Process Information

1Name of legal owner of facility:

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

3Address of _X__ legal owner or ____ operator:

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

Gorgas 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 - 8 5Complete street address of facility (physical location):

460 Gorgas Road Parrish, AL 35580 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 permitted1to be fired in any steam generating unit at this facility?

_X__ coal

_X__ oil (including pet coke)

_X__ natural gas

_X__ other (specify in question 14 below) Note: 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.

2If the boiler is fired by a blend of coal ranks, please specify percentage (separately, on both a mass and on a Btu basis) of each coal rank (e.g., 85% subbituminuous/15% bituminous).

3In reference to footnote 1, if necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting the reason the fuel type was combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research purposes").13If oil is fired, indicate which type of oil was utilized during the previous 12 months prior to the receipt of this ICR:4

_X__ distillate (% _100_) ____ other (specify _______________) (% _____) ____ residual or bunker C (% _____)

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

1The 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 these other materials.

4If the boiler is fired by a blend of fuel oil ranks, please specify percentage (separately, on both a volume and on a Btu basis) of each fuel oil rank (e.g., 85% residual oil/15% distillate).

5If necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting the reason the fuel was combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research purposes"). 140.7 tons Quantity/year

none

none Other Material Boiler cleaning wastes that are not hazardous wastes as defined in 40 CFR Part 261, Subpart B and ADEM Admin. Code R. 335-14-2 may be combusted in these units for energy recovery. Used oil that is not hazardous waste as defined in 40 CFR Part 279 and ADEM Admin. Code R. 335-14-17, and which is generated at Alabama Power facilities in the state of Alabama may be combusted in these units for energy recovery. This includes non-hazardous 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 No

No

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

6 bituminous CBI CBI 110 103 88.8 87.25 1250 1259 950 944 N/A N/Abituminous coal, No. 2 fuel oil, biomass CBI CBI none not available

7 bituminous CBI CBI 110 104 88.5 88.45 1250 1260 950 946 N/A N/Abituminous coal, No. 2 fuel oil CBI CBI none not available

8 bituminous CBI CBI 175 161 88.52 not available1800 1824 1000 997 1000 981bituminous coal, No. 2 fuel oil CBI CBI none not available

9 bituminous CBI CBI 185 170 88.52 89.97 1800 1829 1000 986 1000 981bituminous coal, No. 2 fuel oil CBI CBI none not available

10bituminous CBI CBI 720 677 89.1 88.67 3500 3500 1000 1000 1000 986bituminous coal, No. 2 fuel oil CBI CBI none not available

NOTES "N/A" means not applicable. Original design fuel.Based on the original contract boiler data sheet; only the primary fuel is listed if multiple fuels were included on the data sheet. See also text to previous response (Part I, No. 11), which indicates that the design fuel simply means the fuel for which the boiler is optimized to operate at maximum possible efficiency, but that the boiler was designed to handle and burn a range of fuels. MWe Gross Capacity Summer.Identifies the gross normal full load as of May 2009. Alabama Power does not change unit capacities from season to season. MWe Net Capacity Summer.Identifies the net normal full load as of May 2009; taken directly from the 2009 installed and authorized document. Alabama Power does not change unit capacities from season to season. Original design gross efficiency (%, HHV).Taken directly from the original contract boiler data sheet. Present operating gross efficiency (%, HHV).Based on the most recent actual test of the boiler efficiency, unless no recent boiler efficiency test was available. Where no recent test was available, that status is indicated. Design steam pressure (psig).Based on the thermal design of the unit as represented on the turbine heat balance sheet. Operating steam pressure (psig).Represents the average throttle pressure when the unit operated at gross normal full load over a three year period (January 2007 to December 2009). Design steam temperature.Based on the thermal design of the unit as represented on the turbine heat balance sheet. Operating steam temperature.Represents the average steam temperature when the unit operated at gross normal full load over a three year period (January 2007 to December 2009). Design steam reheat temperature.Based on the thermal design of the unit as represented on the turbine heat balance sheet. Operating steam reheat temperature.Represents the average steam reheat 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 Gorgas Units 6 - 10. 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
6 wall-fired (1) low-NOx burners (03/26/2003) N/A (2) cold-side ESP (05/21/1976) N/A

7 wall-fired (1) low-NOx burners (03/11/2003) N/A (2) cold-side ESP (06/18/1976) N/A

8 tangential-fired (1) low-NOx burners + closecoupled and separated OFA (05/06/2001) (5) calcium-based wet flue gas desulfurization2(12/13/2007)(2) sodium injection3(prior to 1991) (3) hot-side ESP (06/01/1972)(4) hydrated lime injection1 [SO3] (12/02/2009)

9 tangential-fired (1) low-NOx burners + closecoupled and separated OFA (04/20/1995) (5) calcium-based wet flue gas desulfurization2(12/13/2007)(2) sodium injection3(prior to 1991) (3) hot-side ESP (06/01/1972)(4) hydrated lime injection1 [SO3] (12/02/2009)

10 tangential-fired (1) low-NOx burners + separated OFA (12/19/1995) (3) SCR (05/23/2002) - the SCR uses a titania-vanadia based ceramic catalyst and anhydrous ammonia as the reductant; the catalyst is designed to minimize SO3 formation4 (6) calcium-based wet flue gas desulfurization2(12/13/2007)(2) flue gas conditioning - SO3 injection (04/1985) (4) cold-side ESP (10/27/1972)(5) hydrated lime injection1 [SO3] (12/02/2009)

Note: "N/A" means not applicable.

1Gorgas units 8, 9, and 10 share a common hydrated lime injection system.

2Gorgas units 8, 9, and 10 share a common FGD.

3Sodium injection on Units 8 and 9 varies between sodium sulfate and sodium carbonate.

4When making catalyst decisions, the primary goal is to achieve the desired NOx performance, with a secondary goal of minimizing SO3formation.

14Boiler 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).

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

16Examples: 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?

17Examples: 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.

18Examples: 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.

19Please 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 6 N/A N/A N/A N/A 7 N/A N/A N/A N/A 8 N/A N/A N/A N/A 9 N/A N/A N/A N/A 10 N/A N/A N/A N/A

Note: "N/A" means not applicable.

20A 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.

21Boiler 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

6 N/A N/A N/A N/A N/A N/A 7 N/A N/A N/A N/A N/A N/A 8 N/A N/A N/A N/A N/A N/A 9 N/A N/A N/A N/A N/A N/A 10 N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

22Boiler 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).

23If 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 6 N/A N/A N/A N/A 7 N/A N/A N/A N/A 8 N/A N/A N/A N/A 9 N/A N/A N/A N/A 10 N/A N/A N/A N/A

Note: "N/A" means not applicable.

24Boiler 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 basedCoal rank(s) upon

which guarantee is based

6 N/A N/A N/A N/A N/A N/A 7 N/A N/A N/A N/A N/A N/A 8 N/A N/A N/A N/A N/A N/A 9 N/A N/A N/A N/A N/A N/A 10 N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

25Boiler 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).

26If 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)

6 0.12 lb/MMBtu (Title V permit; annual Reference Method 5 or 17) N/A N/A4.0 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/ANOx: 0.21 lb/MMBtu (Title V permit; 30-day average between James H Miller Jr and Gorgas units during ozone season)

7 0.12 lb/MMBtu (Title V permit; annual Reference Method 5 or 17) N/A N/A4.0 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/ANOx: 0.21 lb/MMBtu (Title V permit; 30-day average between James H Miller Jr and Gorgas units during ozone season)

8 0.12 lb/MMBtu (Title V permit; annual Reference Method 5 or 17) N/A N/A4.0 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/ANOx: 0.21 lb/MMBtu (Title V permit; 30-day average between James H Miller Jr and Gorgas units during ozone season)

9 0.12 lb/MMBtu (Title V permit; annual Reference Method 5 or 17) N/A N/A4.0 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/ANOx: 0.21 lb/MMBtu (Title V permit; 30-day average between James H Miller Jr and Gorgas units during ozone season)

10 0.12 lb/MMBtu (Title V permit; annual Reference Method 5 or 17) N/A N/A4.0 lb/MMBtu (Title V permit; 24-hour rolling average) N/A N/A N/A N/A N/A N/ANOx: 0.21 lb/MMBtu (Title V permit; 30-day average between James H Miller Jr and Gorgas units during ozone season)

Note: "N/A" means not applicable.

27Boiler 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).

28If 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.

29List the compliance test method utilized.

30List the compliance test method utilized.

31Metal 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)

6 ESP: 0.05 lb/MMBtu, filterable (expired in 1997) N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

7 ESP: 0.05 lb/MMBtu, filterable (expired in 1997) N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A

8 ESP: 0.06 lb/MMBtu, filterable (expired in 2008); 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

9 ESP: 0.06 lb/MMBtu, filterable (expired in 2008); 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 LNB: 0.50 lb/MMBtu NOx guarantee (expired in 1996)

10ESP: 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 LNB: 0.45 lb/MMBtu NOx guarantee (expired in 2000)

Note: "N/A" means not applicable.

1These guarantees are dependent on specific operating conditions and expired 18 months after the FGD began operation.



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

_X__ No Please elaborate.

32Boiler 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).

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

34Metal 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 HCNMetal

HAP37 

### Hg CO Other organics (specify) 6 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 and submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/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 of 2 working days of such deviations, including those attributable to the upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventive measures that were taken. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A

7 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 and submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/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 of 2 working days of such deviations, including those attributable to the upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventive measures that were taken. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A

8 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 and submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/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 of 2 working days of such deviations, including those attributable to the upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventive 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 HCNMetal

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

9 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 and submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/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 of 2 working days of such deviations, including those attributable to the upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventive measures that were taken. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A

10Emission 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 and submitted as proof of compliance with ADEM Rules and Regulations. Submission of an annual particulate matter testing schedule with periodic updates as changes occur will satisfy the 10-day notification requirement. All records must be maintained for 5 years. N/A N/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 of 2 working days of such deviations, including those attributable to the upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or preventive 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.

35Boiler 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).

36If 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.

37Metal 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.

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

### Fuel Analysis39



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

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

Plant Code - 8

39The 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 shBtu/lb 502 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.72 17.27 12,154 461 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.55 15.43 12,596 23 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.43 8.65 13,741 1,758 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.94 14.14 12,695 1,941 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.83 14.12 12,799 1,799 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.73 13.23 13,064 550 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.30 12.58 12,975 703 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.22 11.96 13,023 682 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.71 12.30 13,085 543 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.55 12.55 13,004 556 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.33 11.71 13,150 566 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.31 11.15 13,247 575 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.36 12.10 13,036 649 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.37 13.61 13,065 226 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.03 10.56 13,401 656 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.15 11.16 13,259 727 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.25 13.03 12,950 733 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.32 13.33 12,905 405 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.86 12.24 13,282 284 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.58 12.87 12,908 639 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.10 18.33 12,201 327 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.73 14.65 12,799 363 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.72 14.43 12,761 769 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.57 16.51 12,333 417 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.59 22.47 11,391 634 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.07 18.34 12,063 582 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.59 15.75 12,513 588 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.61 12.02 13,014 375 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.82 12.58 12,969 354 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.93 11.86 13,051 228 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.03 18.57 12,128 176 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.39 16.50 12,268 775 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.69 17.67 12,201 554 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.16 16.51 12,323 884 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.76 19.68 11,907 952 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.91 17.56 12,240 1,002 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.09 14.04 12,917 1,569 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.04 19.83 12,098 1,412 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.21 12.64 13,251 2,047 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.92 17.04 12,468 1,630 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.02 16.58 12,613 1,824 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.14 17.44 12,417 1,952 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.98 11.69 13,447 

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

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

### Fuel source Fuel Shipment MethodD.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,905 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.10 20.86 11,711 1,865 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.16 17.07 12,359 1,843 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.15 15.09 12,663 1,836 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.48 14.63 12,791 1,832 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.37 15.94 12,620 1,466 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.30 17.29 12,349 1,064 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.03 13.18 13,007 1,213 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.28 14.92 12,807 1,145 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 2.04 16.61 12,329 1,690 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.86 12.88 13,017 1,555 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.59 11.75 13,270 1,465 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.66 12.40 13,136 1,575 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.45 15.58 12,567 1,690 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.28 16.72 12,382 1,473 6, 7 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.64 15.15 12,643 396 6, 7 N/A N/A MARY LEE TRUCK 1.85 14.77 12,798 397 6, 7 N/A N/A MARY LEE TRUCK 1.85 14.77 12,798 393 6, 7 N/A N/A MARY LEE TRUCK 1.85 14.77 12,798 367 6, 7 N/A N/A MARY LEE TRUCK 1.85 14.77 12,798 288 6, 7 N/A N/A MARY LEE TRUCK 1.75 16.71 12,460 394 6, 7 N/A N/A MARY LEE TRUCK 1.72 16.16 12,576 502 6, 7 N/A N/A MARY LEE TRUCK 2.06 14.74 12,852 340 6, 7 N/A N/A MARY LEE TRUCK 1.84 14.99 12,729 348 6, 7 N/A N/A MARY LEE TRUCK 1.17 14.43 12,706 239 6, 7 N/A N/A MARY LEE TRUCK 1.32 14.93 12,687 400 6, 7 N/A N/A MARY LEE TRUCK 1.95 14.00 12,974 397 6, 7 N/A N/A MARY LEE TRUCK 2.37 14.47 12,995 390 6, 7 N/A N/A MARY LEE TRUCK 1.79 13.85 12,929 748 6, 7 N/A N/A MARY LEE TRUCK 1.99 14.35 12,854 314 6, 7 N/A N/A MARY LEE TRUCK 2.16 16.46 12,529 315 6, 7 N/A N/A MARY LEE TRUCK 2.38 16.48 12,554 317 6, 7 N/A N/A MARY LEE TRUCK 1.48 15.79 12,485 317 6, 7 N/A N/A MARY LEE TRUCK 2.20 16.27 12,432 537 6, 7 N/A N/A MARY LEE TRUCK 2.09 15.20 12,831 269 6, 7 N/A N/A MARY LEE TRUCK 2.19 14.97 12,867 315 6, 7 N/A N/A MARY LEE TRUCK 1.91 16.06 12,571 374 6, 7 N/A N/A MARY LEE TRUCK 1.83 14.99 12,762 370 6, 7 N/A N/A MARY LEE TRUCK 2.01 15.25 12,684 348 6, 7 N/A N/A MARY LEE TRUCK 1.92 15.79 12,656 375 6, 7 N/A N/A MARY LEE TRUCK 2.36 15.66 12,690 390 6, 7 N/A N/A MARY LEE TRUCK 1.85 16.48 12,497 377 6, 7 N/A N/A MARY LEE TRUCK 1.97 16.05 12,624 399 6, 7 N/A N/A MARY LEE TRUCK 2.52 16.12 12,596 313 6, 7 N/A N/A MARY LEE TRUCK 1.55 15.33 12,665 322 6, 7 N/A N/A MARY LEE TRUCK 1.63 15.47 12,669D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method

322 6, 7 N/A N/A MARY LEE TRUCK 1.46 15.19 12,661 373 6, 7 N/A N/A MARY LEE TRUCK 1.63 15.59 12,571 375 6, 7 N/A N/A MARY LEE TRUCK 1.75 15.70 12,617 318 6, 7 N/A N/A MARY LEE TRUCK 1.85 15.75 12,527 530 6, 7 N/A N/A MARY LEE TRUCK 1.70 16.54 12,282 394 6, 7 N/A N/A MARY LEE TRUCK 1.78 15.14 12,704 107 6, 7 N/A N/A MARY LEE TRUCK 1.73 14.76 12,715 189 6, 7 N/A N/A MARY LEE TRUCK 2.27 15.56 12,651 409 6, 7 N/A N/A MARY LEE TRUCK 2.01 15.01 12,821 532 6, 7 N/A N/A MARY LEE TRUCK 2.08 15.13 12,805 926 6, 7 N/A N/A MARY LEE TRUCK 1.87 14.88 12,861 947 6, 7 N/A N/A MARY LEE TRUCK 1.78 14.33 12,805 383 6, 7 N/A N/A MARY LEE TRUCK 1.74 14.55 12,753 408 6, 7 N/A N/A MARY LEE TRUCK 1.89 14.70 12,817 411 6, 7 N/A N/A MARY LEE TRUCK 1.90 13.72 13,041 321 6, 7 N/A N/A MARY LEE TRUCK 2.52 14.20 13,112 321 6, 7 N/A N/A MARY LEE TRUCK 2.11 12.05 13,497 323 6, 7 N/A N/A MARY LEE TRUCK 2.21 13.14 13,265 320 6, 7 N/A N/A MARY LEE TRUCK 2.28 13.88 13,112 318 6, 7 N/A N/A MARY LEE TRUCK 1.73 13.24 13,080 321 6, 7 N/A N/A MARY LEE TRUCK 1.98 13.22 13,167 319 6, 7 N/A N/A MARY LEE TRUCK 1.88 13.76 13,087 327 6, 7 N/A N/A MARY LEE TRUCK 1.58 12.10 13,420 323 6, 7 N/A N/A MARY LEE TRUCK 1.88 13.42 12,911 328 6, 7 N/A N/A MARY LEE TRUCK 1.97 13.32 13,151 325 6, 7 N/A N/A MARY LEE TRUCK 2.04 13.72 13,116 324 6, 7 N/A N/A MARY LEE TRUCK 2.25 13.58 13,144 324 6, 7 N/A N/A MARY LEE TRUCK 1.96 12.86 13,317 329 6, 7 N/A N/A MARY LEE TRUCK 1.86 12.80 13,205 352 6, 7 N/A N/A MARY LEE TRUCK 1.65 13.90 12,938 381 6, 7 N/A N/A MARY LEE TRUCK 1.85 14.81 12,886 379 6, 7 N/A N/A MARY LEE TRUCK 1.98 14.66 12,960 184 6, 7 N/A N/A MARY LEE TRUCK 1.62 12.10 13,234 187 6, 7 N/A N/A MARY LEE TRUCK 2.05 12.91 13,217 184 6, 7 N/A N/A MARY LEE TRUCK 2.30 13.20 13,168 187 6, 7 N/A N/A MARY LEE TRUCK 1.53 12.81 13,036 190 6, 7 N/A N/A MARY LEE TRUCK 2.28 13.32 13,060 188 6, 7 N/A N/A MARY LEE TRUCK 2.14 12.24 13,306 181 6, 7 N/A N/A MARY LEE TRUCK 2.24 13.05 13,111 187 6, 7 N/A N/A MARY LEE TRUCK 2.18 10.97 13,493 185 6, 7 N/A N/A MARY LEE TRUCK 2.22 11.14 13,313 186 6, 7 N/A N/A MARY LEE TRUCK 2.07 10.50 13,530 179 6, 7 N/A N/A MARY LEE TRUCK 1.85 11.62 13,271 187 6, 7 N/A N/A MARY LEE TRUCK 2.12 12.56 13,170 191 6, 7 N/A N/A MARY LEE TRUCK 2.16 13.11 13,111D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method

251 6, 7 N/A N/A MARY LEE TRUCK 1.25 10.41 13,336 269 6, 7 N/A N/A MARY LEE TRUCK 1.81 15.97 12,651 271 6, 7 N/A N/A MARY LEE TRUCK 2.11 15.67 12,756 266 6, 7 N/A N/A MARY LEE TRUCK 1.23 15.29 12,652 161 6, 7 N/A N/A MARY LEE TRUCK 1.82 15.28 12,773 162 6, 7 N/A N/A MARY LEE TRUCK 1.59 15.40 12,736 160 6, 7 N/A N/A MARY LEE TRUCK 1.42 15.08 12,930 160 6, 7 N/A N/A MARY LEE TRUCK 1.77 15.42 12,760 159 6, 7 N/A N/A MARY LEE TRUCK 1.49 15.29 12,738 162 6, 7 N/A N/A MARY LEE TRUCK 2.05 16.58 12,526 161 6, 7 N/A N/A MARY LEE TRUCK 2.02 17.03 12,463 159 6, 7 N/A N/A MARY LEE TRUCK 1.98 17.36 12,441 161 6, 7 N/A N/A MARY LEE TRUCK 1.88 15.76 12,678 185 6, 7 N/A N/A MARY LEE TRUCK 1.85 14.28 12,940 158 6, 7 N/A N/A MARY LEE TRUCK 1.82 16.33 12,542 161 6, 7 N/A N/A MARY LEE TRUCK 1.69 15.53 12,747 183 6, 7 N/A N/A MARY LEE TRUCK 1.88 16.25 12,530 161 6, 7 N/A N/A MARY LEE TRUCK 1.75 17.46 12,378 178 6, 7 N/A N/A MARY LEE TRUCK 1.75 17.91 12,244 186 6, 7 N/A N/A MARY LEE TRUCK 1.54 16.40 12,476 157 6, 7 N/A N/A MARY LEE TRUCK 1.78 13.28 13,049 188 6, 7 N/A N/A MARY LEE TRUCK 1.82 13.35 13,118 164 6, 7 N/A N/A MARY LEE TRUCK 1.74 15.19 12,819 173 6, 7 N/A N/A MARY LEE TRUCK 1.25 15.60 12,643 148 6, 7 N/A N/A MARY LEE TRUCK 1.60 16.06 12,533 186 6, 7 N/A N/A MARY LEE TRUCK 1.12 15.70 12,559 156 6, 7 N/A N/A MARY LEE TRUCK 1.27 15.62 12,676 181 6, 7 N/A N/A MARY LEE TRUCK 1.70 15.10 12,799 155 6, 7 N/A N/A MARY LEE TRUCK 1.13 14.65 12,735 184 6, 7 N/A N/A MARY LEE TRUCK 1.65 14.90 12,897 162 6, 7 N/A N/A MARY LEE TRUCK 1.67 14.91 12,924 156 6, 7 N/A N/A MARY LEE TRUCK 1.92 15.82 12,794 243 6, 7 N/A N/A MARY LEE TRUCK 1.88 13.43 13,122 262 6, 7 N/A N/A MARY LEE TRUCK 2.07 13.94 12,901 256 6, 7 N/A N/A MARY LEE TRUCK 1.74 11.74 13,377 266 6, 7 N/A N/A MARY LEE TRUCK 1.91 12.35 13,006 252 6, 7 N/A N/A MARY LEE TRUCK 1.99 12.78 13,076 186 6, 7 N/A N/A MARY LEE TRUCK 2.21 15.52 12,660 175 6, 7 N/A N/A MARY LEE TRUCK 1.93 15.58 12,632 187 6, 7 N/A N/A MARY LEE TRUCK 1.77 12.47 13,296 186 6, 7 N/A N/A MARY LEE TRUCK 2.02 13.06 13,192 185 6, 7 N/A N/A MARY LEE TRUCK 1.84 15.09 12,582 187 6, 7 N/A N/A MARY LEE TRUCK 2.05 13.21 13,107 174 6, 7 N/A N/A MARY LEE TRUCK 1.79 13.69 12,977 184 6, 7 N/A N/A MARY LEE TRUCK 1.64 14.77 12,879D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method

