.0 11.5 11.5 Volume of Gas Metered Actual Cubic Feet 41.00038.40037.950 35.612 34.50835.085 Volume of Water Collected Milliliters 61.00 52.00 55.00 55.00 57.00 53.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.280 0.275 0.275 0.275 0.275 0.275 Weight of Solids Collected Milligrams 14.1 25.1 15.3 15.9 19.7 38.7 Area of Stack Square Feet 216.000216.000216.000 216.000216.000216.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.57650.56550.5955 0.53590.54300.5599 Average Orifice Pressure(DH) Inches Water 1.6 1.4 1.6 1.6 1.6 1.7 Average Stack Temperature Degrees F 228 231 233 229 235 232 Average Meter Temperature Degrees F 46 47 49 44 44 48 Average Generation MW 270 270 269 270 270 269

Side A Side A Side ASide A Side B Side B Side BSide BCombined RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3AverageAverage
Volume of Gas Sampled Standard Dry 43.52640.66740.05741.41737.333 36.17136.55436.686 39.128 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.45 29.45 29.4629.45 29.43 29.30 29.3629.36 29.410
Water vapor in Stack Gas Percent 6.2 5.7 6.1 6.0 6.5 6.9 6.4 6.6 6.276
Average Stack Gas Velocity Feet per second 36.8 36.2 38.2 37.0 34.3 34.9 35.9 35.0 36.072

Stack Gas Flow Rate Actual Cubic 476,955468,803494,497480,085443,967452,840465,353454,053934,138 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 361,452353,850371,843362,382335,769339,424350,501341,898704,280 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 339,084333,762349,270340,705313,995315,986328,109319,363660,069 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 25,39724,999 26,16025,519 23,51823,66724,57523,920 49,439 Per Minute Particulate Concentration Grains per Standard 0.00500.00950.00590.00680.00660.00840.01630.0104 0.0085 Dry Cubic Foot Particulate Concentration Grains per Actual 0.00350.00680.00420.00480.00460.00590.01150.0073 0.0060 Cubic Foot Particulate Emission Rate Pounds per Hour 14.5 27.2 17.6 19.8 17.7 22.7 45.9 28.7 48.5

Particulate Emission Rate Pounds per Million 0.005 0.010 0.0070.007 0.007 0.009 0.0170.011 0.018 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 108.0 106.3 100.1104.8 103.8 99.9 97.2100.3

Post Test Meter Correction Factordimensionless 0.96 0.95 1.01 0.97 1.00 1.04 1.05 1.03
Difference (Allowed 5%) Percent -4.81 -5.28 0.78 -3.10 1.32 4.75 -1.06 1.67 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 4

Calculations

## ATTACHMENT 10 - Gaston Report 10 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/16/20065/16/20065/16/2006 Sampling Time -Start Military 0736 0852 1010 Sampling Time -Stop Military 0842 0956 1115 Number of Ports dimensionless 10 10 10 Number of Points per Port dimensionless 3 3 3 Heat Input Million Btu per Hour 8,310 8,353 8,324 Stack Static Pressure Inches Water -21.50 -21.00 -21.00 Barometric Pressure Inches Mercury 29.95 29.95 29.95 Standard Orifice PressureDH@ Inches Water 1.96 1.96 1.96 Meter Correction Factor dimensionless 1.011 1.011 1.011 Oxygen Concentration Mole Percent O2 5.5 4.0 6.5 Carbon Dioxide Concentration Mole Percent CO2 13.5 13.5 14.5 Volume of Gas Metered Actual Cubic Feet 47.025 42.305 47.600 Volume of Water Collected Milliliters 74.00 65.00 88.00 Sampling Time Minutes 60 60 60 Nozzle Diameter Inches 0.245 0.228 0.245 Weight of Solids Collected Milligrams 20.1 20.6 26.8 Area of Stack Square Feet 812.500 812.500 812.500 Avg. Sqr. Root Velocity Pressure Inches Water 0.9563 0.9945 0.9675 Average Orifice Pressure(DH) Inches Water 2.38 1.92 2.41 Average Stack Temperature Degrees F 269 270 274 Average Meter Temperature Degrees F 54 64 65 Average Generation MW 886 885 884

RUN 1 RUN 2 RUN 3AVERAGE
Volume of Gas Sampled Standard Dry 49.184 43.392 48.711 47.095 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.38 30.32 30.58 30.43
Water vapor in Stack Gas Percent 6.6 6.6 7.8 7.0
Average Stack Gas Velocity Feet per second 64.0 66.6 64.9 65.2

Stack Gas Flow Rate Actual Cubic 3,119,9243,248,8193,163,9103,177,551 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 2,143,2772,229,8172,160,6862,177,927 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 2,001,5292,082,9491,991,3502,025,276 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 149,915 156,013 149,152151,693 Per Minute Particulate Concentration Grains per Standard 0.0063 0.0073 0.0085 0.0074 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0040 0.0047 0.0053 0.0047 Cubic Foot Particulate Emission Rate Pounds per Hour 108.0 130.5 144.6 127.7

Particulate Emission Rate Pounds per Million 0.013 0.016 0.017 0.015 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 101.6 99.5 101.2 100.8

Post Test Meter Correction Factordimensionless 1.01 1.02 1.02 1.02

Percent Difference Allowed 5% 0.23 1.09 0.40 0.57



### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 5

Calculations

## ATTACHMENT 11 - Gaston Report 11 Test Results

Side A Side A Side A Side B Side B Side B Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/8/20075/8/20075/8/2007 5/8/20075/8/20075/8/2007 Sampling Time -Start Military 0806 0924 1042 0806 0924 1042 Sampling Time -Stop Military 0906 1024 1144 0906 1024 1142 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Heat Input Million Btu per Hour 2,523 2,456 2,471 2,523 2,456 2,471 Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.50 -12.50 -12.50 Barometric Pressure Inches Mercury 30.15 30.15 30.15 30.15 30.15 30.15 Standard Orifice PressureDH@ Inches Water 2.258 2.258 2.258 1.896 1.896 1.896 Meter Correction Factor dimensionless 0.982 0.982 0.982 0.986 0.986 0.986 Oxygen Concentration Mole Percent O2 6.5 6.5 6.5 6.5 6.5 6.5 Carbon Dioxide Concentration Mole Percent CO2 10.0 10.0 10.0 10.0 10.0 10.0 Volume of Gas Metered Actual Cubic Feet 38.800 38.280 38.182 47.690 53.060 56.390 Volume of Water Collected Milliliters 62 60 55 42 77 77 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.276 0.275 0.275 0.273 0.275 0.275 Weight of Solids Collected Milligrams 33.4 52.0 45.0 46.6 49.0 61.0 Area of Stack Square Feet 216.000216.000216.000 216.000216.000216.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.59740.6083 0.6012 0.73880.8069 0.8292 Average Orifice Pressure(DH) Inches Water 1.8 1.8 1.8 2.3 2.9 3.0 Average Stack Temperature Degrees F 272 277 279 268 271 277 Average Meter Temperature Degrees F 58 64 67 68 90 101 Average Generation MW 270 270 270 270 270 270

Side ASide BWeighted Side A Side A Side ASide A Side B Side B Side BSide BCombined3 Runs3 Runs3 Runs 6 Runs RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3AverageAverageAVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 39.343 38.373 38.00738.575 47.661 50.950 53.16450.591 44.58338.57538.57550.591 45.430 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.86 29.86 29.8629.86 29.86 29.86 29.8629.86 29.86 29.86 29.86 29.86 29.860
Water vapor in Stack Gas Percent 6.9 6.9 6.4 6.7 4.0 6.6 6.4 5.7 6.2 6.7 6.7 5.7 6.117
Average Stack Gas Velocity Feet per second 39.8 40.7 40.2 40.2 48.8 53.7 55.4 52.7 46.4 40.2 40.2 52.7 47.317

Stack Gas Flow Rate Actual Cubic 515,946526,994520,976521,305632,704696,409718,179682,4311,203,736521,305521,305682,4311,203,736 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 363,881369,251364,128365,753448,403491,254502,531480,729846,483365,753365,753480,729846,483 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 338,753343,938340,907341,199430,544458,629470,458453,210794,410341,199341,199453,210794,410 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 25,373 25,761 25,53425,556 32,248 34,351 35,23733,945 59,50125,55625,55633,945 59,501 Per Minute Particulate Concentration Grains per Standard 0.013 0.021 0.0180.017 0.015 0.015 0.0180.016 0.017 0.017 0.017 0.016 0.017 Dry Cubic Foot Particulate Concentration Grains per Actual 0.009 0.014 0.0120.011 0.010 0.010 0.0120.011 0.011 0.011 0.011 0.011 0.011 Cubic Foot Particulate Emission Rate Pounds per Hour 38.0 61.5 53.3 50.9 55.6 58.2 71.3 61.7 112.6 50.9 50.9 61.7 112.6

Particulate Emission Rate Pounds per Million 0.015 0.025 0.0220.021 0.022 0.024 0.0290.025 0.045 0.021 0.021 0.025 0.045 Btu (Heat Input) Isokinetic Rate Percent 100.6 97.4 97.3 98.4 98.0 96.9 98.6 97.9 98.1 98.4 98.4 97.9

Post Test Meter Correction Factor dimensionless 0.99 1.03 1.02 1.01 1.01 1.05 1.02 1.03 1.02 1.01 1.01 1.03

Percent Difference Allowed 5% 1.0 4.6 4.0 3.2 2.7 6.0 3.1 3.9 3.6 3.2 3.2 3.9

Combined Particulate Emission RatePounds per Million 0.037 0.049 0.0500.045 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 1