186 6, 7 N/A N/A MARY LEE TRUCK 1.19 15.05 12,778 185 6, 7 N/A N/A MARY LEE TRUCK 1.24 14.97 12,775 188 6, 7 N/A N/A MARY LEE TRUCK 1.35 14.98 12,721 164 6, 7 N/A N/A MARY LEE TRUCK 1.20 14.98 12,668 181 6, 7 N/A N/A MARY LEE TRUCK 1.99 14.83 12,865 183 6, 7 N/A N/A MARY LEE TRUCK 1.51 15.62 12,741 184 6, 7 N/A N/A MARY LEE TRUCK 1.85 15.40 12,771 186 6, 7 N/A N/A MARY LEE TRUCK 1.58 14.73 12,896 188 6, 7 N/A N/A MARY LEE TRUCK 1.66 15.29 12,740 187 6, 7 N/A N/A MARY LEE TRUCK 1.89 15.47 12,859 185 6, 7 N/A N/A MARY LEE TRUCK 1.67 15.02 12,780 178 6, 7 N/A N/A MARY LEE TRUCK 1.70 16.05 12,715 183 6, 7 N/A N/A MARY LEE TRUCK 1.77 15.89 12,671 184 6, 7 N/A N/A MARY LEE TRUCK 1.90 15.59 12,636 174 6, 7 N/A N/A MARY LEE TRUCK 1.51 15.73 12,655 183 6, 7 N/A N/A MARY LEE TRUCK 1.40 15.35 12,704 176 6, 7 N/A N/A MARY LEE TRUCK 1.88 15.55 12,749 182 6, 7 N/A N/A MARY LEE TRUCK 1.40 16.11 12,569 185 6, 7 N/A N/A MARY LEE TRUCK 1.66 14.25 12,868 178 6, 7 N/A N/A MARY LEE TRUCK 1.93 15.21 12,823 179 6, 7 N/A N/A MARY LEE TRUCK 2.13 15.56 12,678 184 6, 7 N/A N/A MARY LEE TRUCK 2.03 15.15 12,661 267 6, 7 N/A N/A MARY LEE TRUCK 2.28 16.18 12,564 208 6, 7 N/A N/A MARY LEE TRUCK 2.03 15.00 12,700 214 6, 7 N/A N/A MARY LEE TRUCK 1.80 15.58 12,567 208 6, 7 N/A N/A MARY LEE TRUCK 1.97 15.46 12,576 211 6, 7 N/A N/A MARY LEE TRUCK 1.86 15.58 12,468 215 6, 7 N/A N/A MARY LEE TRUCK 2.14 15.66 12,606 212 6, 7 N/A N/A MARY LEE TRUCK 2.25 17.05 12,455 1,319 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #3 TRUCK 1.57 13.71 12,921 1,233 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #3 TRUCK 1.72 14.46 12,833 1,313 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #3 TRUCK 1.81 14.32 12,805 1,292 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #3 TRUCK 1.80 14.70 12,827 1,296 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #3 TRUCK 1.95 14.80 12,740 1,450 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #3 TRUCK 1.81 16.14 12,536 1,385 8, 9 ALABAMA MARION BLUE CREEK BARGE 1.35 14.29 12,870 1,382 8, 9 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.52 15.74 12,489 1,413 8, 9 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.48 15.56 12,549 1,049 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.42 14.60 12,599 579 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.22 21.98 11,619 1,381 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.27 12.97 12,996 1,344 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.64 15.45 12,409 1,180 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.86 13.36 13,055 762 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.24 14.89 12,778 915 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.41 14.83 12,897D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,851 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.14 13.58 13,071 1,756 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.05 15.51 12,681 860 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.83 15.94 12,495 1,025 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.18 13.93 12,975 967 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.93 25.96 10,760 617 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.85 23.70 11,128 1,970 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.29 17.04 12,316 1,846 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.08 19.20 12,011 1,429 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.10 15.08 12,675 1,299 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.40 15.49 12,334 976 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.51 24.00 11,228 1,927 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.63 14.55 12,746 1,852 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.33 20.71 11,699 2,621 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.54 15.08 12,520 3,552 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.69 15.89 12,429 2,885 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.88 17.29 12,222 1,893 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.61 19.99 11,901 1,736 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.93 18.97 11,903 2,016 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.16 16.75 12,425 1,395 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.72 20.70 11,860 1,625 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.85 17.03 12,106 1,609 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.85 14.54 12,801 932 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.51 20.60 11,849 1,774 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.85 19.27 11,977 1,947 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.08 18.82 12,119 2,063 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.76 15.86 12,619 1,878 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.35 20.61 11,797 1,847 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.37 20.13 11,827 3,860 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.51 16.72 12,328 3,636 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 0.99 15.79 12,545 2,036 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.51 16.13 12,444 2,427 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.44 14.34 12,641 1,905 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.95 16.63 12,451 2,664 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.42 20.34 11,829 2,969 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.93 18.04 12,112 2,381 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.44 16.64 12,520 2,436 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.68 16.65 12,403 2,060 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.24 18.16 12,254 771 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.08 17.32 12,544 1,455 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.96 18.87 12,074 1,859 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.29 14.29 13,003 2,863 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.15 16.04 12,637 1,603 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.07 15.40 12,755 756 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.43 8.94 13,926 1,606 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.56 20.20 11,864D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,774 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.17 14.67 12,861 2,681 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.39 13.59 13,122 1,891 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.99 17.57 12,187 2,059 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.73 16.60 12,527 1,470 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.09 16.97 12,450 1,373 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.66 16.75 12,484 1,660 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.87 14.73 12,695 1,651 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.63 15.03 12,767 1,717 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.76 15.91 12,642 2,137 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.52 14.10 12,800 2,169 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 19.03 12,004 2,595 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.44 17.75 12,161 2,726 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.71 16.53 12,485 2,871 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.78 17.39 12,388 4,015 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.91 15.03 12,864 2,849 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.91 18.22 12,160 2,338 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.79 20.43 11,710 2,638 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.70 16.25 12,492 3,052 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.93 15.68 12,614 3,078 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.83 18.12 12,091 1,909 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.88 17.69 12,230 3,144 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.64 15.29 12,639 2,654 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.61 17.85 12,258 3,269 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.78 15.85 12,573 2,704 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.97 15.11 12,735 3,024 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.52 16.58 12,427 1,894 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.71 17.26 12,328 1,834 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.07 16.38 12,474 1,718 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.67 17.76 12,243 1,656 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.99 17.31 12,289 1,883 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.25 16.38 12,459 2,100 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.81 15.46 12,525 2,064 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.09 17.85 12,224 1,932 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.25 17.65 12,420 1,504 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.60 18.24 12,193 1,944 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.93 14.92 12,821 1,878 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 17.64 12,308 1,936 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.16 18.92 12,057 1,704 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.06 16.13 12,580 2,214 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.91 17.60 12,404 2,302 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.83 17.75 12,305 2,594 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.89 18.68 12,158 2,861 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.92 18.16 12,199 2,739 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.03 13.55 12,534 3,000 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.51 14.96 12,834D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 2,098 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.34 12.88 13,244 1,857 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.18 13.65 13,047 1,989 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.90 14.91 12,822 1,880 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.58 16.79 12,524 1,674 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.78 14.65 12,878 1,781 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.62 16.29 12,628 1,827 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.00 17.96 12,360 1,798 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.14 17.37 12,277 1,646 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.69 15.42 12,650 1,612 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.66 17.27 12,357 1,714 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.88 17.69 12,312 1,971 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.02 16.77 12,438 2,106 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.10 17.06 12,380 2,119 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.05 17.17 12,368 2,023 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.92 17.62 12,257 2,228 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.95 16.77 12,491 2,060 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.02 15.85 12,621 2,289 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.87 15.50 12,682 2,208 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.31 14.01 12,792 2,202 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.93 18.19 12,180 1,888 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.11 17.03 12,367 2,785 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.02 17.29 12,364 2,590 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.25 18.76 12,096 2,675 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.92 17.37 12,387 2,559 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.24 18.21 12,175 2,438 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.14 19.24 12,122 2,656 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.29 16.63 12,420 2,360 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.92 15.17 12,790 2,268 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.91 15.06 12,784 2,186 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.83 16.56 12,428 2,001 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.14 17.78 12,303 1,893 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.03 15.18 12,716 2,241 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.08 16.08 12,605 2,275 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.09 17.35 12,352 1,869 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.03 15.98 12,495 1,708 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.92 17.16 12,410 1,814 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.07 18.86 12,072 1,963 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.98 17.18 12,404 2,012 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.89 16.41 12,427 2,179 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.69 15.81 12,565 1,688 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.11 17.11 12,425 1,373 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.05 18.05 12,248 896 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.83 15.53 12,813 1,986 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.24 16.43 12,586 2,087 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 15.44 12,768D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 2,155 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.89 17.05 12,474 2,067 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.21 17.40 12,356 2,167 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 14.93 12,808 2,135 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.01 16.74 12,533 2,142 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 0.81 14.56 12,605 2,171 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.05 16.26 12,601 2,271 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.15 17.79 12,321 2,214 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.97 17.23 12,397 2,151 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.94 18.27 12,226 2,017 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.75 15.79 12,672 1,315 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 17.23 12,392 2,409 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.52 15.02 12,669 2,325 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.51 14.32 12,845 2,079 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.50 14.43 12,874 2,162 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 14.79 12,813 2,025 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.78 15.07 12,782 1,857 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.94 15.08 12,728 1,766 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.08 15.65 12,654 2,370 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.94 14.27 12,857 1,870 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.97 15.40 12,712 1,826 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.71 14.12 12,847 1,759 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.83 16.75 12,431 1,682 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.74 15.86 12,500 1,870 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.84 16.69 12,437 1,825 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.75 18.28 12,231 1,971 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.71 16.13 12,203 2,144 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 17.01 12,289 2,054 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.86 15.79 12,596 1,667 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.69 14.73 12,826 2,225 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.74 16.10 12,595 2,082 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.72 18.23 12,159 2,396 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.49 16.59 12,502 1,719 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.36 13.82 12,930 1,748 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.01 12.41 13,093 1,836 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.61 16.38 12,537 2,156 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.44 12.78 13,134 2,815 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.92 19.20 12,120 3,055 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.23 17.21 12,388 2,251 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.63 15.09 12,686 1,404 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.64 16.49 12,595 2,236 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.57 12.37 13,184 1,650 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.74 14.73 12,811 1,708 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.90 14.67 12,873 1,734 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.00 15.97 12,602 33 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.74 14.73 12,811D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,815 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.92 15.95 12,524 1,678 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.88 16.72 12,481 1,671 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.86 16.71 12,474 1,749 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.88 17.78 12,261 2,269 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.49 14.65 12,811 2,218 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.81 16.92 12,354 2,145 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 16.37 12,469 2,285 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.75 15.03 12,714 2,265 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 17.62 12,283 2,224 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 15.93 12,518 2,204 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.77 16.48 12,519 2,282 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.82 14.89 12,750 2,375 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.81 16.00 12,538 2,345 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.10 15.15 12,756 2,207 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.10 15.93 12,613 2,239 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.02 16.22 12,571 1,696 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.11 17.70 12,233 2,546 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.01 20.81 11,752 2,427 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.87 16.48 12,481 2,280 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.94 17.59 12,367 2,504 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.86 16.44 12,549 2,209 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.78 15.25 12,739 2,166 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.61 15.35 12,691 2,047 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.57 14.09 12,960 2,137 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.61 15.18 12,751 2,262 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.55 14.84 12,822 1,984 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.73 16.52 12,518 1,988 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.85 16.62 12,476 1,982 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.11 17.60 12,343 2,277 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.51 17.82 12,254 2,314 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 2.09 16.96 12,434 2,249 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.86 15.82 12,660 2,215 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.97 15.46 12,759 1,975 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.83 17.50 12,173 1,975 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.60 17.44 12,281 2,105 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.64 15.01 12,740 1,239 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.68 16.23 12,547 1,221 8, 9 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1 TRUCK 1.98 17.99 12,217 0 8, 9 ALABAMA WALKER MARY LEE TRUCK 519 8, 9 ALABAMA WALKER MARY LEE TRUCK 0.80 15.98 12,410 248 8, 9 ALABAMA WALKER MARY LEE TRUCK 0.84 16.00 12,458 11 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.78 15.99 12,404 490 8, 9 ALABAMA WALKER MARY LEE TRUCK 0.89 14.18 12,784 409 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.12 15.07 12,622 146 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.11 15.47 12,537D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method

590 8, 9 ALABAMA WALKER MARY LEE TRUCK 0.95 15.04 12,624 247 8, 9 ALABAMA WALKER MARY LEE TRUCK 0.86 15.42 12,484 131 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.11 15.47 12,537 857 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.10 15.94 12,361 643 8, 9 ALABAMA WALKER MARY LEE TRUCK 0.95 15.96 12,449 466 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.84 14.97 12,774 378 8, 9 ALABAMA WALKER MARY LEE TRUCK 0.99 15.54 12,472 345 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.47 15.73 12,508 279 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.17 16.54 12,402 194 8, 9 ALABAMA WALKER MARY LEE TRUCK 2.10 17.58 12,304 674 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.08 16.02 12,438 442 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.21 15.79 12,543 396 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.20 16.22 12,470 619 8, 9 ALABAMA WALKER MARY LEE TRUCK 0.97 15.93 12,357 135 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.09 16.33 12,374 1,216 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.78 15.99 12,404 1,379 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.77 14.81 12,704 452 8, 9 ALABAMA WALKER MARY LEE TRUCK 1.51 14.08 12,807 283 8, 9 ALABAMA WALKER MARY LEE TRUCK 2.18 15.98 12,539 228 8, 9 N/A N/A MARY LEE TRUCK 2.89 13.25 13,176 277 8, 9 N/A N/A MARY LEE TRUCK 2.89 13.25 13,176 138 8, 9 N/A N/A MARY LEE TRUCK 2.23 13.31 13,140 149 8, 9 N/A N/A MARY LEE TRUCK 2.41 14.01 13,045 105 8, 9 N/A N/A MARY LEE TRUCK 3.38 14.45 12,975 174 8, 9 N/A N/A MARY LEE TRUCK 2.02 12.15 13,480 139 8, 9 N/A N/A MARY LEE TRUCK 2.27 14.46 12,940 138 8, 9 N/A N/A MARY LEE TRUCK 2.81 14.53 12,963 139 8, 9 N/A N/A MARY LEE TRUCK 2.58 15.77 12,740 139 8, 9 N/A N/A MARY LEE TRUCK 2.56 14.70 12,880 140 8, 9 N/A N/A MARY LEE TRUCK 2.71 16.28 12,625 139 8, 9 N/A N/A MARY LEE TRUCK 2.82 15.86 12,717 138 8, 9 N/A N/A MARY LEE TRUCK 2.26 15.56 12,709 137 8, 9 N/A N/A MARY LEE TRUCK 2.40 15.57 12,712 132 8, 9 N/A N/A MARY LEE TRUCK 2.43 15.90 12,677 139 8, 9 N/A N/A MARY LEE TRUCK 2.37 14.90 12,884 134 8, 9 N/A N/A MARY LEE TRUCK 2.06 16.88 12,430 113 8, 9 N/A N/A MARY LEE TRUCK 2.43 16.36 12,624 104 8, 9 N/A N/A MARY LEE TRUCK 2.54 13.66 13,072 111 8, 9 N/A N/A MARY LEE TRUCK 2.63 15.82 12,725 103 8, 9 N/A N/A MARY LEE TRUCK 2.29 15.45 12,710 126 8, 9 N/A N/A MARY LEE TRUCK 2.47 14.78 12,877 113 8, 9 N/A N/A MARY LEE TRUCK 2.20 15.12 12,811 113 8, 9 N/A N/A MARY LEE TRUCK 2.30 13.19 13,059 114 8, 9 N/A N/A MARY LEE TRUCK 2.21 12.49 13,175 114 8, 9 N/A N/A MARY LEE TRUCK 1.84 16.16 12,571D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method

115 8, 9 N/A N/A MARY LEE TRUCK 1.43 15.97 12,582 114 8, 9 N/A N/A MARY LEE TRUCK 2.29 15.45 12,710 111 8, 9 N/A N/A MARY LEE TRUCK 2.70 16.90 12,503 113 8, 9 N/A N/A MARY LEE TRUCK 1.94 15.65 12,584 115 8, 9 N/A N/A MARY LEE TRUCK 2.26 16.32 12,472 115 8, 9 N/A N/A MARY LEE TRUCK 2.57 16.42 12,611 114 8, 9 N/A N/A MARY LEE TRUCK 2.03 15.08 12,733 117 8, 9 N/A N/A MARY LEE TRUCK 2.31 15.79 12,607 114 8, 9 N/A N/A MARY LEE TRUCK 2.59 16.65 12,576 110 8, 9 N/A N/A MARY LEE TRUCK 2.70 16.78 12,380 112 8, 9 N/A N/A MARY LEE TRUCK 2.00 15.00 12,824 451 8, 9 N/A N/A MARY LEE TRUCK 1.29 14.77 12,381 363 8, 9 N/A N/A MARY LEE TRUCK 0.93 16.18 12,407 344 8, 9 N/A N/A MARY LEE TRUCK 1.08 15.27 12,490 334 8, 9 N/A N/A MARY LEE TRUCK 1.01 15.67 12,742 511 8, 9 N/A N/A MARY LEE TRUCK 1.05 15.62 12,392 733 8, 9 N/A N/A MARY LEE TRUCK 1.07 16.22 12,340 687 8, 9 N/A N/A MARY LEE TRUCK 1.21 17.25 12,228 985 8, 9 N/A N/A MARY LEE TRUCK 1.49 16.56 12,376 149 8, 9 N/A N/A MARY LEE TRUCK 1.19 16.12 12,389 309 8, 9 N/A N/A MARY LEE TRUCK 1.00 13.34 13,011 303 8, 9 N/A N/A MARY LEE TRUCK 1.70 19.29 11,966 295 8, 9 N/A N/A MARY LEE TRUCK 1.52 15.83 12,562 308 8, 9 N/A N/A MARY LEE TRUCK 0.99 16.41 12,391 314 8, 9 N/A N/A MARY LEE TRUCK 0.90 16.71 12,261 304 8, 9 N/A N/A MARY LEE TRUCK 1.11 15.89 12,477 446 8, 9 N/A N/A MARY LEE TRUCK 1.03 15.55 12,502 513 8, 9 N/A N/A MARY LEE TRUCK 0.98 15.49 12,503 513 8, 9 N/A N/A MARY LEE TRUCK 0.96 15.29 12,549 458 8, 9 N/A N/A MARY LEE TRUCK 0.93 15.87 12,389 454 8, 9 N/A N/A MARY LEE TRUCK 0.99 16.06 12,463 456 8, 9 N/A N/A MARY LEE TRUCK 0.99 15.39 12,545 439 8, 9 N/A N/A MARY LEE TRUCK 1.00 15.30 12,518 460 8, 9 N/A N/A MARY LEE TRUCK 0.95 15.52 12,290 421 8, 9 N/A N/A MARY LEE TRUCK 0.95 15.53 12,475 443 8, 9 N/A N/A MARY LEE TRUCK 1.13 15.02 12,587 477 8, 9 N/A N/A MARY LEE TRUCK 0.96 15.12 12,547 57 8, 9 N/A N/A MARY LEE TRUCK 0.99 15.47 12,477 465 8, 9 N/A N/A MARY LEE TRUCK 0.89 14.88 12,538 481 8, 9 N/A N/A MARY LEE TRUCK 0.92 15.89 12,374 236 8, 9 N/A N/A MARY LEE TRUCK 1.30 17.33 12,217 236 8, 9 N/A N/A MARY LEE TRUCK 1.03 14.56 12,700 453 8, 9 N/A N/A MARY LEE TRUCK 0.89 15.45 12,503 297 8, 9 N/A N/A MARY LEE TRUCK 1.02 13.35 13,011 305 8, 9 N/A N/A MARY LEE TRUCK 0.92 14.55 12,715D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method

307 8, 9 N/A N/A MARY LEE TRUCK 0.93 14.21 12,774 317 8, 9 N/A N/A MARY LEE TRUCK 1.06 14.64 12,625 470 8, 9 N/A N/A MARY LEE TRUCK 1.28 13.79 12,940 471 8, 9 N/A N/A MARY LEE TRUCK 1.16 12.35 13,184 360 8, 9 N/A N/A MARY LEE TRUCK 1.07 15.28 12,608 397 8, 9 N/A N/A MARY LEE TRUCK 0.97 15.45 12,512 317 8, 9 N/A N/A MARY LEE TRUCK 0.89 14.68 12,632 393 8, 9 N/A N/A MARY LEE TRUCK 1.20 13.59 12,956 398 8, 9 N/A N/A MARY LEE TRUCK 1.02 12.59 13,197 352 8, 9 N/A N/A MARY LEE TRUCK 0.96 13.84 12,955 257 8, 9 N/A N/A MARY LEE TRUCK 0.90 15.02 12,573 263 8, 9 N/A N/A MARY LEE TRUCK 1.02 15.41 12,506 265 8, 9 N/A N/A MARY LEE TRUCK 0.85 15.19 12,569 316 8, 9 N/A N/A MARY LEE TRUCK 0.87 15.16 12,506 177 8, 9 N/A N/A MARY LEE TRUCK 1.00 15.02 12,567 318 8, 9 N/A N/A MARY LEE TRUCK 1.04 15.60 12,481 320 8, 9 N/A N/A MARY LEE TRUCK 0.90 15.70 12,448 292 8, 9 N/A N/A MARY LEE TRUCK 0.87 14.72 12,629 274 8, 9 N/A N/A MARY LEE TRUCK 1.06 14.30 12,686 312 8, 9 N/A N/A MARY LEE TRUCK 0.80 14.36 12,621 316 8, 9 N/A N/A MARY LEE TRUCK 0.89 14.95 12,530 459 8, 9 N/A N/A MARY LEE TRUCK 0.98 15.44 12,489 411 8, 9 N/A N/A MARY LEE TRUCK 1.09 15.98 12,418 386 8, 9 N/A N/A MARY LEE TRUCK 1.04 15.36 12,491 470 8, 9 N/A N/A MARY LEE TRUCK 0.89 15.67 12,505 467 8, 9 N/A N/A MARY LEE TRUCK 0.99 15.76 12,413 473 8, 9 N/A N/A MARY LEE TRUCK 0.93 15.51 12,475 408 8, 9 N/A N/A MARY LEE TRUCK 0.93 15.51 12,475 322 8, 9 N/A N/A MARY LEE TRUCK 0.82 15.13 12,534 233 8, 9 N/A N/A MARY LEE TRUCK 0.71 16.98 12,233 258 8, 9 N/A N/A MARY LEE TRUCK 0.77 16.22 12,343 260 8, 9 N/A N/A MARY LEE TRUCK 1.04 15.93 12,396 254 8, 9 N/A N/A MARY LEE TRUCK 1.01 15.26 12,504 259 8, 9 N/A N/A MARY LEE TRUCK 1.04 15.93 12,396 499 8, 9 N/A N/A MARY LEE TRUCK 1.09 15.86 12,352 501 8, 9 N/A N/A MARY LEE TRUCK 1.14 16.19 12,412 483 8, 9 N/A N/A MARY LEE TRUCK 1.11 15.75 12,436 496 8, 9 N/A N/A MARY LEE TRUCK 1.11 15.59 12,438 512 8, 9 N/A N/A MARY LEE TRUCK 0.80 17.09 12,241 509 8, 9 N/A N/A MARY LEE TRUCK 0.79 17.14 12,244 400 8, 9 N/A N/A MARY LEE TRUCK 0.85 16.14 12,395 222 8, 9 N/A N/A MARY LEE TRUCK 1.02 15.89 12,443 225 8, 9 N/A N/A MARY LEE TRUCK 1.26 16.43 12,429 223 8, 9 N/A N/A MARY LEE TRUCK 1.06 14.49 12,663 222 8, 9 N/A N/A MARY LEE TRUCK 0.86 15.01 12,544D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method

227 8, 9 N/A N/A MARY LEE TRUCK 1.34 16.50 12,368 224 8, 9 N/A N/A MARY LEE TRUCK 1.10 16.13 12,422 220 8, 9 N/A N/A MARY LEE TRUCK 0.80 14.94 12,570 223 8, 9 N/A N/A MARY LEE TRUCK 1.37 15.50 12,635 225 8, 9 N/A N/A MARY LEE TRUCK 1.20 13.96 12,771 225 8, 9 N/A N/A MARY LEE TRUCK 0.96 14.77 12,647 226 8, 9 N/A N/A MARY LEE TRUCK 1.23 16.12 12,393 223 8, 9 N/A N/A MARY LEE TRUCK 1.05 15.82 12,457 225 8, 9 N/A N/A MARY LEE TRUCK 1.07 15.58 12,498 225 8, 9 N/A N/A MARY LEE TRUCK 1.07 15.58 12,498 308 8, 9 N/A N/A MARY LEE TRUCK 1.10 16.36 12,356 311 8, 9 N/A N/A MARY LEE TRUCK 1.10 16.36 12,356 250 8, 9 N/A N/A MARY LEE TRUCK 0.94 15.43 12,538 320 8, 9 N/A N/A MARY LEE TRUCK 0.90 15.95 12,449 225 8, 9 N/A N/A MARY LEE TRUCK 0.92 15.95 12,457 311 8, 9 N/A N/A MARY LEE TRUCK 0.92 16.35 12,402 312 8, 9 N/A N/A MARY LEE TRUCK 0.86 17.17 12,213 317 8, 9 N/A N/A MARY LEE TRUCK 0.94 16.56 12,299 313 8, 9 N/A N/A MARY LEE TRUCK 0.75 16.37 12,334 315 8, 9 N/A N/A MARY LEE TRUCK 0.69 15.87 12,305 658 8, 9 N/A N/A NEW CASTLE TRUCK 1.85 15.02 12,651 665 8, 9 N/A N/A NEW CASTLE TRUCK 1.92 17.12 12,277 372 8, 9 N/A N/A NEW CASTLE TRUCK 1.56 16.77 12,337 277 8, 9 N/A N/A NEW CASTLE TRUCK 1.55 17.68 12,232 278 8, 9 N/A N/A NEW CASTLE TRUCK 2.09 17.05 12,322 284 8, 9 N/A N/A NEW CASTLE TRUCK 1.60 16.27 12,483 466 8, 9 N/A N/A NEW CASTLE TRUCK 1.61 16.76 12,362 449 8, 9 N/A N/A NEW CASTLE TRUCK 1.63 14.60 12,729 459 8, 9 N/A N/A NEW CASTLE TRUCK 2.10 16.78 12,406 423 8, 9 N/A N/A NEW CASTLE TRUCK 1.51 15.49 12,474 414 8, 9 N/A N/A NEW CASTLE TRUCK 1.03 15.27 12,627 522 8, 9 N/A N/A NEW CASTLE TRUCK 1.68 14.91 12,722 404 8, 9 N/A N/A NEW CASTLE TRUCK 1.64 14.22 12,862 372 8, 9 N/A N/A NEW CASTLE TRUCK 1.31 13.83 12,813 215 8, 9 N/A N/A NEW CASTLE TRUCK 1.43 14.34 12,725 187 8, 9 N/A N/A NEW CASTLE TRUCK 1.43 14.97 12,629 334 8, 9 N/A N/A NEW CASTLE TRUCK 1.98 14.62 12,560 533 8, 9 N/A N/A NEW CASTLE TRUCK 1.81 14.82 12,715 359 8, 9 N/A N/A NEW CASTLE TRUCK 2.06 15.07 12,697 465 8, 9 N/A N/A NEW CASTLE TRUCK 1.55 14.24 12,713 540 8, 9 N/A N/A NEW CASTLE TRUCK 1.69 15.52 12,461 451 8, 9 N/A N/A NEW CASTLE TRUCK 1.55 15.09 12,567 337 8, 9 N/A N/A NEW CASTLE TRUCK 1.55 15.09 12,567 378 8, 9 N/A N/A NEW CASTLE TRUCK 1.35 15.49 12,539 324 8, 9 N/A N/A NEW CASTLE TRUCK 1.61 15.70 12,537D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method