Calculations

## ATTACHMENT 12 - Gaston Report 12 Test Results

Side A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 8/23/20078/23/20078/23/20078/23/20078/23/20078/23/2007 Sampling Time -Start Military 1026 1204 1332 1026 1204 1332 Sampling Time -Stop Military 1130 1308 1436 1130 1308 1436 Number of Ports dimensionless 8 8 8 8 8 8 Number of Points per Port dimensionless 4 4 4 4 4 4 Heat Input Million Btu per Hour 2,542 2,523 2,527 2,542 2,523 2,527 Stack Static Pressure Inches Water -22.00 -22.00 -22.00 -22.00 -22.00 -22.00 Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10 30.10 30.10 Standard Orifice PressureDH@ Inches Water 1.939 1.939 1.939 2.418 2.418 2.418 Meter Correction Factor dimensionless 0.981 0.981 0.981 0.939 0.939 0.939 Oxygen Concentration Mole Percent O2 8.5 9.0 9.0 8.5 8.5 8.5 Carbon Dioxide Concentration Mole Percent CO2 11.0 11.0 11.0 12.5 12.5 12.5 Volume of Gas Metered Actual Cubic Feet 57.945 48.220 44.860 45.381 43.849 44.800 Volume of Water Collected Milliliters 81 69 55 82 73 77 Sampling Time Minutes 64 64 64 64 64 64 Nozzle Diameter Inches 0.262 0.236 0.225 0.215 0.213 0.213 Weight of Solids Collected Milligrams 9.2 8.8 11.6 16.1 16.4 13.5 Area of Stack Square Feet 135.298 135.298 135.298 135.298 135.298 135.298 Avg. Sqr. Root Velocity Pressure Inches Water 0.9161 0.8952 0.9081 1.0006 0.9774 0.9951 Average Orifice Pressure(DH) Inches Water 2.9 1.9 1.6 2.1 2.0 2.0 Average Stack Temperature Degrees F 287 290 290 263 274 276 Average Meter Temperature Degrees F 99 110 106 94 97 99 Average Generation MW 265 265 265 265 265 265

Side A Side A Side A Side B Side B Side BSide ASide B RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 54.389 44.265 41.492 41.109 39.487 40.21046.71540.268 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.10 30.12 30.12 30.34 30.34 30.34 30.11 30.34
Water vapor in Stack Gas Percent 6.6 6.8 5.9 8.6 8.0 8.3 6.4 8.3
Average Stack Gas Velocity Feet per second 62.2 60.9 61.7 66.9 65.8 67.1 61.6 66.6

Stack Gas Flow Rate Actual Cubic 505,230 494,756 500,892 543,112 533,782 544,545500,293540,480 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 339,718 331,414 335,525 377,296 365,413 371,721335,552371,477 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 317,464 308,760 315,819 344,912 336,161 340,985314,014340,686 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 23,778 23,126 23,655 25,834 25,178 25,54023,52025,517 Per Minute Particulate Concentration Grains per Standard 0.003 0.003 0.004 0.006 0.006 0.005 0.003 0.006 Dry Cubic Foot Particulate Concentration Grains per Actual 0.002 0.002 0.003 0.004 0.004 0.003 0.002 0.004 Cubic Foot Particulate Emission Rate Pounds per Hour 7.1 8.1 11.7 17.8 18.4 15.1 8.9 17.1

Particulate Emission Rate Pounds per Million 0.003 0.003 0.005 0.007 0.007 0.006 0.004 0.007 Btu (Heat Input) Isokinetic Rate Percent 96.7 99.7 100.6 99.9 100.3 100.7 99.0 100.3
Post Test Meter Correction Check (Yqa) dimensionless 1.02 0.99 0.98 0.98 0.98 0.98 1.00 0.98

Percent Difference Allowed 5% Average 3.5 1.3 0.2 4.5 4.3 4.0 1.7 4.3

Combined Particulate Emission Rate Pounds per Million 0.010 0.011 0.011 0.010 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 2

Calculations

## ATTACHMENT 13 - Gaston Report 13 Test Results

Side A Side A Side A Side B Side B Side B Title of Run RUN 1 RUN 2 RUN 3 RUN 5 RUN 6 RUN 7 Date Month/Day/Year 2/13/20072/13/20072/13/2007 2/13/20072/13/20072/13/2007 Sampling Time -Start Military 0720 1004 1230 0720 1004 1230 Sampling Time -Stop Military 0928 1212 1438 0928 1212 1438 Number of Ports dimensionless 16 16 16 16 16 16 Number of Points per Port dimensionless 4 4 4 4 4 4 Heat Input Million Btu per Hour 2,539 2,567 2,530 2,539 2,567 2,530 Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -20.00 -20.00 -20.00 Barometric Pressure Inches Mercury 29.80 29.80 29.80 29.80 29.80 29.80 Standard Orifice PressureDH@ Inches Water 1.939 1.939 1.939 2.418 2.418 2.418 Meter Correction Factor dimensionless 0.981 0.981 0.981 0.939 0.939 0.939 Oxygen Concentration Mole Percent O2 8.0 6.0 6.5 8.0 7.0 7.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.5 13.0 12.0 12.5 12.0 Volume of Gas Metered Actual Cubic Feet 76.671 74.804 79.309 76.749 80.209 76.082 Volume of Water Collected Milliliters 98 114 121 76 130 112 Sampling Time Minutes 128 128 128 128 128 128 Nozzle Diameter Inches 0.215 0.212 0.215 0.218 0.218 0.213 Weight of Solids Collected Milligrams 35.8 61.6 53.5 32.9 51.4 43.1 Area of Stack Square Feet 134.24 134.24 134.24 134.24 134.24 134.24 Avg. Sqr. Root Velocity Pressure Inches Water 0.8969 0.8941 0.9132 0.8133 0.8541 0.8380 Average Orifice Pressure(DH) Inches Water 1.2 1.2 1.3 1.4 1.5 1.3 Average Stack Temperature Degrees F 263 263 304 257 261 261 Average Meter Temperature Degrees F 63 61 66 70 69 73 Average Generation MW 269 269 269 269 269 269

Side A Side A Side A Side A Side B Side B Side B Side B RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 75.903 74.294 78.04676.081 71.800 75.184 70.71272.566 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.24 30.24 30.3430.273 30.24 30.28 30.2230.247
Water vapor in Stack Gas Percent 5.7 6.7 6.8 6.4 4.7 7.5 6.9 6.4
Average Stack Gas Velocity Feet per second 59.7 59.6 62.5 60.6 54.0 57.1 56.0 55.7

Stack Gas Flow Rate Actual Cubic 480,831 480,418 503,619488,289 434,548 459,812 451,221448,527 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 334,127 333,746 331,161333,011 302,808 318,829 312,608311,415 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 314,985 311,265 308,637311,629 288,437 294,833 290,919291,396 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 23,592 23,314 23,11723,341 21,604 22,083 21,79021,826 Per Minute Particulate Concentration Grains per Standard 0.007 0.013 0.0110.010 0.007 0.011 0.0090.009 Dry Cubic Foot Particulate Concentration Grains per Actual 0.005 0.008 0.0060.007 0.005 0.007 0.0060.006 Cubic Foot Particulate Emission Rate Pounds per Hour 19.6 34.1 27.927.201 17.4 26.6 23.422.486

Particulate Emission Rate Pounds per Million 0.008 0.013 0.0110.011 0.007 0.010 0.0090.009 Btu (Heat Input) Combined Particulate Emission RatePounds per Million 0.015 0.024 0.0200.020 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 100.2 102.1 105.2102.494 100.7 103.2 103.0102.282

Post Test Meter Correction Factor dimensionless 0.98 0.97 0.96 0.97 0.93 0.93 0.92 0.93

Percent Difference Allowed 5% -0.3 -1.1 -1.6 -1.0 -1.2 -0.4 -1.9 -1.2 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 3

Calculations

## ATTACHMENT 14 - Gaston Report 14 Test Results

SIDE A SIDE A SIDE A SIDE B SIDE B SIDE B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 4/18/20074/18/20074/18/20074/18/20074/18/20074/18/2007 Sampling Time -Start Military 0722 0843 0957 0722 0840 0957 Sampling Time -Stop Military 0822 0943 1057 0822 0940 1057 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Heat Input Million Btu per Hour 2,550 2,566 2,576 2,550 2,566 2,576 Stack Static Pressure Inches Water -9.00 -9.00 -9.00 -9.00 -9.00 -9.00 Barometric Pressure Inches Mercury 30.05 30.05 30.05 30.05 30.05 30.05 Standard Orifice PressureDH@ Inches Water 2.418 2.418 2.418 1.939 1.939 1.939 Meter Correction Factor dimensionless 0.939 0.939 0.939 0.981 0.981 0.981 Oxygen Concentration Mole Percent O2 9 10 7 6 7 7 Carbon Dioxide Concentration Mole Percent CO2 10 9 12 10 11 11 Volume of Gas Metered Actual Cubic Feet 45.262 45.455 43.270 40.195 40.485 40.810 Volume of Water Collected Milliliters 54 71 58 43 45 43 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.277 0.278 0.272 0.277 0.277 0.277 Weight of Solids Collected Milligrams 62.9 33.2 123.3 59.3 43.4 39.6 Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.6293 0.6240 0.6093 0.5873 0.5879 0.6005 Average Orifice Pressure(DH) Inches Water 2.2 2.2 2.0 1.6 1.6 1.7 Average Stack Temperature Degrees F 254 255 256 255 258 261 Average Meter Temperature Degrees F 67 72 72 59 62 61 Average Generation MW 271 271 271 271 271 271