218 8, 9 N/A N/A NEW CASTLE TRUCK 1.61 15.70 12,537 309 8, 9 N/A N/A NEW CASTLE TRUCK 1.22 14.99 12,633 310 8, 9 N/A N/A NEW CASTLE TRUCK 1.29 15.62 12,566 316 8, 9 N/A N/A NEW CASTLE TRUCK 1.50 15.41 12,679 323 8, 9 N/A N/A NEW CASTLE TRUCK 1.75 15.60 12,517 315 8, 9 N/A N/A NEW CASTLE TRUCK 1.99 15.95 12,545 313 8, 9 N/A N/A NEW CASTLE TRUCK 1.90 14.95 12,672 308 8, 9 N/A N/A NEW CASTLE TRUCK 1.36 16.65 12,330 330 10 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.11 12.78 13,007 604 10 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.37 13.49 12,949 371 10 ALABAMA BIBB, JEFFERSON, TUSCALOOSA, WALKER AMERICAN #1, AMERICAN #2, AMERICAN #3, AMERICAN #4, BEAR CREEK TRUCK 1.59 14.09 12,900 1,346 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.26 16.63 12,443 1,448 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 15.50 12,711 1,336 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 16.38 12,553 1,381 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.19 16.48 12,407 1,358 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.07 16.71 12,645 1,317 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.12 16.11 12,687 1,400 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 15.05 12,808 1,374 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 15.95 12,686 1,423 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 15.41 12,803 1,402 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.04 15.10 12,929 1,457 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.19 16.08 12,655 1,352 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.07 16.02 12,778 1,408 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.19 15.86 12,657 1,404 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 15.88 12,639 1,413 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.23 16.79 12,507 1,419 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 15.95 12,689 1,384 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.23 15.55 12,656 1,395 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.21 15.64 12,660 1,342 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.49 14.41 12,976 1,392 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.24 15.45 12,930 1,315 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.17 14.48 13,020 1,442 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.30 14.37 13,067 1,425 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.17 14.56 12,973 1,281 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.31 15.58 12,742 1,442 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.11 14.31 12,971 1,381 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.18 15.01 12,834 1,334 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.44 14.56 12,816 1,320 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.19 11.61 13,212 1,204 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.24 12.58 13,183 1,368 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.18 12.10 13,211 1,137 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.13 12.24 13,164 1,237 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.15 12.96 13,103 1,355 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.19 13.36 13,148 1,279 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.15 13.08 12,997D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,436 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.15 13.26 13,049 1,446 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.18 12.68 13,109 1,430 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.30 11.26 13,293 1,383 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.64 12.74 12,929 1,404 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.44 12.28 13,006 1,384 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.26 10.81 13,277 1,424 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.26 11.89 13,079 1,382 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.31 12.22 13,010 1,422 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.29 11.30 13,048 1,388 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.19 13.25 13,067 1,458 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.14 14.30 12,912 1,444 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.33 14.10 12,934 1,473 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.25 17.05 12,232 1,459 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.37 18.18 11,979 1,379 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.39 11.90 13,100 1,375 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.33 14.07 12,686 1,327 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.58 18.57 11,948 1,387 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.29 16.06 12,573 1,454 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.54 16.56 12,270 1,381 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.36 18.05 11,932 1,410 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.36 13.12 13,040 1,387 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.36 14.82 12,868 1,429 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.33 14.72 12,835 1,368 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.29 15.08 12,692 1,397 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 15.33 12,679 1,430 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.23 14.43 12,776 1,431 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.42 13.46 12,774 1,413 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.38 14.97 12,631 1,425 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.34 13.04 12,942 1,442 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.45 15.69 12,250 1,461 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.35 15.63 12,555 1,373 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.42 17.15 12,359 1,470 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.50 13.03 12,966 1,467 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.34 16.21 12,566 1,423 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.58 16.83 12,358 1,393 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.49 18.09 12,183 1,419 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.49 15.66 12,490 1,348 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.51 16.54 12,322 1,392 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.62 16.36 12,368 1,484 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.35 16.25 12,439 1,450 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.39 16.55 12,322 1,425 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.52 16.41 12,331 1,496 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.44 13.36 12,932 1,424 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.44 12.98 13,042 1,467 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.30 14.87 12,558D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,445 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.29 11.79 13,112 1,450 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.36 13.63 12,833 1,366 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 14.67 12,612 1,421 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 14.04 12,722 1,417 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.45 13.35 12,952 1,418 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.33 15.17 12,544 1,401 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.31 13.52 12,938 1,400 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.55 16.38 12,371 1,464 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.33 13.37 13,035 1,414 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.47 16.40 12,417 1,456 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.35 15.11 12,781 1,458 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.42 14.46 12,792 1,405 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.29 14.19 12,802 1,277 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.36 14.16 12,683 1,401 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.37 14.23 12,655 1,310 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.44 13.79 12,771 1,395 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.41 14.77 12,568 1,324 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.29 14.78 12,678 1,303 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.35 13.98 12,767 1,379 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.42 15.68 12,499 1,385 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 15.41 12,497 1,387 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.42 15.15 12,639 1,422 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.43 15.17 12,524 1,442 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.52 15.65 12,396 1,499 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.47 15.45 12,426 1,444 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 12.35 13,003 1,430 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.26 13.65 12,652 1,389 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.29 13.11 12,857 1,442 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.30 13.80 12,748 1,368 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.28 13.43 12,861 1,469 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.38 14.05 12,659 1,319 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.30 11.88 12,882 1,345 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 12.23 12,828 1,378 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.34 12.45 12,786 1,400 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.37 13.46 12,609 1,360 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.28 14.01 12,531 1,422 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 12.95 12,662 1,407 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.57 14.07 12,303 1,405 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.55 14.99 12,481 1,423 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.47 14.36 12,614 1,402 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.54 15.35 12,477 1,433 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.58 14.48 12,563 1,447 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.52 14.68 12,508 1,432 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.30 11.60 13,037 1,423 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.36 12.72 12,917D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,419 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.41 13.86 12,633 1,385 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.33 12.72 12,825 1,472 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.35 12.55 12,885 1,451 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.27 15.47 12,402 1,403 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.27 15.25 12,484 1,412 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.34 15.22 12,468 1,440 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.28 13.94 12,692 1,251 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.34 14.48 12,603 1,383 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.51 16.61 12,230 1,404 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.45 13.96 12,660 1,404 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.43 10.56 13,146 1,449 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.49 10.33 13,097 1,415 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.52 10.30 13,165 1,481 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 12.68 12,801 1,416 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.36 12.03 12,876 1,440 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.35 11.67 12,940 1,386 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 11.00 13,076 1,389 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.34 11.22 13,073 1,422 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 10.81 12,963 1,376 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.46 11.44 12,965 1,356 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.54 10.97 13,029 1,365 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.43 9.95 13,253 1,307 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.31 12.92 12,780 1,244 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.39 11.91 12,915 1,358 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.35 12.40 12,827 1,242 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.29 11.91 12,874 1,361 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.33 11.59 12,991 1,329 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.18 11.66 13,019 1,293 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.35 12.01 12,926 1,034 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.44 12.38 12,902 1,358 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.38 12.35 12,814 1,340 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.27 12.32 12,907 1,402 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.35 11.30 13,002 1,371 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.23 11.56 12,969 1,374 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 12.24 12,869 1,268 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.36 14.51 12,510 1,220 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.41 12.24 12,892 1,316 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 13.35 12,676 1,224 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 12.52 12,811 1,398 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.39 12.41 12,848 1,280 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.34 11.29 13,058 1,404 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.47 11.92 12,919 1,348 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 12.60 12,780 1,382 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 12.35 12,816 1,394 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.36 11.37 13,010D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,080 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.37 13.37 12,678 1,409 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.34 10.99 13,066 1,431 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.50 10.98 13,002 1,427 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.43 11.64 12,959 1,384 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 11.91 12,958 1,357 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.41 11.40 13,002 1,411 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.42 10.89 13,105 1,408 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.52 13.14 12,788 1,422 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.50 12.61 12,910 1,371 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.44 12.61 12,885 1,340 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.55 13.87 12,649 1,378 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.44 12.35 12,887 1,263 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.39 12.65 12,885 1,454 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.56 13.48 12,666 1,425 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.52 14.06 12,581 1,424 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.51 14.09 12,546 1,424 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.45 13.93 12,618 1,438 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.49 13.10 12,788 1,478 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.69 14.64 12,497 1,376 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.30 13.35 12,601 1,383 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.39 14.41 12,566 1,347 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.41 13.22 12,727 1,388 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.37 13.23 12,650 1,382 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 15.31 12,362 1,341 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.37 14.16 12,621 1,245 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 12.47 12,813 1,353 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 12.04 12,890 1,326 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.32 12.36 12,856 1,473 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.39 13.40 12,661 1,390 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.53 13.58 12,608 1,357 10 ALABAMA MARION BLUE CREEK, JAGGAR BARGE 1.40 13.74 12,629 1,431 10 N/A N/A 5A, 7, 8 BARGE 0.94 16.03 12,730 1,351 10 N/A N/A 5A, 7, 8 BARGE 1.17 16.78 12,588 1,372 10 N/A N/A 5A, 7, 8 BARGE 1.12 16.81 12,601 1,427 10 N/A N/A 5A, 7, 8 BARGE 0.95 15.57 12,785 1,355 10 N/A N/A 5A, 7, 8 BARGE 0.94 16.06 12,762 1,402 10 N/A N/A 5A, 7, 8 BARGE 0.94 14.78 12,940 1,298 10 N/A N/A 5A, 7, 8 BARGE 1.21 16.52 12,717 1,298 10 N/A N/A 5A, 7, 8 BARGE 1.48 17.81 12,369 1,267 10 N/A N/A 5A, 7, 8 BARGE 1.27 16.66 12,746 1,453 10 N/A N/A 5A, 7, 8 BARGE 1.17 16.93 12,720 1,280 10 N/A N/A 5A, 7, 8 BARGE 1.23 16.63 12,643 1,298 10 N/A N/A 5A, 7, 8 BARGE 1.17 16.65 12,790 1,375 10 N/A N/A 5A, 7, 8 BARGE 1.15 15.68 12,864 1,241 10 N/A N/A 5A, 7, 8 BARGE 1.25 15.41 12,882D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,324 10 N/A N/A 5A, 7, 8 BARGE 1.12 15.53 12,901 1,288 10 N/A N/A 5A, 7, 8 BARGE 1.14 14.20 13,155 1,188 10 N/A N/A 5A, 7, 8 BARGE 1.17 15.66 12,869 1,299 10 N/A N/A 5A, 7, 8 BARGE 1.16 14.38 13,016 1,294 10 N/A N/A 5A, 7, 8 BARGE 1.20 15.32 12,752 1,358 10 N/A N/A 5A, 7, 8 BARGE 1.26 15.07 13,001 1,346 10 N/A N/A 5A, 7, 8 BARGE 1.28 15.79 12,793 1,398 10 N/A N/A 5A, 7, 8 BARGE 1.26 15.39 12,879 1,281 10 N/A N/A 5A, 7, 8 BARGE 1.25 15.34 12,935 1,403 10 N/A N/A 5A, 7, 8 BARGE 1.19 15.34 12,929 1,372 10 N/A N/A 5A, 7, 8 BARGE 1.02 16.30 12,726 1,369 10 N/A N/A 5A, 7, 8 BARGE 1.15 15.36 12,913 1,431 10 N/A N/A 5A, 7, 8 BARGE 1.11 15.62 12,860 1,396 10 N/A N/A 5A, 7, 8 BARGE 1.13 15.93 12,851 1,365 10 N/A N/A 5A, 7, 8 BARGE 1.16 15.50 12,870 1,375 10 N/A N/A 5A, 7, 8 BARGE 1.21 15.00 12,961 1,363 10 N/A N/A 5A, 7, 8 BARGE 1.26 16.86 12,628 1,340 10 N/A N/A 5A, 7, 8 BARGE 1.23 16.68 12,698 1,361 10 N/A N/A 5A, 7, 8 BARGE 1.26 15.16 12,950 1,382 10 N/A N/A 5A, 7, 8 BARGE 1.29 15.25 12,929 1,429 10 N/A N/A 5A, 7, 8 BARGE 1.31 16.00 12,805 1,396 10 N/A N/A 5A, 7, 8 BARGE 1.25 15.25 12,926 1,368 10 N/A N/A MARY LEE BARGE 1.08 15.36 12,778 1,353 10 N/A N/A MARY LEE BARGE 1.00 15.75 12,760 1,410 10 N/A N/A MARY LEE BARGE 0.99 15.55 12,633 1,431 10 N/A N/A MARY LEE BARGE 0.99 15.17 12,686 1,479 10 N/A N/A MARY LEE BARGE 1.14 15.30 12,534 1,466 10 N/A N/A MARY LEE BARGE 1.13 14.52 12,707 1,404 10 N/A N/A MARY LEE BARGE 1.25 14.39 12,674 1,444 10 N/A N/A MARY LEE BARGE 1.15 14.56 12,697 1,475 10 N/A N/A MARY LEE BARGE 0.90 15.31 12,705 1,450 10 N/A N/A MARY LEE BARGE 0.87 15.30 12,670 1,462 10 N/A N/A MARY LEE BARGE 1.01 14.94 12,709 1,453 10 N/A N/A MARY LEE BARGE 0.78 15.85 12,510 1,418 10 N/A N/A MARY LEE BARGE 0.94 15.39 12,655 1,392 10 N/A N/A MARY LEE BARGE 0.85 15.55 12,816 1,462 10 N/A N/A MARY LEE BARGE 1.11 13.16 12,961 1,433 10 N/A N/A MARY LEE BARGE 1.05 14.28 12,913 1,477 10 N/A N/A MARY LEE BARGE 1.30 17.90 12,329 1,490 10 N/A N/A MARY LEE BARGE 1.25 16.61 12,537 1,489 10 N/A N/A MARY LEE BARGE 1.23 16.29 12,436 1,511 10 N/A N/A MARY LEE BARGE 1.35 18.44 12,222 1,504 10 N/A N/A MARY LEE BARGE 1.51 18.35 12,265 1,437 10 N/A N/A MARY LEE BARGE 1.38 18.15 12,213 1,431 10 N/A N/A MARY LEE BARGE 1.58 18.06 12,285D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,441 10 N/A N/A MARY LEE BARGE 1.42 17.08 12,446 1,408 10 N/A N/A MARY LEE BARGE 1.31 18.62 12,221 1,398 10 N/A N/A MARY LEE BARGE 1.50 18.66 12,099 1,424 10 N/A N/A MARY LEE BARGE 1.25 20.02 11,958 1,459 10 N/A N/A MARY LEE BARGE 1.50 21.10 11,758 1,445 10 N/A N/A MARY LEE BARGE 1.31 19.75 11,898 1,449 10 N/A N/A MARY LEE BARGE 1.34 19.40 12,033 1,423 10 N/A N/A MARY LEE BARGE 1.50 20.00 11,921 1,455 10 N/A N/A MARY LEE BARGE 1.38 17.60 12,256 1,452 10 N/A N/A MARY LEE BARGE 1.49 20.25 11,881 1,353 10 N/A N/A MARY LEE BARGE 1.55 17.84 12,238 1,425 10 N/A N/A MARY LEE BARGE 1.49 17.71 12,273 1,398 10 N/A N/A MARY LEE BARGE 1.78 19.20 11,896 1,461 10 N/A N/A MARY LEE BARGE 1.14 14.15 12,892 1,417 10 N/A N/A MARY LEE BARGE 1.43 16.35 12,430 1,391 10 N/A N/A MARY LEE BARGE 1.31 16.42 12,526 1,438 10 N/A N/A MARY LEE BARGE 1.23 16.61 12,487 1,428 10 N/A N/A MARY LEE BARGE 1.26 15.17 12,784 1,441 10 N/A N/A MARY LEE BARGE 1.26 16.94 12,317 1,467 10 N/A N/A MARY LEE BARGE 1.21 17.19 12,335 1,395 10 N/A N/A MARY LEE BARGE 1.25 17.78 12,334 1,489 10 N/A N/A MARY LEE BARGE 1.03 15.34 12,791 1,512 10 N/A N/A MARY LEE BARGE 1.14 13.59 12,941 1,441 10 N/A N/A MARY LEE BARGE 0.96 16.62 12,534 1,504 10 N/A N/A MARY LEE BARGE 1.17 16.51 12,557 1,407 10 N/A N/A MARY LEE BARGE 1.18 15.62 12,579 1,479 10 N/A N/A MARY LEE BARGE 1.29 15.73 12,587 1,375 10 N/A N/A MARY LEE BARGE 1.20 15.28 12,683 1,435 10 N/A N/A MARY LEE BARGE 1.32 16.02 12,555 1,276 10 N/A N/A MARY LEE BARGE 1.54 13.39 13,043 1,399 10 N/A N/A MARY LEE BARGE 1.05 14.60 12,920 1,401 10 N/A N/A MARY LEE BARGE 1.12 13.12 13,277 1,466 10 N/A N/A MARY LEE BARGE 1.14 13.90 13,103 1,435 10 N/A N/A MARY LEE BARGE 1.26 13.18 13,158 1,397 10 N/A N/A MARY LEE BARGE 1.18 13.27 13,232 1,412 10 N/A N/A MARY LEE BARGE 1.25 12.07 13,366 1,394 10 N/A N/A MARY LEE BARGE 1.08 15.15 12,887 1,348 10 N/A N/A MARY LEE BARGE 1.15 11.94 13,458 1,432 10 N/A N/A MARY LEE BARGE 1.12 12.96 13,250 1,469 10 N/A N/A MARY LEE BARGE 1.30 16.14 12,468 1,401 10 N/A N/A MARY LEE BARGE 1.35 15.28 12,630 1,451 10 N/A N/A MARY LEE BARGE 1.21 14.97 12,729 1,483 10 N/A N/A MARY LEE BARGE 1.10 12.67 13,137 1,515 10 N/A N/A MARY LEE BARGE 1.14 13.39 13,028 1,420 10 N/A N/A MARY LEE BARGE 1.00 14.40 12,938D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,453 10 COLOMBIA GRAN MADRE TRUCK 0.58 6.76 13,018 1,404 10 COLOMBIA GRAN MADRE TRUCK 0.58 6.94 13,044 1,752 10 ALABAMA WALKER MARY LEE TRUCK 0.87 13.72 12,363 834 10 ALABAMA WALKER MARY LEE TRUCK 0.87 14.20 12,705 425 10 ALABAMA WALKER MARY LEE TRUCK 0.88 14.29 12,610 958 10 ALABAMA WALKER MARY LEE TRUCK 0.89 15.30 12,410 2,484 10 ALABAMA WALKER MARY LEE TRUCK 1.10 16.34 12,308 2,314 10 ALABAMA WALKER MARY LEE TRUCK 1.42 13.63 12,743 1,264 10 ALABAMA WALKER MARY LEE TRUCK 0.77 16.63 12,145 2,058 10 ALABAMA WALKER MARY LEE TRUCK 1.53 14.67 12,569 1,361 10 ALABAMA WALKER MARY LEE TRUCK 0.98 15.19 12,419 1,446 10 ALABAMA WALKER MARY LEE TRUCK 0.78 14.20 12,535 1,886 10 ALABAMA WALKER MARY LEE TRUCK 0.73 14.04 12,632 1,582 10 ALABAMA WALKER MARY LEE TRUCK 0.75 15.33 12,250 1,229 10 ALABAMA WALKER MARY LEE TRUCK 0.82 17.84 11,866 1,525 10 ALABAMA WALKER MARY LEE TRUCK 1.11 14.88 12,392 1,536 10 ALABAMA WALKER MARY LEE TRUCK 0.67 16.60 12,192 1,614 10 ALABAMA WALKER MARY LEE TRUCK 0.65 14.23 12,452 1,435 10 ALABAMA WALKER MARY LEE TRUCK 0.62 15.31 12,350 1,614 10 ALABAMA WALKER MARY LEE TRUCK 0.59 15.03 12,366 1,211 10 ALABAMA WALKER MARY LEE TRUCK 0.58 15.23 12,412 1,336 10 ALABAMA WALKER MARY LEE TRUCK 0.64 14.18 12,501 1,485 10 ALABAMA WALKER MARY LEE TRUCK 0.60 15.77 12,305 1,687 10 ALABAMA WALKER MARY LEE TRUCK 0.60 16.03 12,276 1,163 10 ALABAMA WALKER MARY LEE TRUCK 0.61 15.76 12,368 1,177 10 ALABAMA WALKER MARY LEE TRUCK 0.75 15.83 12,401 1,458 10 ALABAMA WALKER MARY LEE TRUCK 0.77 15.32 12,423 1,668 10 ALABAMA WALKER MARY LEE TRUCK 0.81 14.96 12,493 1,262 10 ALABAMA WALKER MARY LEE TRUCK 0.72 15.27 12,478 1,515 10 ALABAMA WALKER MARY LEE TRUCK 0.73 14.46 12,640 1,285 10 ALABAMA WALKER MARY LEE TRUCK 0.86 13.12 12,948 1,960 10 ALABAMA WALKER MARY LEE TRUCK 0.74 12.28 13,039 1,198 10 ALABAMA WALKER MARY LEE TRUCK 0.68 15.17 12,395 1,602 10 ALABAMA WALKER MARY LEE TRUCK 0.64 12.14 12,885 1,343 10 ALABAMA WALKER MARY LEE TRUCK 0.57 13.24 12,756 1,161 10 ALABAMA WALKER MARY LEE TRUCK 0.62 14.82 12,517 1,523 10 ALABAMA WALKER MARY LEE TRUCK 0.62 16.05 12,320 1,747 10 ALABAMA WALKER MARY LEE TRUCK 0.59 16.05 12,283 1,910 10 ALABAMA WALKER MARY LEE TRUCK 0.64 14.90 12,584 1,904 10 ALABAMA WALKER MARY LEE TRUCK 0.66 14.39 12,569 1,320 10 ALABAMA WALKER MARY LEE TRUCK 0.69 14.47 12,508 1,816 10 ALABAMA WALKER MARY LEE TRUCK 0.80 14.46 12,559 2,329 10 ALABAMA WALKER MARY LEE TRUCK 0.64 14.82 12,490 1,403 10 ALABAMA WALKER MARY LEE TRUCK 0.70 15.00 12,404 2,225 10 ALABAMA WALKER MARY LEE TRUCK 0.67 14.52 12,485D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,458 10 ALABAMA WALKER MARY LEE TRUCK 0.69 13.58 12,618 670 10 ALABAMA WALKER MARY LEE TRUCK 0.59 16.10 12,268 2,069 10 ALABAMA WALKER MARY LEE TRUCK 0.69 15.70 12,319 1,645 10 ALABAMA WALKER MARY LEE TRUCK 0.65 15.25 12,456 1,713 10 ALABAMA WALKER MARY LEE TRUCK 0.82 16.21 12,281 949 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.22 15.28 12,473 596 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.17 15.85 12,420 673 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.39 15.34 12,550 530 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.09 14.88 12,550 631 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.08 15.20 12,522 432 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.26 15.22 12,524 519 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.19 15.27 12,480 507 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.23 15.18 12,513 508 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.12 15.45 12,533 639 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.09 16.03 12,320 526 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 0.94 15.57 12,466 637 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.06 15.95 12,334 604 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.02 16.09 12,291 625 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.19 15.67 12,511 628 10 WEST VIRGINIA KANAWHA VARIOUS BARGE 1.59 15.90 12,417 604 10 N/A N/A MARY LEE BARGE 1.13 15.99 12,305 555 10 N/A N/A MARY LEE BARGE 1.25 13.41 12,884 376 10 N/A N/A MARY LEE BARGE 1.55 13.16 12,871 548 10 N/A N/A MARY LEE BARGE 1.26 14.05 12,700 561 10 N/A N/A MARY LEE BARGE 1.12 14.88 12,581 1,051 10 N/A N/A MARY LEE BARGE 2.14 14.36 12,922 912 10 N/A N/A MARY LEE BARGE 1.12 14.88 12,581 976 10 N/A N/A MARY LEE BARGE 0.87 15.90 12,210 1,122 10 N/A N/A MARY LEE BARGE 0.74 15.05 12,648 871 10 N/A N/A MARY LEE BARGE 0.90 14.87 12,501 1,424 10 N/A N/A MARY LEE BARGE 0.78 15.29 12,471 831 10 ALABAMA MARION BLUE CREEK BARGE 1.09 11.94 12,818 282 10 ALABAMA MARION BLUE CREEK BARGE 1.40 14.93 12,514 231 10 ALABAMA MARION BLUE CREEK BARGE 1.10 13.51 12,807 608 10 ALABAMA MARION BLUE CREEK BARGE 1.29 13.98 12,573 461 10 ALABAMA MARION BLUE CREEK BARGE 1.46 12.59 12,841 437 10 ALABAMA MARION BLUE CREEK BARGE 1.32 11.63 12,959 411 10 ALABAMA MARION BLUE CREEK BARGE 1.21 12.56 12,827 338 10 ALABAMA MARION BLUE CREEK BARGE 1.21 13.86 12,672 257 10 ALABAMA MARION BLUE CREEK BARGE 1.31 10.49 13,180 51 10 ALABAMA MARION BLUE CREEK BARGE 1.41 13.05 12,813 355 10 ALABAMA MARION BLUE CREEK BARGE 1.47 11.60 12,999 1,373 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.94 16.43 12,749 1,312 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.89 15.77 12,931 1,406 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.23 16.19 12,621D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,369 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.97 15.25 12,953 1,510 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 14.56 12,909 1,459 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 13.95 13,016 1,366 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.28 15.60 12,665 1,442 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 15.18 12,812 1,434 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 15.28 12,872 1,384 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.16 14.59 12,910 1,437 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.09 12.92 13,241 1,431 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.09 13.29 13,195 1,415 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 13.45 13,157 1,450 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 13.89 13,046 1,439 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.11 12.83 13,263 1,380 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 14.06 13,022 1,425 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.07 14.09 13,123 1,424 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 14.31 12,984 1,442 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.16 13.68 13,124 1,473 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 13.71 13,064 1,404 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.99 14.37 13,088 1,475 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 14.27 12,991 1,305 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.05 15.34 12,831 1,397 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.88 15.60 12,899 1,421 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.88 15.68 12,921 1,403 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.08 15.54 12,843 1,460 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.05 15.56 12,801 1,431 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.11 14.48 12,898 1,438 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.09 15.18 12,928 1,449 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.10 14.19 13,053 1,460 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 14.43 13,038 1,430 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 15.18 12,863 1,436 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.16 14.28 12,903 1,457 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.14 14.37 12,971 1,380 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.88 15.20 13,031 1,351 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.82 13.84 13,237 1,383 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.79 14.19 13,223 1,439 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.92 15.01 13,003 1,333 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.02 15.48 12,860 1,389 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.04 14.99 12,936 1,497 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.00 14.38 12,992 1,438 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.07 14.13 13,028 1,524 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.05 14.03 12,951 1,433 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.02 14.57 12,954 1,499 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.00 14.92 12,939 1,423 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.07 15.43 12,803 1,419 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.96 14.15 12,839 1,387 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.01 13.50 13,205D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,418 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.09 14.93 12,899 1,395 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.08 15.27 12,868 1,413 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.05 14.86 13,006 1,422 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.10 14.61 12,977 1,415 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.74 12.44 13,547 1,408 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.05 13.94 13,124 1,358 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.77 12.78 13,499 1,419 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.97 12.87 13,455 1,443 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.01 13.62 13,230 1,403 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.95 13.39 13,293 1,490 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.14 14.84 12,972 1,472 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.09 15.06 12,944 1,473 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.08 14.93 12,978 1,439 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.05 15.09 12,937 1,584 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.04 14.76 13,051 1,448 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.12 14.65 13,047 1,438 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.25 14.96 12,932 1,431 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 14.73 12,970 1,439 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 14.85 12,970 1,433 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.08 15.00 12,920 1,460 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.00 14.13 13,169 1,398 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.93 14.21 13,087 1,410 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.08 15.26 12,918 1,462 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.04 14.75 12,996 1,470 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 15.48 12,801 1,437 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 15.12 12,850 1,462 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.09 15.26 12,861 1,444 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 15.46 12,874 1,439 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.14 14.16 13,064 1,461 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.21 15.07 12,866 1,417 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.16 15.12 12,937 1,424 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 14.86 12,920 1,442 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 14.95 12,935 1,451 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.10 14.90 12,939 1,415 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 15.82 12,824 1,423 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 14.80 12,963 1,462 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.25 15.42 12,834 1,432 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.24 14.14 13,048 1,436 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.21 14.47 12,979 1,443 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 14.82 12,954 1,430 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 15.97 12,782 1,427 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 15.97 12,782 1,437 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 15.97 12,782 1,412 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 15.97 12,782 1,378 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 15.97 12,782D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,412 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 15.97 12,782 1,451 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 16.81 12,703 1,473 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.11 17.67 12,511 1,443 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 17.13 12,639 1,472 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 16.54 12,697 1,461 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.08 17.40 12,567 1,467 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.19 16.58 12,675 1,493 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.14 14.31 13,099 1,449 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 15.72 12,891 1,514 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.12 14.85 13,017 1,482 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.16 15.60 12,940 1,459 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 15.17 12,936 1,423 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 15.57 12,854 1,483 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.99 16.35 12,780 1,443 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 15.90 12,802 1,477 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.01 15.90 12,932 1,450 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.07 15.81 12,893 1,459 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.12 17.01 12,635 1,404 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.11 17.60 12,602 1,453 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.32 15.27 12,891 1,447 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.25 14.95 12,850 1,449 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.24 16.41 12,689 1,423 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.24 15.44 12,884 1,444 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.61 14.66 13,009 1,448 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.67 15.22 12,911 1,403 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.45 13.64 13,176 1,412 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.38 13.71 13,169 1,426 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.46 13.71 13,201 1,429 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.39 14.69 13,008 1,442 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.53 13.54 13,194 1,407 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.46 13.55 13,170 1,413 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.19 13.89 13,163 1,428 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 13.99 13,178 1,443 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 15.18 12,984 1,446 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.28 13.95 13,124 1,392 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.23 15.09 12,985 1,481 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 16.32 12,793 1,404 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.23 15.78 12,893 1,397 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.27 15.36 12,917 1,428 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.14 14.69 13,050 1,426 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.07 15.73 12,891 1,405 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.08 15.26 13,031 1,429 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.27 15.04 12,971 1,467 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.25 15.60 12,940 1,394 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 17.01 12,707D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,464 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.16 16.63 12,715 1,468 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.19 16.02 12,818 1,440 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.24 16.31 12,800 1,463 