Side A Side A Side A Side B Side B Side BSide ASide B RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AverageAverage
Volume of Gas Sampled Standard Dry 42.994 42.783 40.708 40.462 40.526 40.91142.16240.633 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.96 29.84 30.20 29.84 30.04 30.0430.0029.97
Water vapor in Stack Gas Percent 5.6 7.2 6.3 4.8 5.0 4.7 6.4 4.8
Average Stack Gas Velocity Feet per second 41.2 41.1 39.8 38.4 38.4 39.3 40.7 38.7

Stack Gas Flow Rate Actual Cubic 533,336 532,094 515,663 498,208 498,254 509,645527,031502,036 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 387,255 385,668 373,672 361,209 359,866 366,747382,198362,607 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 365,639 357,725 350,187 344,001 341,991 349,458357,850345,150 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 27,386 26,794 26,229 25,766 25,615 26,17426,80325,852 Per Minute Particulate Concentration Grains per Standard 0.023 0.012 0.047 0.023 0.016 0.0150.0270.018 Dry Cubic Foot Particulate Concentration Grains per Actual 0.015 0.008 0.032 0.016 0.011 0.0100.0180.012 Cubic Foot Particulate Emission Rate Pounds per Hour 70.6 36.6 140.0 66.5 48.3 44.7 82.4 53.2

Particulate Emission Rate Pounds per Million 0.028 0.014 0.054 0.026 0.019 0.0170.0320.021 Btu (Heat Input) Combined Particulate Emission RatePounds per Million 0.054 0.033 0.072 0.053 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 101.1 102.1 103.7 101.2 101.9 100.7 102.3 101.3

Post Test Meter Correction Factor dimensionless 0.94 0.94 0.92 0.99 0.98 0.99 0.93 0.99

Percent Difference Allowed 5% -0.3 0.0 -1.7 0.8 -0.2 1.2 -0.7 0.6 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 4

Calculations

## ATTACHMENT 15 - Gaston Report 15 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/10/20075/10/20075/10/2007 Sampling Time -Start Military 0726 1456 1618 Sampling Time -Stop Military 1416 1608 1730 Number of Ports dimensionless 10 10 10 Number of Points per Port dimensionless 3 3 3 Heat Input Million Btu per Hour 7,970 7,970 7,970 Stack Static Pressure Inches Water -21.50 -21.50 -21.50 Barometric Pressure Inches Mercury 29.90 29.90 29.90 Standard Orifice PressureDH@ Inches Water 1.896 1.896 1.896 Meter Correction Factor dimensionless 0.986 0.986 0.986 Oxygen Concentration Mole Percent O2 6.5 6 5.5 Carbon Dioxide Concentration Mole Percent CO2 13 12.5 13.5 Volume of Gas Metered Actual Cubic Feet 48.445 44.633 38.052 Volume of Water Collected Milliliters 77 82 64 Sampling Time Minutes 60 60 60 Nozzle Diameter Inches 0.239 0.230 0.210 Weight of Solids Collected Milligrams 39.4 79.5 47.3 Area of Stack Square Feet 812.500 812.500 812.500 Avg. Sqr. Root Velocity Pressure Inches Water 1.0282 1.0482 1.0370 Average Orifice Pressure(DH) Inches Water 2.5 2.3 1.5 Average Stack Temperature Degrees F 307 324 323 Average Meter Temperature Degrees F 93 115 114 Average Generation MW 886 886 886

RUN 1 RUN 2 RUN 3Average

Volume of Gas Sampled Standard Dry 45.880 40.645 34.654 40.393 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.34 30.24 30.38 30.32

Water vapor in Stack Gas Percent 7.3 8.7 8.0 8.0

Average Stack Gas Velocity Feet per second 70.8 73.3 72.2 72.1

Stack Gas Flow Rate Actual Cubic 3,452,6173,574,0533,519,8273,515,499 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 2,248,4762,277,1812,247,0262,257,561 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 2,083,8592,079,6872,067,3132,076,953 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 156,081 155,769 154,842155,564 Per Minute Particulate Concentration Grains per Standard 0.013 0.030 0.021 0.021 Dry Cubic Foot Particulate Concentration Grains per Actual 0.008 0.018 0.012 0.013 Cubic Foot Particulate Emission Rate Pounds per Hour 236.2 537.0 372.5 381.9

Particulate Emission Rate Pounds per Million 0.030 0.067 0.047 0.048 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 95.7 91.7 94.4 93.9



### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 5

Calculations

### ATTACHMENT 16 - Gaston Report 16 Test Results

Title of Run RUN 1 RUN 2 RUN 3A RUN 3B Date Month/Day/Year 4/17/20084/17/20084/17/20084/17/2008 Sampling Time -Start Military 0915 0915 1144 1144 Sampling Time -Stop Military 1115 1115 1244 1244 Number of Ports dimensionless 12 12 12 12 Number of Points per Port dimensionless 5 5 5 5 Heat Input Million Btu per Hour 2,854 2,854 2,861 2,861 Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00 Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10 Standard Orifice Pressure DH@ Inches Water 2.206 2.258 2.206 2.258 Meter Correction Factor dimensionless 0.970 0.982 0.970 0.982 Oxygen Concentration Mole Percent O2 7.0 6.0 6.5 8.50 Carbon Dioxide Concentration Mole Percent CO2 12.3 12.5 12.5 13.00 Volume of Gas Metered Actual Cubic Feet 76.445 77.230 36.625 38.125 Volume of Water Collected Milliliters 95.6 101.0 25.6 51.0 Sampling Time Minutes 120 120 60 60 Nozzle Diameter Inches 0.275 0.276 0.275 0.274 Weight of Solids Collected Milligrams 64.9 72.3 52.2 32.6 Area of Stack Square Feet 432.000 432.000 216.000 216.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.5843 0.5804 0.5701 0.6256 Average Orifice Pressure (DH) Inches Water 1.6 1.7 1.5 1.9 Average Stack Temperature Degrees F 249 252 251 263 Average Meter Temperature Degrees F 63 58 69 66 Average Generation MW 271 271 271 271

RUN 1 RUN 2 RUN 3A RUN 3BAVERAGE

Volume of Gas Sampled Standard Dry 75.567 78.076 35.804 37.991 75.8 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.24 30.24 30.26 30.42 30.27

Water vapor in Stack Gas Percent 5.6 5.7 3.3 5.9 5.3

Average Stack Gas Velocity Feet per second 38.0 37.9 36.9 41.0 38.3

Stack Gas Flow Rate Actual Cubic 985,289 981,340 478,818 531,576992,341 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 716,552 710,105 347,289 378,958717,635 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 676,281 669,348 335,982 356,436679,349 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 50,653 50,134 25,165 26,69750,883 Per Minute Particulate Concentration Grains per Standard 0.013 0.014 0.022 0.013 0.015 Dry Cubic Foot Particulate Concentration Grains per Actual 0.009 0.010 0.016 0.009 0.010 Cubic Foot Particulate Emission Rate Pounds per Hour 76.7 81.8 64.7 40.4 87.8

Particulate Emission Rate Pounds per Million 0.027 0.029 0.023 0.014 0.031 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 97.5 101.0 93.0 93.7 97.3

Post Test Meter Correction Check dimensionless 0.97 0.97 1.00 1.04 0.99

Percent Difference Allowed 5% Average -0.1 -1.2 2.6 5.9 1.0 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GASTON STEAM PLANT UNIT 1

Calculations

## ATTACHMENT 17 - Gaston Report 17 Test Results

SIDE A SIDE A SIDE A SIDE B SIDE B SIDE B Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 7/9/20087/9/20087/9/20087/9/20087/9/20087/9/2008 Sampling Time -Start Military 0800 0938 1106 0800 0938 1106 Sampling Time -Stop Military 0904 1042 1210 0904 1042 1210 Number of Ports dimensionless 8 8 8 8 8 8 Number of Points per Port dimensionless 4 4 4 4 4 4 Heat Input Million Btu per Hour 2,775 2,778 2,738 2,775 2,778 2,738 Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -21.00 -21.00 -21.00 Barometric Pressure Inches Mercury 29.97 29.97 29.97 29.97 29.97 29.97 Standard Orifice Pressure DH@ Inches Water 2.211 2.211 2.211 1.939 1.939 1.939 Meter Correction Factor dimensionless 0.927 0.927 0.927 0.981 0.981 0.981 Oxygen Concentration Mole Percent O2 9.0 7.5 8.5 7.5 7.5 8.0 Carbon Dioxide Concentration Mole Percent CO2 11.0 9.0 10.0 10.5 10.5 11.0 Volume of Gas Metered Actual Cubic Feet 46.44245.49544.69241.40546.05546.460 Volume of Water Collected Milliliters 67.0 62.0 66.0 64.8 78.4 80.1 Sampling Time Minutes 64 64 64 64 64 64 Nozzle Diameter Inches 0.220 0.218 0.215 0.215 0.218 0.218 Weight of Solids Collected Milligrams 157.7 91.9 109.6 21.4 49.7 21.0 Area of Stack Square Feet 135.298135.298135.298135.298135.298135.298 Avg. Sqr. Root Velocity Pressure Inches Water 0.94780.95410.94990.8943 1.0134 1.0176 Average Orifice Pressure (DH) Inches Water 1.8 1.8 1.7 1.3 1.7 1.7 Average Stack Temperature Degrees F 281 284 288 264 268 271 Average Meter Temperature Degrees F 82 85 87 85 90 92 Average Generation MW 270 270 270 270 270 270 Combined Flowrate Weighted Side ASide BTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 42.23641.09940.20439.51843.67343.83341.17942.341 83.521 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.12 29.74 29.94 29.98 29.98 30.08 29.93 30.01 29.97
Water vapor in Stack Gas Percent 6.9 6.6 7.2 7.2 7.8 7.9 6.9 7.6 7.3
Average Stack Gas Velocity Feet per second 64.0 64.9 64.6 60.0 68.3 68.7 64.5 65.7 65.1

Stack Gas Flow Rate Actual Cubic 519,401526,640524,654487,332554,725557,470523,565533,1751,056,741 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 354,059357,681354,382337,729382,007382,289355,374367,342722,716 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 329,459333,967328,963313,529352,243352,011330,796339,261670,057 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 24,67625,01424,639 23,483 26,383 26,36624,77725,411 50,187 Per Minute Particulate Concentration Grains per Standard 0.058 0.034 0.042 0.008 0.018 0.007 0.045 0.011 0.028 Dry Cubic Foot Particulate Concentration Grains per Actual 0.036 0.022 0.026 0.005 0.011 0.005 0.028 0.007 0.017 Cubic Foot Particulate Emission Rate Pounds per Hour 162.4 98.6 118.4 22.4 52.9 22.3 126.4 32.5 159.0

Particulate Emission Rate Pounds per Million 0.059 0.035 0.043 0.008 0.019 0.008 0.046 0.012 0.057 Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 102.6 100.3 102.5 105.7 101.1 101.5 101.8 102.8

Post Test Meter Correction Checkdimensionless 0.92 0.95 0.93 0.93 0.97 0.97 0.93 0.96

Percent Difference Allowed 5% Average -0.9 1.8 0.4 -4.7 -1.0 -1.6 0.4 -2.4 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 2

Calculations

## ATTACHMENT 18 - Gaston Report 18 Test Results

Side A Side A Side A Side B Side B Side B Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/28/20085/28/20085/28/20085/28/20085/28/20085/28/2008 Sampling Time -Start Military 0829 0958 1122 0829 0958 1122 Sampling Time -Stop Military 0933 1102 1226 0933 1102 1226 Number of Ports dimensionless 8 8 8 8 8 8 Number of Points per Port dimensionless 4 4 4 4 4 4 Heat Input Million Btu per Hour 2,623 2,681 2,559 2,623 2,681 2,559 Stack Static Pressure Inches Water -19.0 -19.0 -19.0 -18.0 -18.0 -18.0 Barometric Pressure Inches Mercury 30.05 30.05 30.05 30.05 30.05 30.05 Standard Orifice Pressure DH@ Inches Water 1.939 1.939 1.939 2.211 2.211 2.211 Meter Correction Factor dimensionless 0.981 0.981 0.981 0.927 0.927 0.927 Oxygen Concentration Mole Percent O2 8.5 7.5 6.5 8.0 9.0 5.5 Carbon Dioxide Concentration Mole Percent CO2 12.5 12.0 12.5 13.0 12.5 12.5 Volume of Gas Metered Actual Cubic Feet 41.788 41.575 42.078 42.592 42.640 52.026 Volume of Water Collected Milliliters 66.1 69.8 78.1 55.0 74.0 88.0 Sampling Time Minutes 64 64 64 64 64 64 Nozzle Diameter Inches 0.221 0.218 0.216 0.221 0.217 0.220 Weight of Solids Collected Milligrams 7.3 15.7 17.1 8.9 10.0 17.1 Area of Stack Square Feet 134.240 134.240 134.240 134.240 134.240 134.240 Avg. Sqr. Root Velocity Pressure Inches Water 0.896 0.916 0.943 0.877 0.926 1.085 Average Orifice Pressure(DH) Inches Water 1.37 1.39 1.42 1.51 1.58 2.28 Average Stack Temperature Degrees F 262 264 270 270 271 271 Average Meter Temperature Degrees F 78 82 84 76 79 81 Average Generation MW 270 268 270 270 268 270 Sides A & B Combined Side A Side A Side A Side B Side B Side BSide ASide BTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 40.586 40.053 40.387 39.229 39.070 47.56940.34241.956 82.298 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.34 30.22 30.26 30.40 30.36 30.22 30.27 30.33 30.30
Water vapor in Stack Gas Percent 7.1 7.6 8.3 6.2 8.2 8.0 7.7 7.5 7.6
Average Stack Gas Velocity Feet per second 59.5 61.1 63.2 58.3 61.9 72.7 61.2 64.3 62.8

Stack Gas Flow Rate Actual Cubic 479,040 491,966 508,862 469,274 498,374 585,155493,289517,6011,010,890 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 335,271 343,352 352,376 325,992 345,688 405,986343,666359,222 702,888 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 311,399 317,323 322,977 305,810 317,392 373,466317,233332,223 649,456 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 23,324 23,767 24,191 22,905 23,773 27,97323,76124,883 48,644 Per Minute Particulate Concentration Grains per Standard 0.0028 0.0060 0.0065 0.0035 0.0039 0.00550.00510.0043 0.0047 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0018 0.0039 0.0041 0.0023 0.0025 0.00350.00330.0028 0.0030 Cubic Foot Particulate Emission Rate Pounds per Hour 7.4 16.4 18.1 9.2 10.7 17.7 14.0 12.5 26.5

Particulate Emission Rate Pounds per Million 0.0028 0.0061 0.0071 0.0035 0.0040 0.00690.00530.0048 0.0101 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 102.6 102.1 103.1 101.0 100.5 101.2 102.6 100.9

Post Test Meter Correction Checkdimensionless 0.949 0.968 0.968 0.913 0.935 0.924 0.962 0.924

Percent Difference Allowed 5% Average -3.2 -1.3 -1.3 -1.4 0.8 -0.3 -1.9 -0.3 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 3

Calculations

## ATTACHMENT 19 - Gaston Report 19 Test Results

Side A Side A Side A Side B Side B Side B Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/29/20085/29/20085/29/20085/29/20085/29/20085/29/2008 Sampling Time -Start Military 0734 0850 1024 0734 0850 1024 Sampling Time -Stop Military 0834 0950 1124 0834 0950 1124 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Heat Input Million Btu per Hour 2,579 2,585 2,583 2,579 2,585 2,583 Stack Static Pressure Inches Water -9.00 -9.00 -9.00 -9.00 -9.00 -9.00 Barometric Pressure Inches Mercury 29.80 29.80 29.80 29.80 29.80 29.80 Standard Orifice Pressure DH@ Inches Water 2.211 2.211 2.211 1.939 1.939 1.939 Meter Correction Factor dimensionless 0.927 0.927 0.927 0.981 0.981 0.981 Oxygen Concentration Mole Percent O2 6.0 5.5 6.0 6.0 5.0 5.0 Carbon Dioxide Concentration Mole Percent CO2 12.0 14.0 13.0 13.5 14.0 14.0 Volume of Gas Metered Actual Cubic Feet 40.695 43.485 41.385 39.660 39.531 38.816 Volume of Water Collected Milliliters 72.0 72.0 75.0 66.9 71.2 79.4 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.272 0.275 0.272 0.276 0.274 0.275 Weight of Solids Collected Milligrams 64.1 66.5 69.5 26.3 54.0 61.4 Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.596 0.618 0.600 0.569 0.577 0.582 Average Orifice Pressure(DH) Inches Water 1.64 1.83 1.67 1.44 1.40 1.37 Average Stack Temperature Degrees F 269 268 270 276 277 279 Average Meter Temperature Degrees F 70 75 78 74 79 81 Average Generation MW 271 271 271 271 271 271 Sides A & B Combined Side ASide BTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 37.593 39.796 37.643 38.457 37.985 37.13838.34437.860 76.204 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.16 30.46 30.32 30.40 30.44 30.44 30.31 30.43 30.37
Water vapor in Stack Gas Percent 8.3 7.8 8.6 7.6 8.1 9.1 8.2 8.3 8.3
Average Stack Gas Velocity Feet per second 39.6 40.8 39.8 37.8 38.4 38.9 40.1 38.4 39.2

Stack Gas Flow Rate Actual Cubic 513,473 529,400 516,172 490,226 498,041 503,837519,682497,3681,017,050 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 362,351 373,744 363,523 342,248 347,264 350,402366,539346,638 713,177 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 332,386 344,414 332,354 316,345 319,109 318,364336,385317,939 654,324 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 24,896 25,797 24,893 23,694 23,901 23,84525,19523,814 49,009 Per Minute Particulate Concentration Grains per Standard 0.0263 0.0257 0.0284 0.0105 0.0219 0.02550.02680.0193 0.0232 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0170 0.0167 0.0183 0.0068 0.0140 0.01610.01730.0123 0.0149 Cubic Foot Particulate Emission Rate Pounds per Hour 74.8 76.0 81.0 28.6 59.9 69.5 77.3 52.6 129.9

Particulate Emission Rate Pounds per Million 0.0290 0.0294 0.0314 0.0111 0.0232 0.02690.02990.0204 0.0503 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 100.9 100.8 101.0 105.3 104.6 101.8 100.9 103.9

Post Test Meter Correction Checkdimensionless 0.935 0.925 0.932 0.962 0.956 0.964 0.931 0.961

Percent Difference Allowed 5% Average 0.8 -0.2 0.5 -1.9 -2.5 -1.7 0.4 -2.0 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 4