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 16.41 12,756 1,439 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.19 15.79 12,866 1,443 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 15.99 12,915 1,460 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.16 16.11 12,837 1,465 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 16.46 12,780 1,425 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.12 17.08 12,734 1,481 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 17.14 12,680 1,443 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.36 15.13 12,975 1,446 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.34 14.86 13,029 1,450 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 14.82 12,952 1,407 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 16.29 12,776 1,420 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.32 14.53 13,022 1,407 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.40 15.25 12,941 1,396 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.31 15.73 12,907 1,421 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.24 15.63 12,861 1,403 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.33 15.41 12,925 1,395 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.36 13.92 13,179 1,402 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.34 14.57 13,043 1,401 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.29 15.49 12,879 1,421 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.26 15.17 12,966 1,447 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.21 15.43 12,849 1,371 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.14 15.59 12,893 1,382 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 15.81 12,869 1,385 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.16 15.96 12,810 1,406 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.24 16.27 12,762 1,383 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.15 16.82 12,659 1,395 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.11 16.20 12,728 1,419 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.10 17.18 12,595 1,383 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.10 16.85 12,632 1,412 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.11 16.18 12,731 1,400 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 16.84 12,602 1,359 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 15.48 12,834 1,349 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 14.74 12,980 1,370 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.11 15.13 12,951 1,269 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 15.22 12,914 1,449 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.21 15.65 12,801 1,388 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 15.55 12,830 1,392 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.12 16.14 12,708 1,394 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 15.28 12,835 1,398 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 15.02 12,941 1,285 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 15.94 12,839 1,419 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 15.09 12,915D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,121 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 15.23 12,937 1,446 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.31 14.87 12,980 1,448 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.46 14.88 12,957 1,411 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.25 14.72 13,051 1,462 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 15.20 12,929 1,453 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.08 16.43 12,718 1,505 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.14 16.35 12,752 1,449 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.19 14.60 13,086 1,446 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.18 14.89 13,033 1,446 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.26 14.82 12,965 1,463 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 14.66 13,005 1,445 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 14.91 13,012 1,407 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.34 15.25 12,859 1,458 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.17 14.57 13,131 1,422 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.35 13.75 13,097 1,406 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.29 14.36 12,990 1,511 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.35 14.65 12,928 1,443 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.19 15.09 12,949 1,439 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.16 15.15 12,936 1,432 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 15.20 12,914 1,409 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.27 15.17 12,880 1,464 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.23 16.29 12,703 1,425 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.11 17.64 12,536 1,401 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 0.99 18.14 12,460 1,414 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.27 14.55 13,039 1,384 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.09 18.13 12,465 1,454 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.32 14.91 13,002 1,484 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.27 14.89 13,040 1,426 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.27 14.89 12,991 1,480 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.31 14.86 13,009 1,442 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.28 15.28 12,946 1,414 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.29 15.53 12,924 1,452 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 15.64 12,939 1,449 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.13 16.96 12,735 1,478 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.28 14.46 13,161 1,489 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.26 14.91 13,012 1,467 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 16.06 12,845 1,409 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.26 13.93 13,203 1,401 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.28 14.34 13,149 1,178 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.21 15.06 13,018 1,384 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.27 13.33 13,336 1,356 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.20 14.95 13,013 1,408 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.23 14.60 13,076 1,424 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.22 15.26 12,944 1,392 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.26 15.65 12,891D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,403 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.32 14.74 13,004 1,423 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.32 15.54 12,879 1,406 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.37 15.28 12,943 1,420 10 ALABAMA JEFFERSON, WALKER BLUE CREEK BARGE 1.31 15.39 12,913 1,400 10 N/A N/A BROOKWOOD BARGE 1.22 14.60 13,032 1,355 10 N/A N/A BROOKWOOD BARGE 1.08 15.49 12,832 1,413 10 N/A N/A BROOKWOOD BARGE 1.16 14.61 13,036 1,350 10 N/A N/A BROOKWOOD BARGE 1.11 15.05 12,852 1,418 10 N/A N/A BROOKWOOD BARGE 1.10 15.00 12,987 1,358 10 N/A N/A BROOKWOOD BARGE 1.18 15.31 12,965 1,362 10 N/A N/A BROOKWOOD BARGE 1.05 12.70 13,284 1,377 10 N/A N/A BROOKWOOD BARGE 1.30 14.05 13,153 1,430 10 N/A N/A BROOKWOOD BARGE 1.23 14.07 13,145 1,385 10 N/A N/A BROOKWOOD BARGE 1.19 13.45 13,110 1,400 10 N/A N/A BROOKWOOD BARGE 1.09 13.55 13,115 1,344 10 N/A N/A BROOKWOOD BARGE 1.04 13.34 13,002 1,347 10 N/A N/A BROOKWOOD BARGE 1.06 13.26 13,202 1,377 10 N/A N/A BROOKWOOD BARGE 1.06 13.09 13,265 1,420 10 N/A N/A BROOKWOOD BARGE 1.10 13.93 13,141 1,432 10 N/A N/A BROOKWOOD BARGE 1.06 13.61 13,130 1,401 10 N/A N/A BROOKWOOD BARGE 1.07 12.63 13,270 1,406 10 N/A N/A BROOKWOOD BARGE 1.04 12.79 13,265 1,375 10 N/A N/A BROOKWOOD BARGE 1.15 14.24 12,966 1,332 10 N/A N/A BROOKWOOD BARGE 1.18 14.04 13,109 1,355 10 N/A N/A BROOKWOOD BARGE 1.19 15.47 12,814 1,418 10 N/A N/A BROOKWOOD BARGE 1.17 14.28 13,066 1,362 10 N/A N/A BROOKWOOD BARGE 1.31 14.19 13,125 1,313 10 N/A N/A BROOKWOOD BARGE 1.10 13.94 13,184 1,381 10 N/A N/A BROOKWOOD BARGE 1.10 12.22 13,525 1,460 10 N/A N/A BROOKWOOD BARGE 1.13 12.49 13,411 1,387 10 N/A N/A BROOKWOOD BARGE 1.09 12.69 13,170 1,455 10 N/A N/A BROOKWOOD BARGE 1.08 13.13 13,352 1,377 10 N/A N/A BROOKWOOD BARGE 1.15 13.75 13,170 1,351 10 N/A N/A BROOKWOOD BARGE 1.23 14.03 13,086 1,373 10 N/A N/A BROOKWOOD BARGE 1.19 12.79 13,314 1,345 10 N/A N/A BROOKWOOD BARGE 1.17 13.05 13,346 1,377 10 N/A N/A BROOKWOOD BARGE 1.17 13.37 13,204 1,462 10 N/A N/A BROOKWOOD BARGE 1.18 14.42 13,012 1,339 10 N/A N/A BROOKWOOD BARGE 1.25 13.51 13,210 1,416 10 N/A N/A BROOKWOOD BARGE 1.16 12.80 13,336 1,397 10 N/A N/A BROOKWOOD BARGE 1.51 15.75 12,868 1,439 10 N/A N/A BROOKWOOD BARGE 1.14 13.94 13,158 1,358 10 N/A N/A BROOKWOOD BARGE 1.29 13.47 13,314 1,312 10 N/A N/A BROOKWOOD BARGE 1.38 14.47 13,082 1,325 10 N/A N/A BROOKWOOD BARGE 1.29 13.74 13,196D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,379 10 N/A N/A BROOKWOOD BARGE 1.36 14.12 13,267 2,370 10 N/A N/A MARY LEE TRUCK 0.74 17.00 12,115 1,340 10 N/A N/A MARY LEE TRUCK 0.72 16.12 12,227 1,118 10 N/A N/A MARY LEE TRUCK 0.69 13.71 12,658 1,145 10 N/A N/A MARY LEE TRUCK 0.69 13.74 12,678 1,782 10 N/A N/A MARY LEE TRUCK 1.06 14.41 12,668 987 10 N/A N/A MARY LEE TRUCK 0.76 12.33 12,803 1,066 10 N/A N/A MARY LEE TRUCK 0.84 14.85 12,443 978 10 N/A N/A MARY LEE TRUCK 1.03 14.83 12,482 969 10 N/A N/A MARY LEE TRUCK 0.93 14.95 12,506 943 10 N/A N/A MARY LEE TRUCK 0.77 14.95 12,451 963 10 N/A N/A MARY LEE TRUCK 0.72 15.38 12,317 1,366 10 N/A N/A MARY LEE TRUCK 1.63 17.29 12,246 1,431 10 N/A N/A MARY LEE TRUCK 1.10 15.51 12,454 1,690 10 N/A N/A MARY LEE TRUCK 0.72 15.59 12,401 1,692 10 N/A N/A MARY LEE TRUCK 0.91 14.50 12,656 1,403 10 N/A N/A MARY LEE TRUCK 0.86 15.21 12,440 1,342 10 N/A N/A MARY LEE TRUCK 0.82 16.16 12,206 1,227 10 N/A N/A MARY LEE TRUCK 0.81 14.52 12,576 1,734 10 N/A N/A MARY LEE TRUCK 0.70 14.81 12,429 1,799 10 N/A N/A MARY LEE TRUCK 0.81 13.57 12,853 1,891 10 N/A N/A MARY LEE TRUCK 0.90 11.88 13,363 1,739 10 N/A N/A MARY LEE TRUCK 0.83 13.15 12,815 1,524 10 N/A N/A MARY LEE TRUCK 0.80 13.66 12,797 1,492 10 N/A N/A MARY LEE TRUCK 0.92 14.38 12,694 1,522 10 N/A N/A MARY LEE TRUCK 0.83 14.91 12,589 1,598 10 N/A N/A MARY LEE TRUCK 0.73 14.50 12,560 1,297 10 N/A N/A MARY LEE TRUCK 0.85 14.65 12,588 1,127 10 N/A N/A MARY LEE TRUCK 0.73 14.99 12,507 1,433 10 N/A N/A MARY LEE TRUCK 0.64 16.15 12,367 1,713 10 N/A N/A MARY LEE TRUCK 0.90 12.89 13,112 2,024 10 N/A N/A MARY LEE TRUCK 0.88 13.76 12,741 1,690 10 N/A N/A MARY LEE TRUCK 1.23 13.41 12,989 1,309 10 N/A N/A MARY LEE TRUCK 1.18 12.85 13,105 2,049 10 N/A N/A MARY LEE TRUCK 0.86 13.54 12,903 1,971 10 N/A N/A MARY LEE TRUCK 1.08 12.21 13,201 2,252 10 N/A N/A MARY LEE TRUCK 1.00 12.60 13,123 965 10 N/A N/A MARY LEE TRUCK 0.90 12.66 13,152 214 10 N/A N/A MARY LEE TRUCK 1.00 15.85 12,363 639 10 N/A N/A MARY LEE TRUCK 1.10 9.68 13,835 554 10 N/A N/A MARY LEE TRUCK 1.02 12.02 13,107 1,235 10 N/A N/A MARY LEE TRUCK 0.70 15.66 12,323 1,265 10 N/A N/A MARY LEE TRUCK 0.74 13.27 12,758 1,206 10 N/A N/A MARY LEE TRUCK 0.61 14.49 12,463 1,671 10 N/A N/A MARY LEE TRUCK 0.94 11.64 13,381D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,734 10 N/A N/A MARY LEE TRUCK 1.02 13.43 12,898 2,279 10 N/A N/A MARY LEE TRUCK 0.95 13.87 12,695 1,552 10 N/A N/A MARY LEE TRUCK 0.84 14.05 12,692 1,478 10 N/A N/A MARY LEE TRUCK 0.92 13.79 12,780 1,135 10 N/A N/A MARY LEE TRUCK 0.92 12.24 13,085 1,098 10 N/A N/A MARY LEE TRUCK 0.94 13.42 12,875 1,044 10 N/A N/A MARY LEE TRUCK 0.90 14.04 12,766 1,229 10 N/A N/A MARY LEE TRUCK 0.92 12.39 13,057 1,086 10 N/A N/A MARY LEE TRUCK 0.97 15.35 12,703 996 10 N/A N/A MARY LEE TRUCK 0.97 14.41 12,835 653 10 N/A N/A MARY LEE TRUCK 0.83 17.41 12,110 781 10 N/A N/A MARY LEE TRUCK 1.39 16.52 12,303 1,507 10 N/A N/A MARY LEE TRUCK 0.83 14.05 12,606 1,546 10 N/A N/A MARY LEE TRUCK 0.73 15.22 12,426 1,214 10 N/A N/A MARY LEE TRUCK 0.99 12.49 13,167 1,247 10 N/A N/A MARY LEE TRUCK 0.98 12.92 13,087 1,140 10 N/A N/A MARY LEE TRUCK 0.93 14.72 12,739 1,322 10 N/A N/A MARY LEE TRUCK 0.63 15.14 12,464 1,027 10 N/A N/A MARY LEE TRUCK 0.76 14.76 12,510 1,161 10 N/A N/A MARY LEE TRUCK 1.64 15.97 12,712 1,579 10 N/A N/A MARY LEE TRUCK 0.90 14.27 12,602 1,442 10 N/A N/A MARY LEE TRUCK 0.77 15.06 12,521 1,282 10 N/A N/A MARY LEE TRUCK 0.81 14.98 12,531 1,556 10 N/A N/A MARY LEE TRUCK 0.74 15.53 12,477 580 10 N/A N/A MARY LEE TRUCK 0.80 13.95 12,811 1,313 10 N/A N/A MARY LEE TRUCK 0.78 15.35 12,561 1,701 10 N/A N/A MARY LEE TRUCK 0.65 15.15 12,450 1,224 10 N/A N/A MARY LEE TRUCK 0.84 15.22 12,514 1,449 10 N/A N/A MARY LEE TRUCK 0.75 16.07 12,394 1,589 10 N/A N/A MARY LEE TRUCK 0.73 15.14 12,521 736 10 N/A N/A MARY LEE TRUCK 0.68 14.57 12,540 1,514 10 N/A N/A MARY LEE TRUCK 1.09 13.31 12,993 1,635 10 N/A N/A MARY LEE TRUCK 0.93 16.30 12,455 1,240 10 N/A N/A MARY LEE TRUCK 0.77 15.31 12,469 1,975 10 N/A N/A MARY LEE TRUCK 0.92 12.14 13,342 1,436 10 N/A N/A MARY LEE TRUCK 1.01 16.04 12,488 1,824 10 N/A N/A MARY LEE TRUCK 1.14 13.15 13,121 1,785 10 N/A N/A MARY LEE TRUCK 0.99 16.06 12,514 1,732 10 N/A N/A MARY LEE TRUCK 0.89 14.76 12,711 1,798 10 N/A N/A MARY LEE TRUCK 0.78 14.58 12,539 2,057 10 N/A N/A MARY LEE TRUCK 0.72 15.10 12,534 1,929 10 N/A N/A MARY LEE TRUCK 0.64 15.63 12,454 1,939 10 N/A N/A MARY LEE TRUCK 0.78 15.53 12,405 2,346 10 N/A N/A MARY LEE TRUCK 0.77 15.89 12,356 2,144 10 N/A N/A MARY LEE TRUCK 0.71 15.26 12,539D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 2,613 10 N/A N/A MARY LEE TRUCK 0.71 15.71 12,463 2,520 10 N/A N/A MARY LEE TRUCK 0.95 14.85 12,557 1,278 10 N/A N/A MARY LEE TRUCK 1.01 14.61 12,695 1,281 10 N/A N/A MARY LEE TRUCK 1.12 14.29 12,713 1,389 10 N/A N/A MARY LEE TRUCK 0.87 13.85 12,744 1,272 10 N/A N/A MARY LEE TRUCK 0.94 16.44 12,322 1,634 10 N/A N/A MARY LEE TRUCK 0.96 15.15 12,513 1,762 10 N/A N/A MARY LEE TRUCK 0.80 15.71 12,325 1,809 10 N/A N/A MARY LEE TRUCK 0.95 15.33 12,425 1,817 10 N/A N/A MARY LEE TRUCK 0.73 15.67 12,449 1,897 10 N/A N/A MARY LEE TRUCK 0.75 16.02 12,359 1,531 10 N/A N/A MARY LEE TRUCK 0.89 15.34 12,537 1,831 10 N/A N/A MARY LEE TRUCK 0.81 15.31 12,484 1,729 10 N/A N/A MARY LEE TRUCK 0.69 15.53 12,485 1,861 10 N/A N/A MARY LEE TRUCK 0.71 15.23 12,488 1,870 10 N/A N/A MARY LEE TRUCK 0.73 15.90 12,417 1,818 10 N/A N/A MARY LEE TRUCK 0.62 15.66 12,415 1,714 10 N/A N/A MARY LEE TRUCK 0.86 14.17 12,709 1,764 10 N/A N/A MARY LEE TRUCK 0.83 15.29 12,557 1,255 10 N/A N/A MARY LEE TRUCK 0.73 14.49 12,621 1,293 10 N/A N/A MARY LEE TRUCK 0.82 14.40 12,695 1,318 10 N/A N/A MARY LEE TRUCK 0.65 14.81 12,499 1,327 10 N/A N/A MARY LEE TRUCK 0.75 15.21 12,497 1,280 10 N/A N/A MARY LEE TRUCK 0.74 16.05 12,256 1,281 10 N/A N/A MARY LEE TRUCK 0.76 14.51 12,575 1,281 10 N/A N/A MARY LEE TRUCK 0.57 15.09 12,475 1,374 10 N/A N/A MARY LEE TRUCK 0.77 14.68 12,572 1,286 10 N/A N/A MARY LEE TRUCK 0.83 14.42 12,597 1,289 10 N/A N/A MARY LEE TRUCK 0.64 45.06 12,416 1,287 10 N/A N/A MARY LEE TRUCK 0.85 14.91 12,493 1,372 10 N/A N/A MARY LEE TRUCK 0.80 13.91 12,694 1,389 10 N/A N/A MARY LEE TRUCK 0.88 14.27 12,632 1,397 10 N/A N/A MARY LEE TRUCK 0.81 14.39 12,638 1,294 10 INDIANA GIBSON INDIANA #5 BARGE 1.19 7.49 13,564 1,293 10 INDIANA GIBSON INDIANA #5 BARGE 1.15 7.11 13,604 1,277 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.21 13,613 1,280 10 INDIANA GIBSON INDIANA #5 BARGE 1.19 7.16 13,611 1,283 10 INDIANA GIBSON INDIANA #5 BARGE 1.23 7.30 13,597 1,290 10 INDIANA GIBSON INDIANA #5 BARGE 1.21 7.08 13,600 1,284 10 INDIANA GIBSON INDIANA #5 BARGE 1.16 7.10 13,580 1,288 10 INDIANA GIBSON INDIANA #5 BARGE 1.19 7.21 13,608 1,264 10 INDIANA GIBSON INDIANA #5 BARGE 1.18 7.14 13,641 1,266 10 INDIANA GIBSON INDIANA #5 BARGE 1.17 7.17 13,623 1,268 10 INDIANA GIBSON INDIANA #5 BARGE 1.20 7.17 13,630 1,277 10 INDIANA GIBSON INDIANA #5 BARGE 1.20 7.12 13,615D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,263 10 INDIANA GIBSON INDIANA #5 BARGE 1.20 7.25 13,586 1,271 10 INDIANA GIBSON INDIANA #5 BARGE 1.20 7.22 13,604 1,272 10 INDIANA GIBSON INDIANA #5 BARGE 1.19 7.19 13,647 1,262 10 INDIANA GIBSON INDIANA #5 BARGE 1.21 7.05 13,621 1,355 10 INDIANA GIBSON INDIANA #5 BARGE 1.28 7.08 13,626 1,324 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.01 13,662 1,327 10 INDIANA GIBSON INDIANA #5 BARGE 1.30 7.30 13,501 1,277 10 INDIANA GIBSON INDIANA #5 BARGE 1.24 7.07 13,597 1,300 10 INDIANA GIBSON INDIANA #5 BARGE 1.23 7.08 13,585 1,318 10 INDIANA GIBSON INDIANA #5 BARGE 1.29 7.15 13,570 1,302 10 INDIANA GIBSON INDIANA #5 BARGE 1.22 7.12 13,363 1,313 10 INDIANA GIBSON INDIANA #5 BARGE 1.23 7.08 13,665 1,287 10 INDIANA GIBSON INDIANA #5 BARGE 1.23 7.24 13,544 1,302 10 INDIANA GIBSON INDIANA #5 BARGE 1.24 7.45 13,572 1,289 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.12 13,433 1,310 10 INDIANA GIBSON INDIANA #5 BARGE 1.22 7.21 13,548 1,311 10 INDIANA GIBSON INDIANA #5 BARGE 1.24 7.14 13,577 1,305 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.24 13,600 1,321 10 INDIANA GIBSON INDIANA #5 BARGE 1.29 7.27 13,417 1,318 10 INDIANA GIBSON INDIANA #5 BARGE 1.23 7.19 13,538 1,283 10 INDIANA GIBSON INDIANA #5 BARGE 1.23 7.30 13,605 1,287 10 INDIANA GIBSON INDIANA #5 BARGE 1.22 7.20 13,608 1,297 10 INDIANA GIBSON INDIANA #5 BARGE 1.24 7.40 13,616 1,315 10 INDIANA GIBSON INDIANA #5 BARGE 1.24 7.40 13,581 1,301 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.43 13,450 1,308 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.63 13,467 1,299 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.38 13,536 1,296 10 INDIANA GIBSON INDIANA #5 BARGE 1.27 7.17 13,550 1,322 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.45 13,568 1,298 10 INDIANA GIBSON INDIANA #5 BARGE 1.31 7.71 13,473 1,305 10 INDIANA GIBSON INDIANA #5 BARGE 1.38 8.03 13,438 1,308 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.45 13,511 1,303 10 INDIANA GIBSON INDIANA #5 BARGE 1.29 7.89 13,466 1,304 10 INDIANA GIBSON INDIANA #5 BARGE 1.27 7.44 13,560 1,317 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.84 13,490 1,319 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.70 13,527 1,313 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 6.55 13,592 1,312 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 6.51 13,701 1,262 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 6.99 13,520 1,321 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 6.71 13,630 1,334 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 6.86 13,597 1,322 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 6.85 13,654 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 6.81 13,652 1,318 10 INDIANA GIBSON INDIANA #5 BARGE 1.30 6.47 13,692 1,284 10 INDIANA GIBSON INDIANA #5 BARGE 1.30 6.70 13,713D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,300 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.03 13,650 1,323 10 INDIANA GIBSON INDIANA #5 BARGE 1.41 7.18 13,616 1,300 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 6.47 13,741 1,300 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 6.76 13,710 1,294 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.16 13,573 1,275 10 INDIANA GIBSON INDIANA #5 BARGE 1.31 7.03 13,618 1,307 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.13 13,554 1,170 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.41 13,534 1,290 10 INDIANA GIBSON INDIANA #5 BARGE 1.27 7.09 13,575 1,270 10 INDIANA GIBSON INDIANA #5 BARGE 1.27 6.89 13,626 1,312 10 INDIANA GIBSON INDIANA #5 BARGE 1.27 7.34 13,522 1,294 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.22 13,592 1,296 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.31 13,510 1,284 10 INDIANA GIBSON INDIANA #5 BARGE 1.27 7.02 13,630 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.28 6.97 13,671 1,307 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.23 13,331 1,302 10 INDIANA GIBSON INDIANA #5 BARGE 1.31 7.43 13,643 1,297 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.61 13,562 1,300 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.46 13,511 1,222 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.43 13,593 1,300 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.71 13,538 1,293 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.48 13,631 1,287 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.39 13,584 1,325 10 INDIANA GIBSON INDIANA #5 BARGE 1.27 7.64 13,558 1,304 10 INDIANA GIBSON INDIANA #5 BARGE 1.28 7.68 13,541 1,320 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.53 13,592 1,322 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.59 13,517 1,305 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.86 13,475 1,298 10 INDIANA GIBSON INDIANA #5 BARGE 1.31 7.88 13,500 1,309 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.59 13,580 1,311 10 INDIANA GIBSON INDIANA #5 BARGE 1.30 7.52 13,538 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.45 7.15 13,618 1,307 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.39 13,588 1,307 10 INDIANA GIBSON INDIANA #5 BARGE 1.41 7.36 13,612 1,295 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.36 13,577 1,311 10 INDIANA GIBSON INDIANA #5 BARGE 1.42 7.26 13,564 1,322 10 INDIANA GIBSON INDIANA #5 BARGE 1.40 7.34 13,580 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.43 7.30 13,596 1,309 10 INDIANA GIBSON INDIANA #5 BARGE 1.46 7.26 13,556 1,317 10 INDIANA GIBSON INDIANA #5 BARGE 1.40 7.55 13,508 1,325 10 INDIANA GIBSON INDIANA #5 BARGE 1.41 7.43 13,600 1,328 10 INDIANA GIBSON INDIANA #5 BARGE 1.38 7.46 13,529 1,318 10 INDIANA GIBSON INDIANA #5 BARGE 1.43 7.56 13,538 1,321 10 INDIANA GIBSON INDIANA #5 BARGE 1.45 7.43 13,471 1,322 10 INDIANA GIBSON INDIANA #5 BARGE 1.39 7.37 13,577D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.38 7.55 13,507 1,338 10 INDIANA GIBSON INDIANA #5 BARGE 1.41 7.27 13,559 1,318 10 INDIANA GIBSON INDIANA #5 BARGE 1.59 7.80 13,452 1,337 10 INDIANA GIBSON INDIANA #5 BARGE 1.61 7.64 13,578 1,304 10 INDIANA GIBSON INDIANA #5 BARGE 1.48 7.40 13,571 1,341 10 INDIANA GIBSON INDIANA #5 BARGE 1.56 7.69 13,468 1,321 10 INDIANA GIBSON INDIANA #5 BARGE 1.62 7.54 13,523 1,329 10 INDIANA GIBSON INDIANA #5 BARGE 1.59 7.77 13,510 1,306 10 INDIANA GIBSON INDIANA #5 BARGE 1.56 7.70 13,506 1,294 10 INDIANA GIBSON INDIANA #5 BARGE 1.55 7.49 13,522 1,323 10 INDIANA GIBSON INDIANA #5 BARGE 1.43 7.29 13,570 1,334 10 INDIANA GIBSON INDIANA #5 BARGE 1.46 7.27 13,568 1,315 10 INDIANA GIBSON INDIANA #5 BARGE 1.52 7.29 13,570 1,361 10 INDIANA GIBSON INDIANA #5 BARGE 1.47 7.54 13,506 1,321 10 INDIANA GIBSON INDIANA #5 BARGE 1.52 7.36 13,603 1,323 10 INDIANA GIBSON INDIANA #5 BARGE 1.57 7.37 13,597 1,332 10 INDIANA GIBSON INDIANA #5 BARGE 1.51 7.46 13,557 1,326 10 INDIANA GIBSON INDIANA #5 BARGE 1.56 7.49 13,602 1,324 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.33 13,563 1,320 10 INDIANA GIBSON INDIANA #5 BARGE 1.46 7.43 13,560 1,338 10 INDIANA GIBSON INDIANA #5 BARGE 1.44 7.64 13,532 1,363 10 INDIANA GIBSON INDIANA #5 BARGE 1.42 7.45 13,551 1,322 10 INDIANA GIBSON INDIANA #5 BARGE 1.44 7.37 13,570 1,294 10 INDIANA GIBSON INDIANA #5 BARGE 1.47 7.39 13,588 1,360 10 INDIANA GIBSON INDIANA #5 BARGE 1.50 7.71 13,536 1,320 10 INDIANA GIBSON INDIANA #5 BARGE 1.38 7.24 13,574 1,344 10 INDIANA GIBSON INDIANA #5 BARGE 1.42 7.53 13,538 1,320 10 INDIANA GIBSON INDIANA #5 BARGE 1.40 7.35 13,581 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.27 13,595 1,344 10 INDIANA GIBSON INDIANA #5 BARGE 1.44 7.28 13,562 1,337 10 INDIANA GIBSON INDIANA #5 BARGE 1.41 7.47 13,538 1,326 10 INDIANA GIBSON INDIANA #5 BARGE 1.45 7.38 13,532 1,328 10 INDIANA GIBSON INDIANA #5 BARGE 1.44 7.57 13,499 1,296 10 INDIANA GIBSON INDIANA #5 BARGE 1.39 7.34 13,570 1,295 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.03 13,595 1,279 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 6.97 13,627 1,294 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.05 13,635 1,308 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.14 13,528 1,308 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 6.95 13,604 1,322 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 6.93 13,628 1,305 10 INDIANA GIBSON INDIANA #5 BARGE 1.29 6.90 13,589 1,310 10 INDIANA GIBSON INDIANA #5 BARGE 1.39 7.21 13,598 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.18 13,613 1,280 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 6.92 13,648 1,289 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.15 13,613D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,296 10 INDIANA GIBSON INDIANA #5 BARGE 1.30 7.20 13,633 1,299 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.27 13,607 1,307 10 INDIANA GIBSON INDIANA #5 BARGE 1.29 7.18 13,606 1,308 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.21 13,590 1,306 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.09 13,611 1,319 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.49 13,550 1,334 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.27 13,579 1,318 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.33 13,577 1,321 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.37 13,579 1,318 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.41 13,569 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.31 7.13 13,621 1,313 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.48 13,521 1,334 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.51 13,509 1,328 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.27 13,635 1,317 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.28 13,581 1,297 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.33 13,606 1,326 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.41 13,555 1,312 10 INDIANA GIBSON INDIANA #5 BARGE 1.41 7.54 13,545 1,322 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.43 13,537 1,295 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.29 13,597 1,303 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.49 13,590 1,322 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.79 13,503 1,308 10 INDIANA GIBSON INDIANA #5 BARGE 1.38 7.70 13,565 1,327 10 INDIANA GIBSON INDIANA #5 BARGE 1.39 7.80 13,486 1,323 10 INDIANA GIBSON INDIANA #5 BARGE 1.40 7.43 13,574 1,331 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.47 13,537 1,341 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.57 13,466 1,332 10 INDIANA GIBSON INDIANA #5 BARGE 1.40 7.61 13,559 1,336 10 INDIANA GIBSON INDIANA #5 BARGE 1.38 7.64 13,479 1,304 10 INDIANA GIBSON INDIANA #5 BARGE 1.30 7.06 13,619 1,320 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.16 13,586 1,305 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.17 13,579 1,319 10 INDIANA GIBSON INDIANA #5 BARGE 1.29 7.31 13,553 1,323 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.08 13,587 1,332 10 INDIANA GIBSON INDIANA #5 BARGE 1.28 6.97 13,632 1,320 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.23 13,531 1,319 10 INDIANA GIBSON INDIANA #5 BARGE 1.31 7.31 13,544 1,346 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.56 13,543 1,330 10 INDIANA GIBSON INDIANA #5 BARGE 1.44 7.53 13,587 1,362 10 INDIANA GIBSON INDIANA #5 BARGE 1.40 7.63 13,542 1,328 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.39 13,543 1,340 10 INDIANA GIBSON INDIANA #5 BARGE 1.41 7.54 13,547 1,339 10 INDIANA GIBSON INDIANA #5 BARGE 1.39 7.82 13,545 1,347 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.59 13,413 1,327 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.59 13,506D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,318 10 INDIANA GIBSON INDIANA #5 BARGE 1.28 7.42 13,554 1,276 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.63 13,456 1,311 10 INDIANA GIBSON INDIANA #5 BARGE 1.27 7.20 13,564 1,332 10 INDIANA GIBSON INDIANA #5 BARGE 1.51 7.69 13,521 1,317 10 INDIANA GIBSON INDIANA #5 BARGE 1.33 7.54 13,493 1,289 10 INDIANA GIBSON INDIANA #5 BARGE 1.28 7.41 13,556 1,307 10 INDIANA GIBSON INDIANA #5 BARGE 1.24 7.49 13,473 1,340 10 INDIANA GIBSON INDIANA #5 BARGE 1.25 7.70 13,387 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.42 7.53 13,559 1,313 10 INDIANA GIBSON INDIANA #5 BARGE 1.40 7.43 13,521 1,309 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.40 13,757 1,320 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.22 13,660 1,313 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.42 13,722 1,314 10 INDIANA GIBSON INDIANA #5 BARGE 1.40 7.45 13,625 1,310 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.52 13,612 1,329 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.36 13,584 1,332 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.55 13,515 1,296 10 INDIANA GIBSON INDIANA #5 BARGE 1.26 7.48 13,481 1,302 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.76 13,498 1,294 10 INDIANA GIBSON INDIANA #5 BARGE 1.38 7.70 13,479 1,318 10 INDIANA GIBSON INDIANA #5 BARGE 1.35 7.49 13,542 1,339 10 INDIANA GIBSON INDIANA #5 BARGE 1.41 7.80 13,502 1,327 10 INDIANA GIBSON INDIANA #5 BARGE 1.32 7.36 13,592 1,339 10 INDIANA GIBSON INDIANA #5 BARGE 1.26 7.57 13,459 1,333 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.09 13,606 1,328 10 INDIANA GIBSON INDIANA #5 BARGE 1.38 7.25 13,603 1,278 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.00 13,692 1,332 10 INDIANA GIBSON INDIANA #5 BARGE 1.37 7.22 13,566 1,288 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.10 13,648 1,302 10 INDIANA GIBSON INDIANA #5 BARGE 1.39 7.27 13,664 1,344 10 INDIANA GIBSON INDIANA #5 BARGE 1.36 7.29 13,447 1,319 10 INDIANA GIBSON INDIANA #5 BARGE 1.34 7.22 13,656 1,409 10 N/A N/A BROOKWOOD BARGE 1.34 13.61 13,227 1,404 10 N/A N/A BROOKWOOD BARGE 1.15 14.07 13,237 1,396 10 N/A N/A BROOKWOOD BARGE 1.17 13.76 13,220 1,458 10 N/A N/A BROOKWOOD BARGE 1.18 14.68 13,056 1,415 10 N/A N/A BROOKWOOD BARGE 1.21 13.58 13,341 1,369 10 N/A N/A BROOKWOOD BARGE 1.13 14.42 13,048 1,383 10 N/A N/A BROOKWOOD BARGE 1.28 13.48 13,215 1,406 10 N/A N/A BROOKWOOD BARGE 1.17 13.63 13,164 1,430 10 N/A N/A BROOKWOOD BARGE 1.11 13.24 13,236 1,316 10 N/A N/A BROOKWOOD BARGE 1.11 13.21 13,169 1,384 10 N/A N/A BROOKWOOD BARGE 1.18 13.64 13,164 1,332 10 N/A N/A BROOKWOOD BARGE 1.18 14.11 13,135 1,411 10 N/A N/A BROOKWOOD BARGE 1.18 14.11 13,135D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,416 10 N/A N/A BROOKWOOD BARGE 1.18 14.11 13,135 1,393 10 N/A N/A BROOKWOOD BARGE 1.18 14.11 13,135 1,343 10 N/A N/A BROOKWOOD BARGE 1.18 14.11 13,135 1,419 10 N/A N/A BROOKWOOD BARGE 1.18 14.11 13,135 1,372 10 N/A N/A BROOKWOOD BARGE 1.08 13.93 13,250 1,376 10 N/A N/A BROOKWOOD BARGE 1.08 13.93 13,250 1,358 10 N/A N/A BROOKWOOD BARGE 1.08 13.93 13,250 1,443 10 N/A N/A BROOKWOOD BARGE 1.08 13.93 13,250 1,340 10 N/A N/A BROOKWOOD BARGE 1.08 13.93 13,250 1,418 10 N/A N/A BROOKWOOD BARGE 1.08 13.93 13,250 1,312 10 N/A N/A BROOKWOOD BARGE 1.06 12.89 13,292 1,315 10 N/A N/A BROOKWOOD BARGE 1.06 12.89 13,292 1,307 10 N/A N/A BROOKWOOD BARGE 1.06 12.89 13,292 1,382 10 N/A N/A BROOKWOOD BARGE 1.06 12.89 13,292 1,414 10 N/A N/A BROOKWOOD BARGE 1.06 12.89 13,292 1,290 10 N/A N/A BROOKWOOD BARGE 1.06 12.89 13,292 1,292 10 N/A N/A BROOKWOOD BARGE 1.10 14.27 13,146 1,313 10 N/A N/A BROOKWOOD BARGE 1.11 13.91 13,235 1,394 10 N/A N/A BROOKWOOD BARGE 1.09 14.05 13,165 1,351 10 N/A N/A BROOKWOOD BARGE 1.11 14.71 13,097 1,342 10 N/A N/A BROOKWOOD BARGE 1.11 14.10 13,214 1,395 10 N/A N/A BROOKWOOD BARGE 1.08 14.48 13,113 1,383 10 N/A N/A BROOKWOOD BARGE 1.09 13.59 13,298 1,431 10 N/A N/A BROOKWOOD BARGE 1.08 13.75 13,215 1,335 10 N/A N/A BROOKWOOD BARGE 1.11 13.72 13,332 1,385 10 N/A N/A BROOKWOOD BARGE 1.15 13.65 13,273 1,398 10 N/A N/A BROOKWOOD BARGE 1.07 13.08 13,335 1,413 10 N/A N/A BROOKWOOD BARGE 1.11 13.60 13,294 1,290 10 N/A N/A BROOKWOOD BARGE 1.14 13.56 13,154 1,314 10 N/A N/A BROOKWOOD BARGE 1.15 13.49 13,244 1,429 10 N/A N/A BROOKWOOD BARGE 1.16 13.49 13,267 1,372 10 N/A N/A BROOKWOOD BARGE 1.00 13.32 13,312 1,327 10 N/A N/A BROOKWOOD BARGE 1.15 13.75 13,184 1,330 10 N/A N/A BROOKWOOD BARGE 1.09 13.78 13,227 1,356 10 N/A N/A BROOKWOOD BARGE 1.04 13.17 13,365 1,439 10 N/A N/A BROOKWOOD BARGE 1.09 13.61 13,301 1,247 10 N/A N/A BROOKWOOD BARGE 1.03 13.11 13,338 1,389 10 N/A N/A BROOKWOOD BARGE 1.07 13.78 13,389 1,407 10 N/A N/A BROOKWOOD BARGE 1.06 13.08 13,442 1,445 10 N/A N/A BROOKWOOD BARGE 1.13 13.44 13,363 1,331 10 N/A N/A BROOKWOOD BARGE 1.11 11.74 13,643 1,346 10 N/A N/A BROOKWOOD BARGE 1.15 12.99 13,439 1,338 10 N/A N/A BROOKWOOD BARGE 1.08 12.99 13,435 1,366 10 N/A N/A BROOKWOOD BARGE 1.15 12.49 13,587 1,322 10 N/A N/A BROOKWOOD BARGE 1.03 12.48 13,506D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,441 10 N/A N/A BROOKWOOD BARGE 1.07 12.41 13,510 1,366 10 N/A N/A BROOKWOOD BARGE 1.06 11.14 13,737 1,433 10 N/A N/A BROOKWOOD BARGE 1.04 11.46 13,664 1,427 10 N/A N/A BROOKWOOD BARGE 1.04 11.31 13,662 1,361 10 N/A N/A BROOKWOOD BARGE 1.05 11.86 13,617 1,377 10 N/A N/A BROOKWOOD BARGE 1.06 11.88 13,561 1,394 10 N/A N/A BROOKWOOD BARGE 1.06 11.28 13,732 1,375 10 N/A N/A BROOKWOOD BARGE 1.08 11.67 13,642 1,319 10 N/A N/A BROOKWOOD BARGE 1.03 12.20 13,550 1,394 10 N/A N/A BROOKWOOD BARGE 1.07 11.95 13,526 1,414 10 N/A N/A BROOKWOOD BARGE 1.07 12.48 13,471 1,221 10 N/A N/A BROOKWOOD BARGE 1.08 11.90 13,553 1,358 10 N/A N/A BROOKWOOD BARGE 1.06 12.47 13,479 1,314 10 N/A N/A BROOKWOOD BARGE 1.02 11.78 13,578 1,421 10 N/A N/A BROOKWOOD BARGE 1.07 11.83 13,592 1,356 10 N/A N/A BROOKWOOD BARGE 1.09 12.53 13,462 1,351 10 N/A N/A BROOKWOOD BARGE 1.04 12.02 13,600 1,362 10 N/A N/A BROOKWOOD BARGE 1.05 12.51 13,468 1,397 10 N/A N/A BROOKWOOD BARGE 1.10 12.63 13,484 1,400 10 N/A N/A BROOKWOOD BARGE 1.07 12.08 13,542 1,400 10 N/A N/A BROOKWOOD BARGE 1.14 12.48 13,493 1,380 10 N/A N/A BROOKWOOD BARGE 1.06 12.21 13,523 1,346 10 N/A N/A BROOKWOOD BARGE 1.03 12.67 13,489 1,400 10 N/A N/A BROOKWOOD BARGE 1.08 12.29 13,515 1,376 10 N/A N/A BROOKWOOD BARGE 1.05 12.57 13,508 1,429 10 N/A N/A BROOKWOOD BARGE 1.01 13.01 13,168 1,337 10 N/A N/A BROOKWOOD BARGE 0.99 13.23 13,281 1,408 10 N/A N/A BROOKWOOD BARGE 1.05 13.19 13,365 1,385 10 N/A N/A BROOKWOOD BARGE 1.06 13.89 13,291 1,401 10 N/A N/A BROOKWOOD BARGE 1.06 13.53 13,350 1,358 10 N/A N/A BROOKWOOD BARGE 1.14 13.10 13,362 1,316 10 N/A N/A BROOKWOOD BARGE 1.08 12.39 13,532 1,261 10 N/A N/A BROOKWOOD BARGE 1.13 12.10 13,520 1,257 10 N/A N/A BROOKWOOD BARGE 1.10 12.49 13,530 1,354 10 N/A N/A BROOKWOOD BARGE 1.13 12.26 13,578 1,369 10 N/A N/A BROOKWOOD BARGE 1.11 12.41 13,538 1,268 10 N/A N/A BROOKWOOD BARGE 1.13 12.47 13,507 1,406 10 N/A N/A BROOKWOOD BARGE 1.10 12.22 13,461 1,416 10 N/A N/A BROOKWOOD BARGE 1.09 11.55 13,656 1,417 10 N/A N/A BROOKWOOD BARGE 1.15 11.68 13,551 1,407 10 N/A N/A BROOKWOOD BARGE 1.15 11.34 13,604 1,348 10 N/A N/A BROOKWOOD BARGE 1.20 11.68 13,585 1,391 10 N/A N/A BROOKWOOD BARGE 1.23 11.34 13,670 1,418 10 N/A N/A BROOKWOOD BARGE 1.12 13.37 13,333 1,448 10 N/A N/A BROOKWOOD BARGE 1.10 12.25 13,495D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,410 10 N/A N/A BROOKWOOD BARGE 1.09 11.74 13,528 1,417 10 N/A N/A BROOKWOOD BARGE 1.08 12.06 13,590 1,368 10 N/A N/A BROOKWOOD BARGE 1.21 13.53 13,328 1,388 10 N/A N/A BROOKWOOD BARGE 1.17 12.33 13,473 1,371 10 N/A N/A BROOKWOOD BARGE 1.22 12.40 13,460 1,378 10 N/A N/A BROOKWOOD BARGE 1.21 12.91 13,414 1,421 10 N/A N/A BROOKWOOD BARGE 1.15 13.51 13,279 1,356 10 N/A N/A BROOKWOOD BARGE 1.17 12.78 13,414 1,348 10 N/A N/A BROOKWOOD BARGE 1.11 13.11 13,403 1,455 10 N/A N/A BROOKWOOD BARGE 1.22 12.87 13,448 1,422 10 N/A N/A BROOKWOOD BARGE 1.26 13.27 13,404 1,378 10 N/A N/A BROOKWOOD BARGE 1.25 12.82 13,391 1,388 10 N/A N/A BROOKWOOD BARGE 1.24 12.95 13,437 1,422 10 N/A N/A BROOKWOOD BARGE 1.22 13.17 13,335 1,368 10 N/A N/A BROOKWOOD BARGE 1.19 12.96 13,368 1,384 10 N/A N/A BROOKWOOD BARGE 1.10 12.35 13,458 1,273 10 N/A N/A BROOKWOOD BARGE 1.12 12.38 13,535 1,278 10 N/A N/A BROOKWOOD BARGE 1.09 12.72 13,422 1,347 10 N/A N/A BROOKWOOD BARGE 1.08 12.61 13,454 1,345 10 N/A N/A BROOKWOOD BARGE 1.19 12.94 13,372 1,218 10 N/A N/A BROOKWOOD BARGE 1.12 12.90 13,882 1,250 10 N/A N/A BROOKWOOD BARGE 1.15 13.67 13,319 1,369 10 N/A N/A BROOKWOOD BARGE 1.15 13.68 13,315 1,260 10 N/A N/A BROOKWOOD BARGE 1.11 13.41 13,349 1,366 10 N/A N/A BROOKWOOD BARGE 1.12 14.15 13,204 1,348 10 N/A N/A BROOKWOOD BARGE 1.16 13.24 13,281 1,338 10 N/A N/A BROOKWOOD BARGE 1.14 13.27 13,367 1,242 10 N/A N/A BROOKWOOD BARGE 1.08 12.79 13,502 1,448 10 N/A N/A BROOKWOOD BARGE 1.22 12.83 13,364 1,353 10 N/A N/A BROOKWOOD BARGE 1.10 13.29 13,366 1,401 10 N/A N/A BROOKWOOD BARGE 1.13 13.25 13,314 1,360 10 N/A N/A BROOKWOOD BARGE 1.20 12.94 13,347 1,330 10 N/A N/A BROOKWOOD BARGE 1.14 13.34 13,294 1,423 10 N/A N/A BROOKWOOD BARGE 1.13 13.10 13,398 1,273 10 N/A N/A BROOKWOOD BARGE 1.08 13.51 13,339 1,402 10 N/A N/A BROOKWOOD BARGE 1.16 13.73 13,250 1,429 10 N/A N/A BROOKWOOD BARGE 1.10 13.70 13,314 1,364 10 N/A N/A BROOKWOOD BARGE 1.09 13.66 13,309 1,234 10 N/A N/A BROOKWOOD BARGE 1.08 14.03 13,218 1,368 10 N/A N/A BROOKWOOD BARGE 1.11 13.83 13,239 1,383 10 N/A N/A BROOKWOOD BARGE 1.06 13.89 13,286 1,365 10 N/A N/A BROOKWOOD BARGE 1.12 13.51 13,288 1,372 10 N/A N/A BROOKWOOD BARGE 1.13 13.48 13,289 1,269 10 N/A N/A BROOKWOOD BARGE 1.08 13.19 13,369 1,374 10 N/A N/A BROOKWOOD BARGE 1.05 13.40 13,374D.B. D.B. D.B. 

### State/Country County42 

### Coal seam43 % Sulf% A shBtu/lb 

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

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

### Fuel source Fuel Shipment Method 1,350 10 N/A N/A BROOKWOOD BARGE 1.04 13.28 13,424 1,354 10 N/A N/A BROOKWOOD BARGE 1.08 13.94 13,184 1,384 10 N/A N/A BROOKWOOD BARGE 1.01 13.58 13,242 1,321 10 N/A N/A BROOKWOOD BARGE 1.06 14.02 13,246 1,369 10 N/A N/A BROOKWOOD BARGE 1.14 14.28 13,156 1,331 10 N/A N/A BROOKWOOD BARGE 1.08 13.77 13,295 1,366 10 N/A N/A BROOKWOOD BARGE 1.13 14.36 13,205 1,340 10 N/A N/A BROOKWOOD BARGE 1.10 13.50 13,348 1,298 10 N/A N/A BROOKWOOD BARGE 1.17 13.34 13,313 1,392 10 N/A N/A BROOKWOOD BARGE 1.22 14.22 13,249 1,367 10 N/A N/A BROOKWOOD BARGE 1.18 13.29 13,375 1,400 10 N/A N/A BROOKWOOD BARGE 1.15 13.34 13,394 1,371 10 N/A N/A BROOKWOOD BARGE 1.20 13.17 13,470 1,344 10 N/A N/A BROOKWOOD BARGE 1.23 12.91 13,372 1,408 10 N/A N/A BROOKWOOD BARGE 1.46 13.59 13,233 1,331 10 N/A N/A BROOKWOOD BARGE 1.23 13.07 13,358 1,377 10 N/A N/A BROOKWOOD BARGE 1.04 13.12 13,332 1,387 10 N/A N/A BROOKWOOD BARGE 1.16 13.22 13,368 1,404 10 N/A N/A BROOKWOOD BARGE 1.16 13.26 13,343 1,343 10 N/A N/A BROOKWOOD BARGE 1.19 13.26 13,376 1,393 10 N/A N/A BROOKWOOD BARGE 1.17 14.37 13,250 1,392 10 N/A N/A BROOKWOOD BARGE 1.22 12.79 13,474 1,292 10 N/A N/A BROOKWOOD BARGE 1.19 13.82 13,317 1,283 10 N/A N/A BROOKWOOD BARGE 1.23 12.67 13,405 1,337 10 N/A N/A BROOKWOOD BARGE 1.12 12.90 13,418 1,334 10 N/A N/A BROOKWOOD BARGE 1.19 14.59 13,128 1,429 10 N/A N/A BROOKWOOD BARGE 1.23 14.94 12,973 1,379 10 N/A N/A BROOKWOOD BARGE 1.21 14.94 13,064 1,324 10 N/A N/A BROOKWOOD BARGE 1.22 14.16 13,231 1,316 10 N/A N/A BROOKWOOD BARGE 1.26 13.56 13,309 1,378 10 N/A N/A BROOKWOOD BARGE 1.23 13.75 13,254 1,288 10 N/A N/A BROOKWOOD BARGE 1.12 13.30 13,3503For 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):

AntimonyArsenicBerylliumCadmiumChromiumCobaltLeadManganeseSelenium

09-600 8,389 1.16 12.27 13,216 0.136 290 73 15.6 1.8 27.5 1.9 0.14 18.6 6.9 8.2 35.4 1.2AL Marion, Winston, Walker, Tuscaloosa Blue Creek, Black Creek, Clement Barge 09-602 9,400 1.14 15.97 12,756 0.192 132 69 18.4 2.2 28.5 1.9 0.11 24.7 10.1 9.5 45.2 1.9AL Jefferson, Tuscaloosa Blue Creek, Brookwood Barge 09-604 8,882 1.15 14.86 12,976 0.077 112 70 14.3 1.3 14.7 1.7 0.08 19.9 7.4 8.4 27.8 2.1AL Tuscaloosa, Jefferson Brookwood, Mildale, Carter, Blue Creek (washed fines) Barge 09-100 8,223 1.06 6.73 13,675 0.101 2237 61 20.0 1.8 17.4 2.2 0.09 9.3 6.9 12.1 11.4 0.8IN Gibson Herron # 5 Seam Train 09-611 6,316 1.28 17.58 12,246 0.159 372 92 16.5 1.6 30.7 1.4 0.22 22.1 8.4 6.4 33.4 1.1AL Cullman, Jefferson, Shelby Black Creek, Washed Black Creek, Lower New Castle, Thompson #1, JWR #3 Fines, Covol #5 Barge

09-612 8,096 0.82 14.21 12,673 0.063 520 65 14.3 1.5 14.4 2.1 <0.02 19.7 11.9 5.2 28.0 1.1AL Walker Marylee Seam Truck 09-613 20,455 1.88 17.69 12,125 0.259 283 85 19.3 1.4 55.1 2.0 0.31 24.0 9.6 9.8 134.0 1.7AL Jefferson, Walker, Winston, Franklin, Tuscaloosa Marylee, Black Creek, Blend, Jefferson, AM #2, HA Johnson, Johnson, T AM, Jeff BB top & Bottom, Jeff TC, American AM#3 Truck

09-614 6,113 1.54 16.36 12,356 0.234 289 78 17.2 1.2 39.2 1.7 0.21 20.3 10.7 8.1 82.2 1.5AL Walker Marylee Truck 09-615 602 2.28 14.67 12,788 0.382 249 78 17.4 <1 77.8 1.7 0.43 18.5 8.9 8.1 38.5 1.4AL Jefferson New Castle, Marylee Truck 09-616 18,535 1.12 15.28 12,827 0.204 141 46 19.1 2.4 33.4 1.8 0.14 22.8 9.6 7.9 41.9 2.1AL Jefferson, Tuscaloosa Blue Creek, Brookwood Barge 09-617 3,090 1.26 16.18 12,429 0.176 273 83 21.5 1.9 35.1 1.5 0.13 23.9 10.2 8.4 38.2 0.8AL Marion, Winston, 'Walker, Tuscaloosa Blue Creek, Black Creek, Clement Barge 09-620 9,415 1.16 14.15 12,781 0.051 429 88 19.2 1.5 18.8 0.9 0.04 21.1 9.1 6.9 20.5 1.2AL Cullman, Jefferson, Shelby Black Creek, Lower Helena #1, Lower Helena #2, Mary Lee, Blue Creek, JWR #3 Fines Barge

09-104 12,000 1.29 7.39 13,538 0.099 2318 52 20.6 1.5 20.5 2.0 0.10 10.6 6.2 12.0 11.2 1.0IN Gibson Herron # 5 seam Barge 09-621 8,946 1.12 13.43 13,134 0.089 123 81 15.7 1.5 14.1 2.0 <0.02 23.0 8.5 4.9 24.6 2.3AL Tuscaloosa, Jefferson Brookwood, Midale, Johnson, Blue Creek Barge 09-628 1,593 1.79 13.35 13,054 0.254 141 70 17.2 2.5 96.7 1.7 0.90 20.2 11.7 6.1 26.1 0.9AL Jefferson, Walker New Castle, Blue Creek, Coval, Blue Creek Fines Truck 09-629 6,418 0.86 14.06 12,719 0.096 380 56 16.3 2.1 19.1 1.7 0.05 20.1 13.9 7.5 30.4 1.5AL Walker, Tuscaloosa Mary Lee, Carter Truck 09-630 2,264 0.99 15.93 12,386 0.16 272 48 15.3 2.2 27.5 1.4 0.16 21.4 11.8 8.9 26.3 1.4AL Walker Mary Lee Truck 09-631 1,060 1.52 15.64 12,440 0.245 198 79 14.9 3.0 64.9 2.0 0.61 19.3 9.3 8.7 92.2 2.0AL Walker New Castle Truck 09-632 21,157 1.78 17.04 12,393 0.36 495 85 20.5 3.3 55.8 1.9 0.50 26.6 10.9 12.4 137.7 0.8AL Jefferson, Walker, Winston, Franklin, Tuscaloosa Mary Lee, New Castle, Black Creek, Jefferson, Jefferson TC&BB, America #1, 2, 3, &4, Johnson, Top Clements, Bottom& Top America, America Truck

09-647 927 1.19 11.5 13,188 0.135 179 39 20.6 3.0 25.8 2.7 0.13 21.8 14.4 9.8 24.1 2.1AL Walker Black Creek, Jefferson, Vlend, Nickle Plate, Pratt Truck 09-645 398 2.18 11.65 13,339 0.234 199 47 17.3 2.5 92.4 1.7 0.31 15.2 11.7 6.7 22.4 1.3AL Jefferson, Walker New Castle, Blue Creek, Mary Lee Truck 09-644 2,318 0.97 13.26 12,969 0.162 208 53 15.1 1.8 25.6 1.6 0.04 16.3 10.2 7.3 26.4 1.7AL Walker Marylee Seam Truck 09-643 10,004 1.91 16.25 12,474 0.311 203 57 18.7 3.4 43.9 1.9 0.19 19.6 8.8 9.9 53.1 1.8AL Jefferson, Marion, Tuscaloosa, Walker Mary Lee, New Castle, Black Creek, Jefferson, Blend, America#1,#2, AM#2,Johnson HA,Top Clements, Bottom&Top America, Jefferson TC&BB, America Truck

09-642 9,212 1.26 14.72 12,506 0.18 274 74 16.4 1.5 17.8 1.5 0.04 18.2 6.7 8.2 26.3 1.0AL Marion, Winston, Walker, Tuscaloosa Blue Creek, Black Creek, Clement Barge 09-638 18,635 1.07 14.28 12,937 0.222 128 69 17.5 2.5 28.5 2.0 0.18 20.1 9.8 8.8 31.9 2.2AL Jefferson, Tuscaloosa Blue Creek, Brookwood Barge 09-636 9,036 1.03 11.37 13,636 0.111 955 97 14.3 1.7 14.3 1.7 0.07 18.7 7.7 7.9 26.9 1.1AL Jefferson, Tuscaloosa Brookwood, Mildale, Johnson, Blue Creek Barge 09-648 1,394 0.73 15.26 12,434 0.071 344 52 25.7 2.4 16.5 2.4 0.03 31.2 20.3 10.6 44.8 1.5AL Walker, Tuscaloosa Mary Lee, Carter Truck 09-649 880 2.09 14.91 12,679 ND 371 62 21.3 3.5 77.5 3.0 0.30 25.9 16.9 10.7 47.3 0.7AL Walker New Castle Truck 09-105 8,099 1.38 8.04 13,393 0.123 1783 36 21.3 1.6 22.3 1.9 0.13 11.4 7.2 20.2 13.4 0.9IN Gibson Herron # 5 seam Train 09-651 9,077 1.18 15.3 12,868 0.227 115 62 18.5 2.1 41.2 2.1 0.22 24.2 8.7 8.6 36.4 2.2AL Jefferson, Tuscaloosa Blue Creek, Brookwood Barge 09-653 7,000 1.09 11.6 13,299 0.132 385 64 19.2 2.3 30.8 2.0 0.17 19.6 10.1 7.4 63.5 1.6AL Jefferson, Walker, Franklin Blue Creek, Bear Creek & HA (WC), Lick Creek, Nickle Plate, America #1 Train

09-654 8,578 1.12 13.3 13,431 0.091 146 54 16.1 2.4 16.4 1.9 0.08 22.4 8.6 9.5 32.9 1.8AL Jefferson, Tuscaloosa Brookwood, Mildale, Johnson, Blue Creek Fines Barge 09-657 8,795 1.42 12.96 12,731 0.238 375 63 18.4 1.8 23.9 2.0 0.07 21.7 8.2 9.1 26.4 1.0AL Winston, Marion, Walker Black Creek, Blue Creek, Marylee, Jagger, Black Creek Barge 09-658 3,892 2 14.39 12,887 0.318 306 60 17.9 3.5 67.4 2.0 0.27 24.1 9.8 10.2 27.9 1.9AL Franklin, Walker Black Creek, Jefferson, Bleand, Nickle Plate, Pratt Truck 09-659 471 2.04 14.18 12,899 0.304 353 67 14.8 2.3 73.8 1.7 0.25 19.7 9.5 7.9 20.1 1.3AL Jefferson New Castle, Black Creek, Marylee Truck 09-661 8,560 1.82 15.16 12,647 0.323 270 56 16.1 2.7 45.2 2.1 0.18 21.3 8.8 9.9 41.3 1.8AL Jefferson, Marion, Tuscaloosa, Walker Mary Lee, New Castle, Black Creek & HA, Jefferson, America #1,#2, #3, AM#4, Johnson HA, Top Clements, Top America & Bottom (WC), Jefferson TC & BB, America Truck

09-111 8,195 1.45 8.78 13,275 0.123 1975 47 25.0 1.8 23.9 2.1 0.14 13.2 6.9 22.5 14.7 1.0IL Gibson Herron # 5 Seam Train

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

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, tonsTotal

Sulfur, % Ash

Content, %Heating Value,

Btu/lb Mercury,

ppm Chlorine,

ppmFluorine,

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

MoistureVolatilesAsh Fixed CarbonCarbonHydrogenNitrogenTotal SulfurOxygenBariumCopperMagnesiumSodiumVanadiumZinc Al2O3Fe2O3 CaO MgOMnO2P2O5 K2O SiO2 Na2O SO3 TiO2