Calculations

### ATTACHMENT 20 - Gaston Report 20 Test Results

Title of Run RUN 2 RUN 3 RUN 4 Date Month/Day/Year 5/1/20085/1/20085/1/2008 Sampling Time -Start Military 1002 1122 1245 Sampling Time -Stop Military 1110 1231 1354 Number of Ports dimensionless 10 10 10 Number of Points per Port dimensionless 3 3 3 Heat Input Million Btu per Hour 8,146 8,199 8,367 Stack Static Pressure Inches Water -22.00 -22.00 -22.00 Barometric Pressure Inches Mercury 30.00 30.00 30.00 Standard Orifice Pressure DH@ Inches Water 2.139 2.139 2.139 Meter Correction Factor dimensionless 0.988 0.988 0.988 Oxygen Concentration Mole Percent O2 6.0 6.0 5.5 Carbon Dioxide Concentration Mole Percent CO2 13.0 13.0 13.0 Volume of Gas Metered Actual Cubic Feet 37.142 40.035 36.155 Volume of Water Collected Milliliters 68.0 75.0 64.0 Sampling Time Minutes 60 60 60 Nozzle Diameter Inches 0.219 0.219 0.219 Weight of Solids Collected Milligrams 19.7 5.8 29.1 Area of Stack Square Feet 812.500812.500812.500 Avg. Sqr. Root Velocity Pressure Inches Water 0.9253 0.9718 0.9531 Average Orifice Pressure (DH) Inches Water 1.5 1.6 1.4 Average Stack Temperature Degrees F 302 295 300 Average Meter Temperature Degrees F 69 75 78 Average Generation MW 896 890 878

AVERAGE RUN 2 RUN 3 RUN 4Runs 2, 3, and 4

Volume of Gas Sampled Standard Dry 36.855 39.337 35.265 37.152 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.32 30.32 30.30 30.31

Water vapor in Stack Gas Percent 8.0 8.2 7.9 8.0

Average Stack Gas Velocity Feet per second 63.5 66.5 65.4 65.1

Stack Gas Flow Rate Actual Cubic 3,097,3683,239,9773,187,549 3,174,964 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 2,036,5882,150,0332,100,022 2,095,548 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 1,873,8481,972,9721,934,750 1,927,190 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 140,351147,776144,913 144,347 Per Minute Particulate Concentration Grains per Standard 0.008 0.002 0.013 0.008 Dry Cubic Foot Particulate Concentration Grains per Actual 0.005 0.001 0.008 0.005 Cubic Foot Particulate Emission Rate Pounds per Hour 132.2 38.4 210.7 127.1

Particulate Emission Rate Pounds per Million 0.016 0.005 0.025 0.015 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 101.8 103.2 94.3 99.8

Post Test Meter Correction Check dimensionless 1.00 0.96 1.01 0.99

Percent Difference Allowed 5% Average 1.2 -2.9 2.0 0.1



### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 5

Calculations

## ATTACHMENT 21 - Gaston Report 21 Test Results

Side A Side A Side A Side B Side B Side B Title of Run RUN 1 RUN 2 RUN 4 RUN 1 RUN 2 RUN 4 Date Month/Day/Year 7/29/20097/29/20097/30/20097/29/20097/29/20097/30/2009 Sampling Time -Start Military 0716 0836 1710 0001 0836 1710 Sampling Time -Stop Military 0816 0936 1810 0816 0936 1810 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Heat Input Million Btu per Hour 2,533 2,480 2,557 2,533 2,480 2,557 Stack Static Pressure Inches Water -10.00 -10.00 -11.00 -10.00 -10.00 -12.00 Barometric Pressure Inches Mercury 29.88 29.80 29.82 29.80 29.80 29.82 Standard Orifice Pressure DH@ Inches Water 1.907 1.907 1.907 2.080 2.080 2.040 Meter Correction Factor dimensionless 0.98 0.98 0.98 1.051 1.051 0.975 Oxygen Concentration Mole Percent O2 7.5 5.5 10.0 8.0 8.5 10.0 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.5 9.0 12.0 11.0 9.0 Volume of Gas Metered Actual Cubic Feet 41.690 40.116 40.150 37.605 37.353 39.880 Volume of Water Collected Milliliters 84.7 55.4 67.1 61.5 69.3 69.8 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.273 0.277 0.278 0.276 0.277 0.277 Weight of Solids Collected Milligrams 105.7 96.5 74.6 88.0 117.4 118.7 Area of Stack Square Feet 216.000 216.000 216.000 216.000 216.000 216.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.6228 0.5955 0.5754 0.5943 0.5999 0.5798 Average Orifice Pressure (DH) Inches Water 1.7 1.5 1.5 1.7 1.7 1.7 Average Stack Temperature Degrees F 266 269 267 268 272 271 Average Meter Temperature Degrees F 77 79 80 74 76 81 Average Generation MW 270 264 263 270 264 263

Weighted Side A Side BTOTAL or RUN 1 RUN 2 RUN 4 RUN 1 RUN 2 RUN 4AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 40.218 38.488 38.457 39.086 38.704 37.972 39.054 38.588 77.642 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.22 30.22 29.84 30.24 30.10 29.84 30.09 30.06 30.08
Water vapor in Stack Gas Percent 9.0 6.3 7.6 6.9 7.8 8.0 7.7 7.5 7.6
Average Stack Gas Velocity Feet per second 41.4 39.5 38.4 39.4 40.0 38.9 39.8 39.4 39.6

Stack Gas Flow Rate Actual Cubic 536,583 511,519 498,163 510,315 518,613 504,317515,422511,0821,026,503 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 379,179 359,699 350,784 359,609 363,490 352,407363,220358,502721,722 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 344,980 336,874 324,161 334,812 335,237 324,344335,339331,464 66,803 Feet Per Minute Particulate Concentration Grains per Standard 0.040 0.039 0.030 0.035 0.047 0.048 0.036 0.043 0.040 Dry Cubic Foot Particulate Concentration Grains per Actual 0.026 0.025 0.019 0.023 0.030 0.031 0.024 0.028 0.026 Cubic Foot Particulate Emission Rate Pounds per Hour 119.7 111.5 83.0 99.5 134.2 133.8 104.7 122.5 227.2

Particulate Emission Rate Pounds per Million 0.047 0.045 0.032 0.039 0.054 0.052 0.042 0.049 0.090 Allowable Btu (Heat Input) 0.120 Isokinetic Rate Percent 103.2 98.3 101.3 101.1 99.3 100.7 100.9 100.4

Post Test Meter Correction Checkdimensionless 1.00 0.99 0.98 1.08 1.09 1.01 0.99 1.06

Percent Difference Allowed 5% Average 2.2 1.2 -0.1 3.0 3.6 3.8 1.1 3.5 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GASTON STEAM PLANT UNIT 1

Calculations

## ATTACHMENT 22 - Gaston Report 22 Test Results

Title of Run RUN 1A RUN 2A RUN 3A RUN 1B RUN 2B RUN 3B Date Month/Day/Year 3/25/20093/25/20093/25/20093/25/20093/25/20093/25/2009 Sampling Time -Start Military 0756 0915 1038 0756 0915 1038 Sampling Time -Stop Military 0900 1019 1142 0900 1019 1142 Number of Ports dimensionless 8 8 8 8 8 8 Number of Points per Port dimensionless 4 4 4 4 4 4 Heat Input Million Btu per Hour 2,634 2,632 2,603 2,634 2,632 2,603 Stack Static Pressure Inches Water -18.00 -18.00 -18.00 -18.00 -18.00 -18.00 Barometric Pressure Inches Mercury 30.03 30.03 30.03 30.03 30.03 30.03 Standard Orifice Pressure DH@ Inches Water 2.088 2.088 2.088 1.858 1.858 1.858 Meter Correction Factor dimensionless 0.999 0.999 0.999 0.978 0.978 0.978 Oxygen Concentration Mole Percent O2 7.5 6.5 6.0 6.5 7.5 6.0 Carbon Dioxide Concentration Mole Percent CO2 13.0 13.0 12.0 12.0 11.5 10.5 Volume of Gas Metered Actual Cubic Feet 36.870 36.045 36.610 39.077 37.118 38.502 Volume of Water Collected Milliliters 52.0 51.0 44.0 43.2 57.2 47.0 Sampling Time Minutes 64 64 64 64 64 64 Nozzle Diameter Inches 0.223 0.221 0.224 0.223 0.220 0.219 Weight of Solids Collected Milligrams 20.3 49.2 84.1 5.7 5.5 11.1 Area of Stack Square Feet 135.298 135.298 135.298 135.298 135.298 135.298 Avg. Sqr. Root Velocity Pressure Inches Water 0.8195 0.8129 0.8060 0.8700 0.8318 0.8600 Average Orifice Pressure (DH) Inches Water 1.3 1.2 1.3 1.3 1.2 1.2 Average Stack Temperature Degrees F 270 269 270 260 258 257 Average Meter Temperature Degrees F 70 72 73 70 70 71 Average Generation MW 257 258 257 257 258 257 Flowrate Weighted Side ASide BTOTAL or RUN 1A RUN 2A RUN 3A RUN 1B RUN 2B RUN 3BAVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 36.949 36.004 36.517 38.358 36.382 37.70236.49037.480 73.970 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.38 30.34 30.16 30.18 30.14 29.92 30.29 30.08 30.19
Water vapor in Stack Gas Percent 6.2 6.3 5.4 5.0 6.9 5.5 5.9 5.8 5.9
Average Stack Gas Velocity Feet per second 54.5 54.1 53.7 57.5 55.2 57.1 54.1 56.6 55.4

Stack Gas Flow Rate Actual Cubic 442,561 439,112 436,028 467,171 447,958 463,205439,234459,445898,678 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 307,142 305,062 302,647 328,428 315,922 327,073304,950323,808628,758 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 288,060 285,993 286,403 311,894 294,154 308,945286,819304,997591,816 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 21,576 21,421 21,452 23,361 22,032 23,14021,48322,844 44,327 Per Minute Particulate Concentration Grains per Standard 0.008 0.021 0.035 0.002 0.002 0.005 0.022 0.003 0.012 Dry Cubic Foot Particulate Concentration Grains per Actual 0.006 0.014 0.023 0.002 0.002 0.003 0.014 0.002 0.008 Cubic Foot Particulate Emission Rate Pounds per Hour 20.9 51.6 87.1 6.1 5.9 12.0 53.2 8.0 61.2