09-600 9.10 28.57 12.27 59.1676.78 4.55 1.70 1.16 3.54 210 20.9 0.1010.037 39.0 21.2 26.88 8.82 2.20 1.360.04564 0.32 2.81 52.78 0.41 2.98 1.14 09-602 11.13 26.81 15.97 57.22 74.25 4.45 1.50 1.14 2.69 250 26.2 0.1100.048 47.5 21.1 29.58 9.43 1.48 1.140.04478 0.35 2.4451.80 0.41 1.67 1.41 09-604 6.4428.49 14.8656.65 74.96 4.52 1.40 1.15 3.11 260 21.8 0.1310.025 44.0 12.7 26.96 6.87 0.89 1.460.02962 0.20 3.59 57.35 0.23 1.10 1.12 09-100 15.91 34.69 6.73 58.58 79.53 4.70 1.78 1.06 6.20 30 6.8 0.0340.065 21.1 20.2 23.70 10.88 2.39 0.850.02686 0.60 2.67 54.06 1.29 2.10 1.35 09-611 5.40 28.08 17.58 54.3469.55 4.39 1.39 1.28 5.81 260 23.3 0.1480.028 44.2 27.2 27.59 8.93 0.69 1.400.03005 0.15 3.62 55.41 0.21 0.73 1.09 09-612 5.41 31.56 14.21 54.23 71.84 4.63 1.75 0.82 6.75 400 19.3 0.0970.031 37.4 15.0 28.00 6.40 0.85 1.120.03113 0.38 2.88 57.70 0.29 0.66 1.38 09-613 5.9430.53 17.69 51.78 68.51 4.49 1.59 1.88 5.84 680 32.6 0.122 0.035 48.0 29.8 24.95 14.49 1.06 1.150.11987 0.57 2.71 51.63 0.27 1.32 1.29 09-614 5.01 30.17 16.3653.47 69.98 4.51 1.58 1.54 6.03 380 23.9 0.113 0.028 44.1 25.7 26.32 12.17 0.84 1.150.07950 0.41 2.66 53.74 0.23 0.91 1.30 09-615 5.11 30.12 14.67 55.21 71.85 4.61 1.54 2.28 5.05 500 28.5 0.0970.028 40.0 21.9 24.78 17.48 0.81 1.100.04148 0.45 2.8049.70 0.25 0.89 1.23 09-616 7.16 27.05 15.28 57.67 72.90 4.36 1.47 1.12 4.87 270 25.3 0.105 0.040 43.6 16.8 28.79 9.35 1.21 1.150.04334 0.34 2.57 53.17 0.35 1.33 1.42 09-617 8.75 30.40 16.18 53.42 70.36 4.52 1.58 1.26 5.74 190 19.2 0.1360.034 52.9 24.0 24.78 11.06 1.84 1.400.03733 0.33 3.23 53.73 0.28 2.00 1.18 09-620 6.8429.30 14.15 56.55 73.09 4.56 1.57 1.16 5.47 240 20.2 0.095 0.023 44.9 22.2 29.41 7.78 0.85 1.110.02293 0.36 2.76 55.22 0.21 0.79 1.19 09-104 13.1435.30 7.39 57.31 76.78 3.99 1.70 1.29 8.85 30 7.5 0.0380.065 24.1 14.423.40 13.20 1.75 0.840.02409 0.60 2.68 53.67 1.19 1.22 1.35 09-621 6.98 28.30 13.43 58.27 75.60 4.53 1.73 1.12 3.59 180 25.0 0.0940.020 45.5 16.9 29.18 8.06 0.90 1.160.02901 0.25 3.18 54.35 0.20 1.18 1.31 09-628 4.21 30.14 13.35 56.51 74.17 4.72 1.58 1.79 4.39 370 17.4 0.0840.029 38.4 16.6 25.25 13.23 0.87 1.040.03089 0.43 2.75 53.29 0.30 1.19 1.30 09-629 5.11 30.61 14.0655.33 72.85 4.67 1.66 0.86 5.90 270 18.2 0.0890.030 36.1 20.1 28.18 5.90 1.26 1.040.03426 0.47 2.72 57.26 0.28 1.17 1.39 09-630 5.65 30.22 15.93 53.85 71.05 4.58 1.63 0.99 5.82 220 16.2 0.1040.053 45.8 16.3 28.12 6.51 0.68 1.070.02608 0.44 2.48 57.95 0.45 0.69 1.42 09-631 7.06 33.02 15.6451.3470.92 4.76 1.68 1.52 5.48 590 23.1 0.1080.044 42.8 25.1 24.41 11.82 1.29 1.140.09327 0.58 2.97 53.98 0.38 1.66 1.28 09-632 5.06 29.22 17.0453.7470.50 4.51 1.55 1.78 4.62 630 35.3 0.1180.036 53.6 38.426.01 13.72 1.01 1.140.12788 0.65 2.82 51.07 0.28 1.45 1.37 09-647 5.47 31.74 11.5056.7675.55 4.64 1.62 1.19 5.50 820 35.8 0.0700.028 43.5 17.0 27.00 8.79 1.50 1.010.03312 0.64 2.4453.87 0.33 1.93 1.53 09-645 7.2430.40 11.65 57.95 76.24 4.72 1.19 2.18 4.02 280 21.6 0.0640.022 31.3 15.6 22.12 19.62 1.32 0.920.03049 0.35 2.6149.66 0.26 1.63 1.17 09-644 5.17 29.97 13.2656.77 74.48 4.60 1.23 0.97 5.15 210 19.8 0.0840.021 32.4 12.8 26.69 8.80 1.42 1.040.03156 0.46 2.6055.87 0.22 1.33 1.35 09-643 5.8429.33 16.25 54.42 71.50 4.44 1.09 1.91 4.81 410 36.1 0.115 0.031 49.2 22.0 25.77 14.65 0.96 1.170.05175 0.45 2.95 50.81 0.26 1.32 1.28 09-642 8.51 30.61 14.72 54.67 71.63 4.45 1.11 1.26 6.83 150 19.1 0.1060.024 37.9 18.5 25.05 7.88 1.65 1.200.02831 0.42 3.06 57.80 0.22 1.43 1.14 09-638 6.8427.63 14.28 58.09 74.12 4.53 1.20 1.07 4.80 250 26.3 0.1000.034 39.1 16.7 28.89 9.15 1.10 1.160.03540 0.31 2.72 53.21 0.32 1.51 1.37 09-636 7.26 27.44 11.37 61.19 78.56 4.68 1.37 1.03 2.99 190 23.6 0.082 0.026 37.9 16.3 28.45 8.32 2.14 1.190.03738 0.42 2.76 52.45 0.31 2.35 1.33 09-648 6.55 30.16 15.2654.58 71.67 4.44 1.66 0.73 6.24 210 23.8 0.102 0.037 59.3 32.6 29.39 5.93 0.92 1.110.04645 0.38 2.76 56.87 0.33 0.67 1.41 09-649 5.2034.06 14.91 51.03 72.00 4.66 1.65 2.09 4.69 350 26.5 0.082 0.045 45.8 41.8 22.27 14.98 3.75 0.920.05017 0.75 2.3848.92 0.40 4.08 1.21 09-105 14.39 34.98 8.0456.98 75.91 4.79 1.32 1.38 8.56 30 7.5 0.0390.060 22.6 21.5 22.09 12.26 1.69 0.800.02638 0.40 2.63 56.29 1.01 1.37 1.29 09-651 8.58 27.07 15.3057.63 73.15 4.57 1.55 1.18 4.25 250 25.4 0.1060.035 44.4 16.1 28.35 9.48 1.21 1.140.03763 0.30 2.75 53.36 0.31 1.47 1.39 09-653 7.62 31.23 11.6057.17 74.96 4.85 1.90 1.09 5.60 410 21.9 0.0810.035 36.2 17.3 27.14 9.08 1.79 1.160.08669 0.37 2.7453.60 0.41 1.83 1.36 09-654 9.06 26.70 13.3060.0076.03 4.69 1.54 1.12 3.32 250 26.4 0.1080.039 47.0 19.7 27.55 8.90 2.24 1.350.03920 0.38 3.05 52.19 0.39 2.35 1.28 09-657 11.7432.25 12.9654.79 72.34 4.83 1.83 1.42 6.62 120 20.1 0.102 0.022 43.8 23.8 26.18 10.02 1.58 1.310.03228 0.37 3.08 54.30 0.23 1.60 1.16 09-658 6.63 30.29 14.39 55.32 72.46 4.75 1.63 2.00 4.77 440 35.0 0.0910.036 48.8 20.8 25.86 14.23 0.94 1.050.03064 0.51 2.71 51.51 0.34 1.06 1.31 09-659 7.10 29.72 14.18 56.1072.67 4.73 1.47 2.04 4.91 390 17.2 0.085 0.030 37.7 14.0 24.86 14.54 0.79 0.990.02238 0.49 2.86 52.42 0.28 1.00 1.35 09-661 7.88 29.55 15.1655.29 71.49 4.67 1.63 1.82 5.23 420 29.1 0.103 0.032 43.5 17.3 25.78 13.26 1.20 1.120.04315 0.45 2.81 51.69 0.28 1.64 1.34 09-111 14.31 34.80 8.78 56.42 75.24 5.08 1.94 1.45 7.51 30 7.4 0.043 0.072 24.2 21.6 20.93 12.44 1.24 0.820.02648 0.30 2.51 58.15 1.10 1.08 1.31 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 6 Particulate Emissions Test (June 15, 2005) Report 2Unit 7 Particulate Emissions Test (June 16, 2005) Report 3Unit 8 Particulate Emissions Test (June 8, 2005) Report 4Unit 9 Particulate Emissions Test (June 7, 2005) Report 5Unit 10 Particulate Emissions Test (June 9, 2005) Report 6Unit 6 Particulate Emissions Test (July 12, 2006) Report 7Unit 7 Particulate Emissions Test (July 11, 2006) Report 8Unit 8 Particulate Emissions Test (June 9, 2006) Report 9Unit 9 Particulate Emissions Test (June 8, 2006) Report 10Unit 10 Particulate Emissions Test (June 13, 2006) Report 11Unit 6 Particulate Emissions Test (July 10, 2007) Report 12Unit 7 Particulate Emissions Test (July 11, 2007) Report 13Unit 8 Particulate Emissions Test (June 5, 2007) Report 14Unit 9 Particulate Emissions Test (July 13, 2007) Report 15Unit 10 Particulate Emissions Test (June 6, 2007) Report 16Unit 6 Particulate Emissions Test (June 25, 2008) Report 17Unit 7 Particulate Emissions Test (June 27, 2008) Report 18Units 8, 9, and 10 Particulate Emissions Test (June 27, 2008) Report 19Unit 6 Particulate Emissions Test (July 1, 2009) Report 20Unit 7 Particulate Emissions Test (July 1, 2009) Report 21Units 8, 9, and 10 Particulate Emissions Test (July 30, 2009) Report 22Unit 6 Compliance Assurance Monitoring Test (September 6, 2007) Report 23Unit 7 Compliance Assurance Monitoring Test (July 12, 2007) Report 24Unit 9 Compliance Assurance Monitoring Test (November 30, 2007) Report 25Unit 10 Compliance Assurance Monitoring Test (June 7, 2007) Report 26Units 8, 9, and 10 Scrubber Performace Test (January 21 - February 1, 2008)

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: 6/15/2005 Type: duct Constituents: PM Report 2 Date: 6/16/2005 Type: duct Constituents: PM Report 3 Date: 6/8/2005 Type: duct Constituents: PM Report 4 Date: 6/7/2005 Type: duct Constituents: PM Report 5 Date: 6/9/2005 Type: duct Constituents: PM Report 6 Date: 7/12/2006 Type: duct Constituents: PM Report 7 Date: 7/11/2006 Type: duct Constituents: PM Report 8 Date: 6/9/2006 Type: duct Constituents: PM Report 9 Date: 6/8/2006 Type: duct Constituents: PM Report 10 Date: 6/13/2006 Type: duct Constituents: PM Report 11 Date: 7/10/2007 Type: duct Constituents: PM Report 12 Date: 7/11/2007 Type: duct Constituents: PM Report 13 Date: 6/5/2007 Type: duct Constituents: PM

### Report 14 Date: 7/13/2007 Type: duct Constituents: PM

Report 15 Date: 6/6/2007 Type: duct Constituents: PM Report 16 Date: 6/25/2008 Type: duct Constituents: PM Report 17 Date: 6/27/2008 Type: duct Constituents: PM Report 18 Date: 6/27/2008 Type: stack Constituents: PM Report 19 Date: 7/1/2009 Type: duct Constituents: PM Report 20 Date: 7/1/2009 Type: duct Constituents: PM Report 21 Date: 7/30/2009 Type: stack Constituents: PM Report 22 Date: 9/6/2007 Type: duct Constituents: PM Report 23 Date: 7/12/2007 Type: duct Constituents: PM Report 24 Date: 11/30/2007 Type: duct Constituents: PM Report 25 Date: 6/7/2007 Type: duct Constituents: PM Report 26 Date: 1/21 - 2/1/2008 Type: stack/duct Constituents: PM, SO2, NOx, CO, Hg, HCl, HF

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). Report 26 (Units 8, 9, and 10 Scrubber Performance Test) reflects testing both upsteam of the scrubber (scrubber inlet) and at the stack. Particulates, O2

### , CO2

### , CO, moisture, NOx

### , SO2

### , SO3

### , Hg, Ash PSD, HCl, and HF were measured at the scrubber inlet. Additionally, particulates, O2

### , CO2

### , CO, moisture, SO2

### , SO3

### , and Hg were measured at the stack. See the attached Diagram 1 for a schematic of the sampling port locations.

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

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

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

__If yes, please note which reports.

8fDid the unit's control configuration differ from that shown in Part I, question 16, at the time of these test results? Yes _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 conditions present during Reports 3, 4, 5, 8, 9, 10, 13, 14, 15, 24, and 25 (no FGD, no hydrated lime injection).

### Boiler ID 8

9

10

Note: "N/A" means not applicable.

1Sodium injection on Units 8 and 9 varies between sodium sulfate and sodium carbonate.

2When making catalyst decisions, the primary goal is to achieve the desired NOx performance, with a secondary goal of minimizing SO3formation.



### The control configuration shown below is representative of the conditions present during Reports 18, 21, and 26 (no hydrated lime injection, no SO3

### injection operating).

Boiler ID 8

9

10

Note: "N/A" means not applicable.

1Sodium injection on Units 8 and 9 varies between sodium sulfate and sodium carbonate.

2Gorgas units 8, 9, and 10 share a common FGD.

3When making catalyst decisions, the primary goal is to achieve the desired NOx performance, with a secondary goal of minimizing SO3formation. 

### PM control Other control tangential-fired (2) sodium injection1 (prior to 1991) (3) hot-side ESP (06/01/1972) (4) calcium-based wet flue gas desulfurization2 (11/01/2007)

(4) calcium-based wet flue gas desulfurization2 (11/01/2007)

(5) calcium-based wet flue gas desulfurization2 (11/01/2007) 

### Type NOx control SO2 control

tangential-fired

tangential-fired (1) low-NOx burners + closecoupled and separated OFA (05/06/2001)

(1) low-NOx burners + closecoupled and separated OFA (04/20/1995)

(1) low-NOx burners + separated OFA (12/19/1995) (3) SCR (05/23/2002) - the SCR uses a titania-vanadia based ceramic catalyst and anhydrous ammonia as the reductant; the catalyst is designed to minimize SO3formation3 

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

(2) sodium injection1 (prior to 1991) (3) hot-side ESP (06/01/1972) (2) flue gas conditioning - SO3injection (04/1985) (4) cold-side ESP (10/27/1972) N/A

N/A

N/A tangential-fired (1) low-NOx burners + closecoupled and separated OFA (04/20/1995) N/A (2) sodium injection1 (prior to 1991) (3) hot-side ESP (06/01/1972) N/A tangential-fired (1) low-NOx burners + closecoupled and separated OFA (05/06/2001) N/A (2) sodium injection1 (prior to 1991) (3) hot-side ESP (06/01/1972) N/A

tangential-fired (1) low-NOx burners + separated OFA (12/19/1995) (3) SCR (05/23/2002) - the SCR uses a titania-vanadia based ceramic catalyst and anhydrous ammonia as the reductant; the catalyst is designed to minimize SO3formation2 N/A (2) flue gas conditioning - SO3injection (04/1985) (4) cold-side ESP (10/27/1972) N/A

### 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 _X

__No ____If yes, please note which reports and, in addition to the detailed description of the location of the sampling point(s) (question 8c above), include detail about how much, if any, bypass of unscrubbed flue gas was utilized at at the time of testing (including percentage of total scrubber flue gas flow). Note by diagram where sampling ports were located in relation to the bypass ductwork. Report 26 (Units 8, 9, and 10 Scrubber Performance Test) reflects testing both upsteam of the scrubber (scrubber inlet) and at the stack. Particulates, O2

### , CO2

### , CO, moisture, NOx

### , SO2

### , SO3

### , Hg, Ash PSD, HCl, and HF were measured at the scrubber inlet. Additionally, particulates, O2

### , CO2

### , CO, moisture, SO2

### , SO3

### , and Hg were measured at the stack. See the attached Diagram 1 for a schematic of the sampling port locations. No flue gas bypassed the scrubber during this test.

### 9What type of deviation reporting is required for violations of permit requirements? Deviations from permit requirements shall be reported within 48 hours or 2 working days of such deviations, including those attributable to upset conditions as defined in the permit. The report will include the probable cause of said deviations, and any corrective actions or 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 include in each of the quarterly reports submitted to ADEM. Additionally, all deviations from permit terms and conditions are reported in the annual Title V compliance certifications, submitted to both ADEM and EPA. Note: A malfunction is not necessarily a period of non-compliance with permit terms and conditions. Not all reported deviations are considered violations of permit requirements. 11Are continuous emissions monitoring system (CEMS) data available (e.g., mercury, continuous opacity monitoring systems) that are not already being provided to the U.S. EPA, even if from short-term testing? Yes _X

__No ____If yes46

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

Mercury CEMS data are available1

### for the following periods of time:

Units 6-7: July 7, 2009 - December 31, 2009 Units 8-10: November 6, 2008 - December 31, 2009

COMS data are available for the following periods of time:

Units 6-7: June 1, 1994 - December 31, 2009 Units 8-9: 1994 - October 31, 2007 Unit 10A: 1994 - October 31, 2007 Unit 10B: 1994 - October 31, 2007

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.

46Where 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 ReportDate of test PM49 

### SO2 HCl/HF/HCN Metal HAP50 

### Hg51 

### CO Other organics (specify) 6 Report 1 6/15/2005See Attachment 1 N/A N/A N/A N/A N/A N/A 7 Report 2 6/16/2005See Attachment 2 N/A N/A N/A N/A N/A N/A 8 Report 3 6/8/2005See Attachment 3 N/A N/A N/A N/A N/A N/A 9 Report 4 6/7/2005See Attachment 4 N/A N/A N/A N/A N/A N/A 10Report 5 6/9/2005See Attachment 5 N/A N/A N/A N/A N/A N/A 6 Report 6 7/12/2006See Attachment 6 N/A N/A N/A N/A N/A N/A 7 Report 7 7/11/2006See Attachment 7 N/A N/A N/A N/A N/A N/A 8 Report 8 6/9/2006See Attachment 8 N/A N/A N/A N/A N/A N/A 9 Report 9 6/8/2006See Attachment 9 N/A N/A N/A N/A N/A N/A 10Report 10 6/13/2006See Attachment 10 N/A N/A N/A N/A N/A N/A 6 Report 11 7/10/2007See Attachment 11 N/A N/A N/A N/A N/A N/A 7 Report 12 7/11/2007See Attachment 12 N/A N/A N/A N/A N/A N/A 8 Report 13 6/5/2007See Attachment 13 N/A N/A N/A N/A N/A N/A 9 Report 14 7/13/2007See Attachment 14 N/A N/A N/A N/A N/A N/A 10Report 15 6/6/2007See Attachment 15 N/A N/A N/A N/A N/A N/A 6 Report 16 6/25/2008See Attachment 16 N/A N/A N/A N/A N/A N/A 7 Report 17 6/27/2008See Attachment 17 N/A N/A N/A N/A N/A N/A 8, 9, 10Report 18 6/27/2008See Attachment 18 N/A N/A N/A N/A N/A N/A 6 Report 19 7/1/2009See Attachment 19 N/A N/A N/A N/A N/A N/A 7 Report 20 7/1/2009See Attachment 20 N/A N/A N/A N/A N/A N/A 8, 9, 10Report 21 7/30/2009See Attachment 21 N/A N/A N/A N/A N/A N/A 6 Report 22 9/6/2007See Attachment 22 N/A N/A N/A N/A N/A N/A 7 Report 23 7/12/2007See Attachment 23 N/A N/A N/A N/A N/A N/A 9 Report 24 11/30/2007See Attachment 24 N/A N/A N/A N/A N/A N/A 10Report 25 6/7/2007See Attachment 25 N/A N/A N/A N/A N/A N/A 8, 9, 10Report 26 1/21 - 2/1/2008See Attachment 26See Attachment 29See Attachment 27 N/A See Attachment 28See Attachment 27 N/A

Note: "N/A" means not applicable.

47Provide 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.

48For each emissions test run the respondent should provide the following process information: Unit Load (MW), Net generation during run (MWh net), Flue gas moisture content (%), Flue gas flow rate (dscfm or Nm3/hr), Flue gas oxygen content (%, dry), Flue gas carbon dioxide content (%, dry), Flue gas temperature at sampling point (oF), Flue gas pressure at sampling point (atm), Standard temperature (oF), Standard pressure (atm).

49If 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. 50Metal 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.

51Please 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

## DIAGRAM 1 - Sampling Port Locations for Units 8, 9, and 10

Scrubber Performance Testing (Report 26)

FLUE GAS FromBoilers

FGD GAS INLET FGD GAS Outlet GAS TO STACK FGD BYPASS

DAMPER,100% CLOSED DURING ALL TESTING.