Particulate Emission Rate Pounds per Million 0.008 0.020 0.033 0.002 0.002 0.005 0.020 0.003 0.023 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 100.0 99.9 98.5 95.8 99.0 98.6 99.4 97.8

Post Test Meter Correction Checkdimensionless 1.01 1.01 1.01 1.02 1.02 1.00 1.01 1.01

Percent Difference Allowed 5% Average 0.8 0.8 1.5 4.0 4.1 2.2 1.0 3.4 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 2

Calculations

## ATTACHMENT 23 - Gaston Report 23 Test Results

Side A Side A Side A Side B Side B Side B Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/2/20096/2/20096/2/20096/2/20096/2/20096/2/2009 Sampling Time -Start Military 0834 0958 1120 0834 0958 1120 Sampling Time -Stop Military 0938 1102 1224 0938 1102 1224 Number of Ports dimensionless 8 8 8 8 8 8 Number of Points per Port dimensionless 4 4 4 4 4 4 Heat Input Million Btu per Hour 2,902 2,846 2,956 2,902 2,846 2,956 Stack Static Pressure Inches Water -17.00 -17.00 -17.00 -17.00 -17.00 -17.00 Barometric Pressure Inches Mercury 30.05 30.05 30.05 30.05 30.05 30.05 Standard Orifice Pressure DH@ Inches Water 1.858 1.858 1.858 2.088 2.088 2.088 Meter Correction Factor dimensionless 0.978 0.978 0.978 0.999 0.999 0.999 Oxygen Concentration Mole Percent O2 8.00 7.00 7.50 8.00 8.00 8.00 Carbon Dioxide Concentration Mole Percent CO2 14.0 12.5 13.5 13.0 13.0 13.0 Volume of Gas Metered Actual Cubic Feet 44.35042.04540.970 37.63437.328 39.184 Volume of Water Collected Milliliters 71.0 82.0 65.0 57 50 63 Sampling Time Minutes 64 64 64 64 64 64 Nozzle Diameter Inches 0.220 0.213 0.211 0.219 0.218 0.224 Weight of Solids Collected Milligrams 14.0 18.4 20.3 18.5 8.3 9.7 Area of Stack Square Feet 134.240134.240134.240134.240134.240134.240 Avg. Sqr. Root Velocity Pressure Inches Water 0.95880.9585 0.9453 0.87160.8705 0.8614 Average Orifice Pressure (DH) Inches Water 1.5 1.3 1.3 1.4 1.3 1.5 Average Stack Temperature Degrees F 279 285 287 288 298 296 Average Meter Temperature Degrees F 84 88 93 89 96 106 Average Generation MW 270 270 270 270 270 270 Flowrate Weighted Side A Side A Side A Side B Side B Side B Side A Side BTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 42.449 39.932 38.536 36.427 35.696 36.84340.30636.322 76.628 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.56 30.28 30.46 30.40 30.40 30.40 30.43 30.40 30.42
Water vapor in Stack Gas Percent 7.3 8.8 7.4 6.9 6.2 7.4 7.8 6.8 7.3
Average Stack Gas Velocity Feet per second 64.0 64.8 63.6 58.7 58.9 58.4 64.1 58.6 61.4

Stack Gas Flow Rate Actual Cubic 515,785521,671512,068472,451474,371470,157516,508472,326988,834 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 354,764355,877348,506321,073318,108315,881353,049318,354671,403 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 328,873324,510322,872299,011298,358292,454325,418296,608622,026 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 24,633 24,306 24,183 22,396 22,347 21,90524,37422,216 46,590 Per Minute Particulate Concentration Grains per Standard 0.005 0.007 0.008 0.008 0.004 0.004 0.007 0.005 0.006 Dry Cubic Foot Particulate Concentration Grains per Actual 0.003 0.004 0.005 0.005 0.002 0.003 0.004 0.003 0.004 Cubic Foot Particulate Emission Rate Pounds per Hour 14.3 19.7 22.5 20.0 9.2 10.2 18.8 13.1 32.0

Particulate Emission Rate Pounds per Million 0.005 0.007 0.008 0.007 0.003 0.003 0.006 0.005 0.011 Allowable Btu (Heat Input) 0.12 Isokinetic Rate Percent 102.5 104.3 103.1 97.7 96.8 96.5 103.3 97.0

Post Test Meter Correction Checkdimensionless 0.97 0.96 0.96 1.02 1.03 1.04 0.96 1.03

Percent Difference Allowed 5% Average -0.9 -1.6 -2.0 2.4 3.1 3.7 -1.5 3.0 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 3

Calculations

## ATTACHMENT 24 - Gaston Report 24 Test Results

SIDE A SIDE A SIDE A SIDE B SIDE B SIDE B Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 7/8/20097/8/20097/8/20097/8/20097/8/20097/8/2009 Sampling Time -Start Military 0820 0934 1048 0820 0934 1048 Sampling Time -Stop Military 0920 1034 1148 0920 1034 1148 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Heat Input Million Btu per Hour 2,260 2,270 2,268 2,260 2,270 2,268 Stack Static Pressure Inches Water -12.50 -12.00 -12.50 -12.50 -12.50 -12.50 Barometric Pressure Inches Mercury 29.89 29.89 29.89 29.89 29.89 29.89 Standard Orifice Pressure DH@ Inches Water 1.858 1.858 1.858 2.088 2.088 2.088 Meter Correction Factor dimensionless 0.978 0.978 0.978 0.999 0.999 0.999 Oxygen Concentration Mole Percent O2 6.0 6.5 6.0 8.0 6.0 6.0 Carbon Dioxide Concentration Mole Percent CO2 13.0 12.5 13.0 11.5 13.5 13.5 Volume of Gas Metered Actual Cubic Feet 41.853 41.79141.72040.01542.69041.250 Volume of Water Collected Milliliters 56.3 70.4 64.7 50.0 79.0 71.0 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.274 0.274 0.275 0.277 0.278 0.278 Weight of Solids Collected Milligrams 48.8 52.4 138.8 27.3 42.8 73.6 Area of Stack Square Feet 216.000216.000216.000216.000216.000216.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.6172 0.6001 0.6035 0.6223 0.63340.6134 Average Orifice Pressure (DH) Inches Water 1.5 1.5 1.5 1.8 2.0 1.9 Average Stack Temperature Degrees F 277 276 277 267 268 270 Average Meter Temperature Degrees F 77 81 82 72 76 79 Average Generation MW 270 270 270 270 270 270 Flowrate Weighted Side ASide BTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 40.333 40.027 39.882 39.84042.16840.54140.08140.850 80.930 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.32 30.26 30.32 30.16 30.40 30.40 30.30 30.32 30.31
Water vapor in Stack Gas Percent 6.2 7.6 7.1 5.6 8.1 7.6 7.0 7.1 7.0
Average Stack Gas Velocity Feet per second 41.1 40.1 40.3 41.2 42.0 40.7 40.5 41.3 40.9

Stack Gas Flow Rate Actual Cubic 532,917519,360521,968534,127544,901527,861524,749535,6301,060,378 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 369,414361,208362,005375,724382,618369,654364,209375,999740,208 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 346,639333,591336,323354,767351,612341,502338,851349,294688,144 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 25,963 24,986 25,191 26,572 26,336 25,57925,38026,162 51,542 Per Minute Particulate Concentration Grains per Standard 0.019 0.020 0.054 0.011 0.016 0.028 0.031 0.018 0.024 Dry Cubic Foot Particulate Concentration Grains per Actual 0.012 0.013 0.035 0.007 0.010 0.018 0.020 0.012 0.016 Cubic Foot Particulate Emission Rate Pounds per Hour 55.4 57.6 154.5 32.1 47.1 81.8 89.2 53.7 142.8

Particulate Emission Rate Pounds per Million 0.024 0.025 0.068 0.014 0.021 0.036 0.039 0.024 0.063 Allowable Btu (Heat Input) 0.120 Isokinetic Rate Percent 102.3 105.5 103.5 96.6 102.4 101.4 103.7 100.1

Post Test Meter Correction Checkdimensionless 0.95 0.96 0.96 1.04 1.01 1.02 0.96 1.02

Percent Difference Allowed 5% Average -2.4 -2.2 -2.2 3.7 1.4 1.6 -2.3 2.2 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT UNIT 4 OUTLET

Calculations

## ATTACHMENT 25 - Gaston Report 25 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Date Month/Day/Year 4/16/20094/16/20094/16/2009 Sampling Time -Start Military 0750 0930 1050 Sampling Time -Stop Military 0910 1036 1204 Number of Ports dimensionless 10 10 10 Number of Points per Port dimensionless 3 3 3 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 Stack Static Pressure Inches Water -22.50 -22.50 -22.50 Barometric Pressure Inches Mercury 30.10 30.10 30.10 Standard Orifice Pressure DH@ Inches Water 1.858 1.858 1.858 Meter Correction Factor dimensionless 0.978 0.978 0.978 Oxygen Concentration Mole Percent O2 5.5 5.5 7.0 Carbon Dioxide Concentration Mole Percent CO2 14.5 14.5 14.0 Volume of Gas Metered Actual Cubic Feet 35.510 36.865 37.895 Volume of Water Collected Milliliters 54.8 56.0 57.1 Sampling Time Minutes 60 60 60 Nozzle Diameter Inches 0.220 0.220 0.220 Weight of Solids Collected Milligrams 29.3 32.0 48.1 Area of Stack Square Feet 812.500 812.500 812.500 Avg. Sqr. Root Velocity Pressure Inches Water 0.8693 0.8772 0.9008 Average Orifice Pressure(DH) Inches Water 1.2 1.2 1.3 Average Stack Temperature Degrees F 273 281 289 Average Meter Temperature Degrees F 52 57 61 Average Generation MW 886 886 886

RUN 1 RUN 2 RUN 3AVERAGE
Volume of Gas Sampled Standard Dry 36.157 37.192 37.894 37.081 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.54 30.54 30.52 30.53
Water vapor in Stack Gas Percent 6.7 6.6 6.6 6.6
Average Stack Gas Velocity Feet per second 58.1 59.0 60.9 59.3

Stack Gas Flow Rate Actual Cubic 2,832,9492,874,8022,968,4912,892,081 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 1,940,7231,947,2351,989,9181,959,292 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 1,811,4911,818,3601,858,1281,829,327 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 135,681 136,195 139,174137,017 Per Minute Particulate Concentration Grains per Standard 0.0125 0.0133 0.0195 0.0151 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0080 0.0084 0.0122 0.0095 Cubic Foot Particulate Emission Rate Pounds per Hour 193.8 206.5 311.3 237.2

Particulate Emission Rate Pounds per Million 0.024 0.025 0.041 0.030 Allowable Btu (O2 F Factor) 0.12 0.12 0.12 0.12 Heat Input (O2 F Factor) Million Btu per Hour 8,189 8,220 7,5827,996.8

Isokinetic Rate Percent 102.4 104.9 104.6 104.0

Post Test Meter Correction Checkdimensionless 0.968 0.953 0.957 0.959

Percent Difference Allowed 5% Average -1.0 -2.5 -2.1 -1.9



### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 5

Calculations

## ATTACHMENT 26 - Gaston Report 26 Test Results

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/1/20066/1/20066/1/2006 6/1/20066/1/20066/1/2006 Sampling Time -Start Military 0857 1043 1234 0857 1043 1234 Sampling Time -Stop Military 0957 1143 1334 0957 1143 1334 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Heat Input Million Btu per Hour 2,614 2,605 2,593 2,614 2,605 2,593 Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00 -12.00 -12.00 Barometric Pressure Inches Mercury 29.96 29.96 29.96 29.96 29.96 29.96 Standard Orifice PressureDH@ Inches Water 2.008 2.008 2.008 2.378 2.378 2.378 Meter Correction Factor dimensionless 0.967 0.967 0.967 0.938 0.938 0.938 Oxygen Concentration Mole Percent O2 7 6.5 7 7.5 8 7.5 Carbon Dioxide Concentration Mole Percent CO2 11.5 12 12 11.5 11 11.5 Volume of Gas Metered Actual Cubic Feet 41.680 39.342 40.185 40.397 40.315 40.225 Volume of Water Collected Milliliters 65.00 59.00 62.00 62.00 63.00 60.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.275 0.275 0.275 0.275 0.275 0.275 Weight of Solids Collected Milligrams 126.0 156.3 127.7 154.8 119.6 114.1 Area of Stack Square Feet 216.000216.000216.000 216.000216.000216.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.6046 0.6088 0.6121 0.5765 0.5779 0.5790 Average Orifice Pressure(DH) Inches Water 1.668 1.716 1.741 1.852 1.847 1.834 Average Stack Temperature Degrees F 257 260 263 266 269 271 Average Meter Temperature Degrees F 77 81 85 74 78 82

RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 39.883 37.355 37.87838.372 37.679 37.343 36.96337.328 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.12 30.18 30.2030.17 30.14 30.08 30.1430.12
Water vapor in Stack Gas Percent 7.1 6.9 7.2 7.1 7.2 7.4 7.1 7.2
Average Stack Gas Velocity Feet per second 39.7 40.0 40.4 40.0 38.1 38.4 38.4 38.3

Stack Gas Flow Rate Actual Cubic 515,127518,938522,942519,002494,248497,082497,882496,404 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 368,651369,933371,171369,918349,177349,734349,450349,454 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 342,386344,334344,619343,780324,077324,005324,645324,242 Feet Per Minute Particulate Concentration Grains per Standard 0.0487 0.0644 0.05190.0550 0.0633 0.0493 0.04750.0534 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0323 0.0428 0.03420.0364 0.0415 0.0321 0.03100.0349 Cubic Foot Particulate Emission Rate Pounds per Hour 142.8 190.2 153.4162.1 175.7 137.0 132.3 148.3

Particulate Emission Rate Pounds per Million 0.055 0.073 0.0590.062 0.067 0.053 0.0510.057 Btu (Heat Input) Isokinetic Rate Percent 101.6 94.7 95.9 97.4 101.5 100.6 99.4100.5

Post Test Meter Correction Factordimensionless 0.97 1.05 1.04 1.02 0.97 0.97 0.97 0.97

Percent Difference Allowed 5% 0.40 7.96 6.84 5.07 2.94 3.46 3.62 3.34 Run 1 Run 2 Run 3Average Combined Particulate Emission Pounds per Million 0.122 0.126 0.1100.119 Rate Btu (Heat Input) 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT, UNIT 1 COMPLIANCE ASSURANCE MONITORING

Calculations

## ATTACHMENT 27 - Gaston Report 27 Test Results

Condition ICondition ICondition IICondition IICondition IICondition IICondition IICondition II Side A Side B Side A Side A Side A Side B Side B Side B Title of Run RUN 1 RUN 1 RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 2/10/20062/10/20062/10/20062/10/20062/10/20062/10/20062/10/20062/10/2006 Sampling Time -Start Military 0825 0825 1032 1218 1323 1032 1218 1322 Sampling Time -Stop Military 0925 0925 1042 1318 1423 1042 1318 1422 Number of Ports dimensionless 6 6 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 5 5 Heat Input Million Btu per Hour 2,666 2,666 2,699 2,701 2,701 2,699 2,701 2,701 Stack Static Pressure Inches Water -9.00 -9.00 -9.00 -9.00 -9.00 -9.00 -9.00 -9.00 Barometric Pressure Inches Mercury 30.25 30.25 30.25 30.25 30.25 30.25 30.25 30.25 Standard Orifice PressureDH@ Inches Water 2.03 2.35 1.004 1.004 1.004 0.988 0.988 0.988 Meter Correction Factor dimensionless 1.004 0.988 7.0 7.0 7.0 7.0 7.5 7.5 Oxygen Concentration Mole Percent O2 7.0 7.0 12.0 12.0 12.0 11.5 11.0 11.0 Carbon Dioxide Concentration Mole Percent CO2 11.0 11.5 37.150 37.800 37.700 35.117 35.790 36.795 Volume of Gas Metered Actual Cubic Feet 40.900 32.905 59.00 62.00 60.00 55.00 59.00 62.00 Volume of Water Collected Milliliters 65.00 53.00 60 60 60 60 60 60 Sampling Time Minutes 60 60 0.270 0.275 0.275 0.275 0.275 0.275 Nozzle Diameter Inches 0.285 0.275 149.6 144.8 157.6 108.7 101.9 111.9 Weight of Solids Collected Milligrams 76.0 46.7 216.000 216.000 216.000 216.000 216.000 216.000 Area of Stack Square Feet 216.000 216.000 0.5930 0.5791 0.5775 0.5646 0.5693 0.5783 Avg. Sqr. Root Velocity PressureInches Water 0.5771 0.5568 1.3 1.4 1.4 1.7 1.8 1.8 Average Orifice Pressure(DH) Inches Water 1.4 1.6 231 234 234 225 231 232 Average Stack Temperature Degrees F 223 225 52 57 58 46 53 56 Average Meter Temperature Degrees F 41 39

Side A Side A Side A Side B Side B Side B RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Side A Side B RUN 1 RUN 1 39.026 39.325 39.140 36.786 36.968 37.821
Volume of Gas Sampled Standard Dry 43.945 34.960 29.39 29.36 29.38 29.32 29.22 29.20 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.26 29.31 6.6 6.9 6.7 6.6 7.0 7.2
Water vapor in Stack Gas Percent 6.5 6.7 38.0 37.2 37.0 36.0 36.5 37.2
Average Stack Gas Velocity Feet per second 36.8 35.5 491,834 481,554 479,947 466,811 473,466 481,666

Stack Gas Flow Rate Actual Cubic 476,901 460,339 371,557 362,357 361,287 355,761 357,854 363,227 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 364,587 351,017 346,873 337,324 336,972 332,370 332,849 337,207 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 340,856 327,637 25,981 25,266 25,239 24,895 24,930 25,257 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 25,530 24,540 0.0590 0.0567 0.0620 0.0455 0.0424 0.0456 Per Minute Particulate Concentration Grains per Standard 0.0266 0.0206 0.0416 0.0397 0.0435 0.0324 0.0298 0.0319 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0190 0.0146 175.5 164.0 179.1 129.6 121.1 131.7 Cubic Foot Particulate Emission Rate Pounds per Hour 77.8 57.8 0.065 0.061 0.066 0.048 0.045 0.049

Particulate Emission Rate Pounds per Million 0.029 0.022 101.8 101.7 101.4 96.6 96.9 97.9 Btu (Heat Input) Isokinetic Rate Percent 104.7 93.1Run 1 Run 2 Run 3 AVERAGE 0.113 0.106 0.115 0.111 Particulate Emission Rate Pounds per Million Btu (Heat Input) (A&B Combined) 0.0509



### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT - UNIT 4 COMPLIANCE ASSURANCE MONITORING

Calculations

## ATTACHMENT 28 - Gaston Report 28 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/17/20065/17/20065/17/2006 Sampling Time -Start Military 0906 1034 1200 Sampling Time -Stop Military 1007 1137 1302 Number of Ports dimensionless 10 10 10 Number of Points per Port dimensionless 3 3 3 Heat Input Million Btu per Hour 8,375 8,354 8,447 Stack Static Pressure Inches Water -21.50 -21.50 -21.50 Barometric Pressure Inches Mercury 30.00 30.00 30.00 Standard Orifice PressureDH@ 

### Inches Water 1.96 1.96 1.96 Meter Correction Factor dimensionless 1.011 1.011 1.011 Oxygen Concentration Mole Percent O2 4.0 4.0 4.0 Carbon Dioxide Concentration Mole Percent CO2 14.5 14.5 14.5 Volume of Gas Metered Actual Cubic Feet 43.775 45.825 46.880 Volume of Water Collected Milliliters 74.00 73.00 77.00 Sampling Time Minutes 60 60 60 Nozzle Diameter Inches 0.235 0.228 0.248 Weight of Solids Collected Milligrams 44.0 62.1 62.9 Area of Stack Square Feet 812.500 812.500 812.500 Avg. Sqr. Root Velocity Pressure Inches Water 0.9774 1.0023 0.9487 Average Orifice Pressure(DH) Inches Water 2.098 2.210 2.444 Average Stack Temperature Degrees F 280 282 282 Average Meter Temperature Degrees F 60 69 70

RUN 1 RUN 2 RUN 3AVERAGE
Volume of Gas Sampled Standard Dry 45.343 46.650 47.595 46.530 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.48 30.48 30.48 30.48
Water vapor in Stack Gas Percent 7.1 6.9 7.1 7.0
Average Stack Gas Velocity Feet per second 65.6 67.4 63.8 65.6

Stack Gas Flow Rate Actual Cubic 3,199,8803,283,6223,110,5423,198,015 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 2,167,7502,219,6812,100,6982,162,710 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 2,013,1082,067,4031,952,0492,010,853 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 150,782 154,848 146,208150,613 Per Minute Particulate Concentration Grains per Standard 0.0149 0.0205 0.0204 0.0186 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0094 0.0129 0.0128 0.0117 Cubic Foot Particulate Emission Rate Pounds per Hour 257.9 363.3 340.5 320.6

Particulate Emission Rate Pounds per Million 0.031 0.043 0.040 0.038 Btu (Heat Input) Isokinetic Rate Percent 101.2 107.7 98.4 102.5

Post Test Meter Correction Factordimensionless 1.03 1.01 1.04 1.03

Percent Difference Allowed 5% 1.43 0.32 3.28 1.68



### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY E.C. GASTON STEAM PLANT - UNIT 5 COMPLIANCE ASSURANCE MONITORING

Calculations

# ATTACHMENT 29 - Gaston Report 31 Test Results

Title of Run Description Date Start 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 3 GRF Off 2000 Thrott 8/13/2008 10:00 10:50 265.7 55 3.78 14.96 660 4 GRF On 2000 Thrott 8/13/2008 12:50 13:40 267.1 93 3.83 14.92 662 5 High O2 8/14/2008 11:10 12:10 265.7 36 4.41 14.35 660 6 Mid O2 8/14/2008 14:15 15:15 265.3 54 3.86 14.8 642 7 Low O2 8/14/2008 16:40 17:40 264.8 173 3.5 15.11 655 8 GRF On 2015 Thrott 8/15/2008 10:00 11:00 268.5 34 4 14.77 652 9 GRF Off 2015 Thrott 8/15/2008 12:40 13:40 266.3 37 3.92 14.86 646 10 Precip In Traverse 8/18/2008 9:45 11:45 264.3 51 4.05 14.76 653 11 Mid Load/ Temp at 608 8/18/2008 23:00 0:00 173.7 62 4.89 13.97 625 12 Min Load 8/19/2008 1:50 2:50 69.1 59 8.87 10.42 580 13 Precip Out Traverse 8/20/2008 9:46 11:46 265.4 48 4.21 14.66 655 

## BOILER BASELINE PERFORMANCE FOR SCR TEST RESULTS

ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 1

# ATTACHMENT 30 - Gaston Report 32 Test Results

Title of Run Load Description Description Date Start 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 1 Turbine Test Data - Mid Load O2 Bias set at +0.7 7/9/2008 14:32 15:00 223 37 4.12 14.59 651 2 SCR Baseline Efficiency Test O2 Bias set at +0.4 7/10/2008 9:33 10:01 270 36 4.17 14.66 680 3 SCR Baseline Efficiency Test O2 Bias set at +0.4 7/10/2008 11:34 12:02 274 36 4.08 14.73 677 4 SCR Baseline Efficiency Test O2 Bias set at +0.4 7/10/2008 14:26 14:52 270 57 3.92 14.74 671 5 SCR Baseline 250 MW Test O2 Bias set at +0.4 7/10/2008 15:16 15:42 250 133 3.95 14.72 656 6 SCR Baseline 230 MW Test O2 Bias set at +0.4 7/10/2008 16:05 16:33 230 277 3.89 14.71 650 7 SCR Baseline 200 MW Test O2 Bias set at +0.4 7/10/2008 17:06 17:33 200 70 4.73 13.97 646 9 Full Load O2 Bias set at +0.9 7/15/2008 8:18 8:45 270 28 4.34 14.3 674 10 Full Load O2 Bias set at +0.9 7/15/2008 11:02 11:29 270 54 4.48 14.21 672 18a Full Load O2 Bias +0.1 7/24/2008 8:26 8:53 270 103 3.59 15.08 673 19 Full Load O2 Bias +0.3 7/24/2008 10:04 10:31 270 100 3.71 14.94 673 20 Full Load O2 Bias +0.3 7/24/2008 11:47 12:14 270 102 3.77 14.84 674 21 Full Load O2 Bias +0.1 7/24/2008 13:18 13:45 270 183 3.58 15.05 673 22 Low Load O2 Bias +0.8 7/29/2008 3:14 3:41 70 54 9.44 9.9 587 23 Temp vs. Load O2 Bias +0.9 7/29/2008 6:22 6:49 150 315 6.23 12.82 641 24 Temp vs. Load O2 Bias +0.2 7/29/2008 8:19 8:46 155 166 5.4 13.56 635 25 182 MW Load Test O2 Bias +0.3 7/29/2008 10:19 10:46 182 131 4.69 14.19 646 

## SCR BASELINE TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 2

# ATTACHMENT 31 - Gaston Report 33 Test Results

Title of Run Date Start TimeEnd TimeUnit LoadAvg. Econ. Gas Outlet CO Avg. Econ. Gas Outlet O2 Avg. Econ. Gas Outlet CO2 Military Military MW ppm % Dry % Dry FGA Test02 2/2/2005 12:31 13:31 270 140 2.9 15.28 FGA Test03 2/2/2005 13:38 14:48 270 143 2.92 15.28 FGA Test05 2/3/2005 9:55 10:55 270 417 2.98 15.3 Test06 2/8/2005 8:25 175 37 4.21 14.02 Test12 2/9/2005 7:57 75 84 9.13 9.6 

## FLUE GAS ANALYZER VERIFICATION PERFORMANCE TEST RESULTS

ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 3

# ATTACHMENT 32 - Gaston Report 34 Test Results

Title of Run Description Date Start 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 Test 1As Found 9/11/2009 11:41 12:17 269.9 25 4.17 14.55 675.7 Test 2Load Decreased During Test (Opacity) 9/14/2009 13:44 14:20 243.7 255 4.38 14.36 656.4 Test 3As Found Baseline @ 240 MW 9/15/2009 11:53 12:29 240 87 4.5 14.25 650.1 Test 4As Found Baseline @ 255 MW 9/15/2009 13:21 13:57 254.9 44 4.36 14.37 659.3 Test 5Changed "C" Mill PA Damper Bias from -4 to 0. 9/15/2009 14:35 15:11 255 40 4.38 14.36 661.3 Test 6As Found Baseline for the Day @ 255 MW 9/16/2009 9:04 9:39 255 144 4.18 14.6 668.4 Test 7"C" Feeder Bias Changed from -2 to +2 9/16/2009 10:17 10:53 254.9 87 4.3 14.49 668.5 Test 8"A" Feeder Bias Changed from +5 to +2 9/16/2009 12:45 13:21 255 154 4.31 14.47 669.3 Test 9"D" Feeder Bias Changed from -2 to +2 9/16/2009 14:39 15:13 255.2 107 4.14 14.64 668 Test 10Lowered O2 Bias from +.6 to +.35, (.25 % pts lower) 9/16/2009 15:51 16:27 255 112 4.12 14.57 668.5 Test 11"As Found" Baseline for the Day @ 255 MW 9/17/2009 9:10 9:46 255 42 4.2 14.6 661.7 Test 12"A" Burner on "C" Mill, Sleeve Closed to Lightoff 9/17/2009 11:15 11:51 255.1 79 4.11 14.68 659.9 Test 13"C" Burner on "C" Mill, Sleeve Closed to Lightoff 9/17/2009 13:20 13:56 255.1 92 3.91 14.81 660 Test 14Throttled Inner Spin Vanes on "B" Burner on "A" Mill from 6 1/4 to 7 1/4 9/17/2009 15:44 16:20 255 130 3.85 14.89 660 Test 15"As Found" Baseline for the Day @ 255 MW 9/18/2009 8:45 9:21 255.1 25 4.14 14.73 650.5 Test 16Throttled "B" Burner Inner Register on "F" Mill, from 6" to 7 1/4" 9/18/2009 9:58 10:34 255 27 4.09 14.81 651.3 Test 17Opened "A" Burner Inner Register on "C" Mill, from 7" to 5" 9/18/2009 11:27 12:03 255 44 4.28 14.66 652.9 

## FLAME DOCTOR TEST RESULTS ALABAMA POWER COMPANY E. C. GASTON STEAM PLANT

UNIT 4