FGD INLET SAMPLE PORTS FGD OUTLET SAMPLE PORTS FLUE GAS

ADDITIONAL TESTPORTS IN STACK

## ATTACHMENT 1 - Gorgas Report 1 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/15/20056/15/20056/15/2005 Sampling Time -Start Military 0900 1110 1318 Sampling Time -Stop Military 1101 1311 1519 Number of Ports dimensionless 12 12 12 Number of Points per Port dimensionless 5 5 5 Heat Input Million Btu per Hour 1,200 1,189 1,184 Stack Static Pressure Inches Water 0.75 0.75 0.75 Barometric Pressure Inches Mercury 29.97 29.97 29.97 Meter Correction Factor dimensionless 0.999 0.999 0.999 Oxygen Concentration Mole Percent O2 6.3 6.5 6.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 12.0 Volume of Gas Metered Actual Cubic Feet 67.120 63.650 62.645 Volume of Water Collected Milliliters 98.00 101.00 91.00 Sampling Time Minutes 120 120 120 Nozzle Diameter Inches 0.218 0.211 0.215 Weight of Solids Collected Milligrams 96.0 134.1 50.3 Area of Stack Square Feet 162.000162.000162.000 Avg. Sqr. Root Velocity PressureInches Water 0.8058 0.8135 0.8077 Average Orifice Pressure(DH) Inches Water 1.2 1.1 1.2 Average Stack Temperature Degrees F 301 305 305 Average Meter Temperature Degrees F 94 100 104 Average Generation MW 114 114 114

3 Runs RUN 1 RUN 2 RUN 3Average

Volume of Gas Sampled Standard Dry 64.205 60.190 58.89061.095 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.35 29.29 29.3529.33

Water vapor in Stack Gas Percent 6.7 7.3 6.8 6.9

Average Stack Gas Velocity Feet per second 53.8 54.5 54.0 54.1

Stack Gas Flow Rate Actual Cubic 522,653529,511525,236525,800 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 363,659366,671363,593364,641 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 339,282339,830338,940339,351 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 25,412 25,453 25,38725,417 Per Minute Particulate Concentration Grains per Standard 0.0230 0.0343 0.01320.0235 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0149 0.0220 0.00850.0152 Cubic Foot Particulate Emission Rate Pounds per Hour 67.0 99.9 38.2 68.4

Particulate Emission Rate Pounds per Million 0.056 0.084 0.0320.057 Btu (Heat Input) Isokinetic Rate Percent 98.5 98.5 93.096.7



### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 6

Calculations

### ATTACHMENT 2 - Gorgas Report 2 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Standard Orifice PressureDH@ Inches Water 2.34 2.34 2.34 Date Month/Day/Year 6/16/20056/16/20056/16/2005 Sampling Time -Start Military 0737 0945 1154 Sampling Time -Stop Military 0938 1147 1355 Number of Ports dimensionless 12 12 12 Number of Points per Port dimensionless 5 5 5 Heat Input Million Btu per Hour 1,241 1,216 1,230 Stack Static Pressure Inches Water 0.65 0.65 0.65 Barometric Pressure Inches Mercury 30.01 30.01 30.01 Meter Correction Factor dimensionless 0.999 0.999 0.999 Oxygen Concentration Mole Percent O2 6.0 6.0 6.3 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 12.0 Volume of Gas Metered Actual Cubic Feet 60.940 65.940 61.135 Volume of Water Collected Milliliters 101.00 104.00 93.00 Sampling Time Minutes 120 120 120 Nozzle Diameter Inches 0.204 0.209 0.208 Weight of Solids Collected Milligrams 63.6 64.7 37.9 Area of Stack Square Feet 162.000162.000162.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.8123 0.8335 0.7856 Average Orifice Pressure(DH) Inches Water 1.0 1.2 1.1 Average Stack Temperature Degrees F 293 295 294 Average Meter Temperature Degrees F 92 97 103 Average Generation MW 115 115 115

3 Runs RUN 1 RUN 2 RUN 3Average

Volume of Gas Sampled Standard Dry 58.519 62.797 57.63959.652 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.25 29.28 29.3129.28

Water vapor in Stack Gas Percent 7.5 7.2 7.1 7.3

Average Stack Gas Velocity Feet per second 54.0 55.4 52.2 53.9

Stack Gas Flow Rate Actual Cubic 524,766538,651507,360523,592 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 369,401378,522356,635368,186 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 341,646351,148331,461341,418 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 25,589 26,301 24,82625,572 Per Minute Particulate Concentration Grains per Standard 0.0167 0.0159 0.01010.0142 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0109 0.0103 0.00660.0093 Cubic Foot Particulate Emission Rate Pounds per Hour 49.0 47.8 28.841.8

Particulate Emission Rate Pounds per Million 0.039 0.039 0.0230.034 Btu (Heat Input) Isokinetic Rate Percent 101.9 101.3 99.5100.9 Post Test Meter Correction Factordimensionless 0.97 0.97 1.000.981

Percent Difference Allowed 5% 2.8 2.5 0.2 1.8



### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 7

Calculations

## ATTACHMENT 3 - Gorgas Report 3 Test Results

Title of Run RUN 1RUN 2RUN 3aRUN 3b Date Month/Day/Year 6/8/20056/8/20056/8/20056/8/2005 Sampling Time -Start Military 0758075810211021 Sampling Time -Stop Military 1006100611251124 Number of Ports dimensionless 16 16 8 8 Number of Points per Port dimensionless 4 4 4 4 Heat Input Million Btu per Hour1,7561,7561,7261,726 Stack Static Pressure Inches Water -12.00-12.00-12.00-12.00 Barometric Pressure Inches Mercury 29.9529.9529.9529.95 Meter Correction Factor dimensionless 1.0461.0111.0111.046 Oxygen Concentration Mole Percent O2 7.5 7.0 7.0 8.8 Carbon Dioxide Concentration Mole Percent CO2 12.5 12.5 12.5 10.5 Volume of Gas Metered Actual Cubic Feet 73.64676.53538.64938.891 Volume of Water Collected Milliliters 115 145 79 66 Sampling Time Minutes 128 128 64 64 Nozzle Diameter Inches 0.2420.2500.2500.242 Weight of Solids Collected Milligrams 18.025.536.6 17.0 Area of Stack Square Feet 232.500232.500116.250116.250 Avg. Sqr. Root Velocity Pressure Inches Water 0.68040.69770.69510.7134 Average Orifice Pressure(H) Inches Water 1.4 1.4 1.4 1.5 Average Stack Temperature Degrees F 309 299 291 312 Average Meter Temperature Degrees F 77 81 88 79 Average Generation MW 177 177 178 178

Split RUN 1RUN 2RUN 3aRUN 3bAverage

Volume of Gas Sampled Standard Dry 76.16475.87337.82040.06163.659 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.4829.2729.1829.1629.308

Water vapor in Stack Gas Percent 6.6 8.3 9.0 7.27.654

Average Stack Gas Velocity Feet per second 46.347.347.048.947.166

Stack Gas FlowRate Actual Cubic 645,365660,047327,554340,940657,969 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic430,623446,053223,679226,476442,277 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic402,049409,240203,655210,177408,374 Feet Per Minute Stack Gas FlowRate Pounds of Dry Air 30,11330,65215,25415,74230,587 Per Minute Particulate Concentration Grains per Standard0.00360.00520.01490.00650.00651 Dry Cubic Foot Particulate Concentration Grains per Actual 0.00230.00320.00930.00400.00404 Cubic Foot Particulate Emission Rate Pounds per Hour 12.5 18.226.0 11.8 22.8

Particulate Emission Rate Pounds per Million 0.0070.0100.0150.0070.013 Allowable Particulate Emission Rate Btu (Heat Input) 0.120.120.120.12 0.12 Isokinetic Rate Percent 107.798.898.9108.4 

### TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY GORGAS STEAM PLANT, UNIT 8

6/8/2005

Calculations

## ATTACHMENT 4 - Gorgas Report 4 Test Results

Title of Run RUN 1RUN 2RUN 3aRUN 3b Date Month/Day/Year 6/7/20056/7/20056/7/20056/7/2005 Sampling Time -Start Military 1055 1055 1318 1318 Sampling Time -Stop Military 1304 1305 1422 1422 Number of Ports dimensionless 16 16 8 8 Number of Points per Port dimensionless 4 4 4 4 Heat Input Million Btu per Hour 1,652 1,652 1,641 1,641 Stack Static Pressure Inches Water -12.00-12.00-12.00-12.00 Barometric Pressure Inches Mercury 30.05 30.05 30.05 30.05 Meter Correction Factor dimensionless 1.011 1.046 1.011 1.046 Oxygen Concentration Mole Percent O2 7.0 6.0 7.5 8.0 Carbon Dioxide Concentration Mole Percent CO2 11.0 11.0 10.5 10.0 Volume of Gas Metered Actual Cubic Feet 74.45974.89041.13036.839 Volume of Water Collected Milliliters 144 137 67 86 Sampling Time Minutes 128 128 64 64 Nozzle Diameter Inches 0.242 0.241 0.245 0.245 Weight of Solids Collected Milligrams 41.2 44.0 18.1 20.0 Area of Stack Square Feet 232.500232.500116.250116.250 Avg. Sqr. Root Velocity Pressure Inches Water 0.73330.76050.75940.7300 Average Orifice Pressure(DH) Inches Water 1.3 1.5 1.5 1.4 Average Stack Temperature Degrees F 296 298 302 294 Average Meter Temperature Degrees F 85 84 88 84 Average Generation MW 186 186 186 186

Split RUN 1RUN 2RUN 3aRUN 3bAverage

Volume of Gas Sampled Standard Dry 73.52776.67940.39437.72563.089 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.02 29.07 29.11 28.7629.01

Water vapor in Stack Gas Percent 8.4 7.8 7.2 9.7 8.2

Average Stack Gas Velocity Feet per second 49.8 51.6 51.6 49.7 50.7

Stack Gas Flow Rate Actual Cubic 694,032720,384360,140346,499707,019 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 472,453488,865243,374236,584480,425 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 432,576450,942225,749213,658440,975 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 32,40033,77616,90916,00333,029 Per Minute Particulate Concentration Grains per Standard 0.00860.00880.00690.00820.0083 Dry Cubic Foot Particulate Concentration Grains per Actual 0.00540.00550.00430.00500.0052 Cubic Foot Particulate Emission Rate Pounds per Hour 32.0 34.2 13.4 15.0 31.5

Particulate Emission Rate Pounds per Million 0.01940.02070.00810.00910.0191 Allowable Particulate Emission RateBtu (Heat Input) 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 96.6 97.5 99.3 97.9



### TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY GORGAS STEAM PLANT, UNIT 9

6/7/2005

Calculations

### ATTACHMENT 5 - Gorgas Report 5 Test Results

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

Title of Run RUN 1 RUN 2RUN 3 RUN 1 RUN 2RUN 3 Date Month/Day/Year 6/9/20056/9/20056/9/2005 6/9/20056/9/20056/9/2005 Sampling Time -Start Military 0750 0925 1125 0750 0948 1125 Sampling Time -Stop Military 0900 1100 1236 0850 1100 1236 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Heat Input Million Btu per Hour 7,329 7,405 7,388 7,329 7,405 7,388 Stack Static Pressure Inches Water -13.00-13.00-13.00 -13.00-13.00-13.00 Barometric Pressure Inches Mercury 29.98 29.98 29.98 29.98 29.98 29.98 Meter Correction Factor dimensionless 1.046 1.046 1.046 1.011 1.011 1.011 Oxygen Concentration Mole Percent O2 6.5 7.0 7.0 5.8 5.0 7.0 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 11.5 13.0 12.0 11.0 Volume of Gas Metered Actual Cubic Feet 39.21741.21241.887 37.56940.46042.554 Volume of Water Collected Milliliters 57.00 88.00 69.00 56.00 72.00 83.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.242 0.240 0.240 0.242 0.242 0.242 Weight of Solids Collected Milligrams 14.1 28.9 26.0 17.5 26.2 27.1 Area of Stack Square Feet 370.0 370.0 370.0 370.0 370.0 370.0 Avg. Sqr. Root Velocity Pressure Inches Water 0.91180.92280.9205 0.82210.86780.8815 Average Orifice Pressure(DH) Inches Water 2.1 2.1 2.1 1.7 1.8 1.9 Average Stack Temperature Degrees F 324 314 304 291 303 314 Average Meter Temperature Degrees F 74 77 80 75 77 84 Average Generation MW 696 696 690 696 696 690

Side A Side A Side A3 RunsSide B Side B Side B3 Runs RUN 1 RUN 2RUN 3AverageRUN 1 RUN 2RUN 3Average

Volume of Gas Sampled Standard Dry 40.82542.66043.11842.20137.74840.47642.03540.086 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.43 29.12 29.27 29.27 29.51 29.18 29.02 29.24

Water vapor in Stack Gas Percent 6.2 8.9 7.0 7.3 6.5 7.7 8.5 7.6

Average Stack Gas Velocity Feet per second 62.7 63.4 62.7 62.9 55.3 59.1 60.7 58.4

Stack Gas Flow Rate Actual Cubic 1,391,9001,407,0481,391,6571,396,8681,226,9781,312,5811,346,8791,295,480 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 909,651931,483932,348924,494836,732881,177891,190869,700 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 853,555849,044867,038856,546782,117813,097815,404803,539 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 63,93163,59364,94164,15558,58160,90161,07460,185 Per Minute Particulate Concentration Grains per Standard 0.00530.01040.00930.00830.00710.01000.00990.0090 Dry Cubic Foot Particulate Concentration Grains per Actual 0.00330.00630.00580.00510.00460.00620.00600.0056 Cubic Foot Particulate Emission Rate Pounds per Hour 38.9 75.9 69.0 61.3 47.9 69.5 69.4 62.2

Particulate Emission Rate Pounds per Million 0.00530.01030.00930.00830.00650.00940.00940.0084 Btu (Heat Input) Combined Particulate Emission Rate Pounds per Million 0.01180.01960.01870.0167 Allowable Particulate Emission Rate Btu 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 92.3 98.6 97.6 93.2 96.1 99.5 TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY GORGAS STEAM PLANT, UNIT 10

6/9/2005

Calculations

### ATTACHMENT 6 - Gorgas Report 6 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 7/12/20067/12/20067/12/2006 7/12/20067/12/20067/12/2006 Sampling Time -Start Military 1037 1241 1355 1037 1241 1355 Sampling Time -Stop Military 1137 1341 1455 1137 1341 1455 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 1,133 1,135 1,137 1,133 1,135 1,137 Stack Static Pressure Inches Water 0.70 0.70 0.70 0.65 0.65 0.65 Barometric Pressure Inches Mercury 30.02 30.02 30.02 30.02 30.02 30.02 Meter Correction Factor dimensionless 0.982 0.982 0.982 0.995 0.995 0.995 Oxygen Concentration Mole Percent O2 7.5 8.0 7.5 8.0 8.0 8.5 Carbon Dioxide Concentration Mole Percent CO2 11.0 11.5 11.0 11.0 11.0 11.0 Volume of Gas Metered Actual Cubic Feet 33.572 36.535 36.595 37.015 37.200 36.560 Volume of Water Collected Milliliters 51.00 68.00 59.00 78.00 54.00 56.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.215 0.228 0.228 0.220 0.220 0.220 Weight of Solids Collected Milligrams 82.0 53.2 79.1 40.6 28.2 25.3 Area of Stack Square Feet 81.0 81.0 81.0 81.0 81.0 81.0 Avg. Sqr. Root Velocity Pressure Inches Water 0.8316 0.8032 0.8079 0.8430 0.8605 0.8515 Average Orifice Pressure(DH) Inches Water 1.3 1.5 1.5 1.3 1.3 1.2 Average Stack Temperature Degrees F 339 322 336 330 334 344 Average Meter Temperature Degrees F 92 94 95 101 99 103 Average Generation MW 114 114 114 114 114 114

Side A Side A Side ASide ASide B Side B Side BSide B RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average

Volume of Gas Sampled Standard Dry 31.773 34.422 34.45333.549 34.919 35.217 34.35234.830 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.21 29.13 29.1629.17 28.93 29.27 29.2429.15

Water vapor in Stack Gas Percent 7.0 8.5 7.5 7.7 9.5 6.7 7.1 7.8

Average Stack Gas Velocity Feet per second 56.9 54.5 55.3 55.6 57.7 58.7 58.5 58.3

Stack Gas Flow Rate Actual Cubic 276,729264,844268,591270,054280,281285,206284,113283,200 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 183,749179,666179,032180,816188,253190,539187,486188,759 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 170,841164,381165,678166,967170,343177,713174,125174,060 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 12,796 12,312 12,40912,506 12,759 13,311 13,04213,037 Per Minute Particulate Concentration Grains per Standard 0.0397 0.0238 0.03540.0330 0.0179 0.0123 0.01130.0139 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0245 0.0148 0.02180.0204 0.0109 0.0077 0.00700.0085 Cubic Foot Particulate Emission Rate Pounds per Hour 58.2 33.5 50.247.3 26.1 18.8 16.9 20.6

Particulate Emission Rate Pounds per Million 0.0514 0.0295 0.04420.0417 0.0231 0.0165 0.01490.0182 Btu (Heat Input) Combined Particulate Emission RatePounds per Million 0.0744 0.0461 0.05900.0599 Allowable Particulate Emission RateBtu 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 99.6 99.7 99.0 104.8 101.3 100.9 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 6

Calculations

### ATTACHMENT 7 - Gorgas Report 7 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 7/11/20067/11/20067/11/2006 7/11/20067/11/20067/11/2006 Sampling Time -Start Military 0908 1023 1137 0908 1023 1137 Sampling Time -Stop Military 1008 1123 1237 1008 1123 1237 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 1,160 1,155 1,160 1,160 1,155 1,160 Stack Static Pressure Inches Water 0.65 0.65 0.65 0.60 0.60 0.60 Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10 30.10 30.10 Meter Correction Factor dimensionless 0.995 0.995 0.995 0.982 0.982 0.982 Oxygen Concentration Mole Percent O2 7.0 7.0 7.0 6.5 6.5 7.0 Carbon Dioxide Concentration Mole Percent CO2 11.0 11.0 11.0 12.0 11.5 11.5 Volume of Gas Metered Actual Cubic Feet 35.420 33.725 36.610 38.710 38.768 40.922 Volume of Water Collected Milliliters 84.00 57.00 57.00 80.00 64.00 68.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.220 0.217 0.220 0.215 0.210 0.217 Weight of Solids Collected Milligrams 40.5 45.2 36.9 66.8 78.1 66.0 Area of Stack Square Feet 81.0 81.0 81.0 81.0 81.0 81.0 Avg. Sqr. Root Velocity Pressure Inches Water 0.8027 0.7855 0.8187 0.9663 0.9959 0.9935 Average Orifice Pressure(DH) Inches Water 1.2 1.1 1.3 1.9 1.8 2.0 Average Stack Temperature Degrees F 292 296 304 298 303 306 Average Meter Temperature Degrees F 96 106 106 93 96 95 Average Generation MW 115 115 116 115 115 116

Side A Side A Side A3 RunsSide B Side B Side B3 Runs RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average

Volume of Gas Sampled Standard Dry 33.767 31.607 34.31833.231 36.701 36.554 38.66037.305 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 30.04 29.10 29.1729.43 29.05 29.18 29.1929.14

Water vapor in Stack Gas Percent 10.5 7.8 7.3 8.5 9.3 7.6 7.6 8.2

Average Stack Gas Velocity Feet per second 52.5 52.4 54.8 53.2 64.6 66.6 66.5 65.9

Stack Gas Flow Rate Actual Cubic 255,294254,489266,296258,693313,730323,534323,341320,202 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 180,492178,995185,370181,619220,130225,669224,640223,480 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 161,573164,989171,929166,164199,646208,487207,464205,199 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 12,102 12,358 12,87712,446 14,953 15,616 15,53915,369 Per Minute Particulate Concentration Grains per Standard 0.0185 0.0220 0.01660.0190 0.0280 0.0329 0.02630.0291 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0117 0.0143 0.01070.0122 0.0178 0.0212 0.01690.0186 Cubic Foot Particulate Emission Rate Pounds per Hour 25.6 31.1 24.4 27.0 48.0 58.8 46.8 51.2

Particulate Emission Rate Pounds per Million 0.0221 0.0270 0.02100.0234 0.0414 0.0509 0.04030.0442 Btu (Heat Input) Combined Particulate Emission RatePounds per Million 0.0634 0.0779 0.06130.0675 Allowable Particulate Emission RateBtu 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 106.9 100.7 102.1 98.4 98.4 97.9 

### TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY GORGAS STEAM PLANT, UNIT 7

7/11/2006

Calculations

### ATTACHMENT 8 - Gorgas Report 8 Test Report

Title of Run RUN 1RUN 2RUN 3ARUN 3B Date Month/Day/Year 6/9/20066/9/20066/9/20066/9/2006 Sampling Time -Start Military 0807 0807 1026 1026 Sampling Time -Stop Military 1015 1015 1130 1130 Number of Ports dimensionless 16 16 8 8 Number of Points per Port dimensionless 4 4 4 4 Heat Input Million Btu per Hour 1,621 1,621 1,610 1,610 Stack Static Pressure Inches Water -12.00-12.00-12.00-12.00 Barometric Pressure Inches Mercury 30.14 30.14 30.14 30.14 Standard Orifice PressureDH@ Inches Water 1.960 2.084 1.960 2.084 Meter Correction Factor dimensionless 1.011 0.957 1.011 0.957 Oxygen Concentration Mole Percent O2 6.8 5.5 6.0 5.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 11.5 12.0 11.0 Volume of Gas Metered Actual Cubic Feet 77.90079.24538.35038.200 Volume of Water Collected Milliliters 126 159 58 65 Sampling Time Minutes 128 128 64 64 Nozzle Diameter Inches 0.245 0.240 0.245 0.240 Weight of Solids Collected Milligrams 27.7 17.1 15.7 20.2 Area of Stack Square Feet 232.500232.500116.250116.250 Avg. Sqr. Root Velocity Pressure Inches Water 0.73640.71000.66790.7244 Average Orifice Pressure(DH) Inches Water 1.4 1.3 1.2 1.4 Average Stack Temperature Degrees F 285 296 283 308 Average Meter Temperature Degrees F 80 88 96 87 Average Generation MW 177 177 177 177

RUN 1RUN 2RUN 3ARUN 3BAVERAGE

Volume of Gas Sampled Standard Dry 77.85173.84937.23335.68762.720 Cubic Feet Molecular Wt. of Stack Gas (wet) LB/LB-MOLE 29.33 28.95 29.33 29.03 29.15

Water vapor in Stack Gas Percent 7.1 9.2 6.8 7.9 7.9

Average Stack Gas Velocity Feet per second 49.3 48.2 44.6 49.5 48.2

Stack Gas Flow Rate Actual Cubic 687,199671,814311,120344,974671,702 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 476,276458,730216,304231,827461,046 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 442,561416,518201,527213,521424,709 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 33,14831,19715,09415,99331,811 Per Minute Particulate Concentration Grains per Standard 0.00550.00360.00650.00870.0056 Dry Cubic Foot Particulate Concentration Grains per Actual 0.00350.00220.00420.00540.0035 Cubic Foot Particulate Emission Rate Pounds per Hour 20.8 12.7 11.2 16.0 20.2

Particulate Emission Rate Pounds per Million 0.013 0.008 0.007 0.0100.013 Allowable Particulate Emission RateBtu (Heat Input) 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 97.6 102.5 102.5 96.6 100.9

Post Test Meter Correction Factordimensionless 1.05 0.98 0.99 1.04 1.01

Percent Difference Allowed 5% 3.71 1.90 -1.87 8.28 3.01 TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 8

Calculations

### ATTACHMENT 9 - Gorgas Report 9 Test Results

Title of Run RUN 1RUN 2RUN 3ARUN 3B Date Month/Day/Year 6/8/20066/8/20066/8/20066/8/2006 Sampling Time -Start Military 0756 0756 1015 1015 Sampling Time -Stop Military 1004 1004 1119 1119 Number of Ports dimensionless 16 16 8 8 Number of Points per Port dimensionless 4 4 4 4 Heat Input Million Btu per Hour 1,584 1,584 1,581 1,581 Stack Static Pressure Inches Water -12.00-12.00-12.00-12.00 Barometric Pressure Inches Mercury 30.00 30.00 30.00 30.00 Standard Orifice PressureDH@ Inches Water 2.084 1.960 2.084 1.960 Meter Correction Factor dimensionless 0.957 1.011 0.957 1.011 Oxygen Concentration Mole Percent O2 6.0 6.0 7.5 5.0 Carbon Dioxide Concentration Mole Percent CO2 11.8 11.3 10.5 12.0 Volume of Gas Metered Actual Cubic Feet 80.04581.50042.45540.100 Volume of Water Collected Milliliters 148 137 70 75 Sampling Time Minutes 128 128 64 64 Nozzle Diameter Inches 0.240 0.245 0.240 0.245 Weight of Solids Collected Milligrams 31.2 48.3 18.5 21.6 Area of Stack Square Feet 232.500232.500116.250116.250 Avg. Sqr. Root Velocity Pressure Inches Water 0.75740.74730.78140.7427 Average Orifice Pressure(DH) Inches Water 1.5 1.5 1.6 1.5 Average Stack Temperature Degrees F 285 279 279 298 Average Meter Temperature Degrees F 89 80 98 87 Average Generation MW 183 183 183 183

RUN 1RUN 2RUN 3ARUN 3BAVERAGE

Volume of Gas Sampled Standard Dry 74.12881.12838.68539.42164.770 Cubic Feet Molecular Wt. of Stack Gas (wet) LB/LB-MOLE 29.08 29.15 29.04 29.12 29.10

Water vapor in Stack Gas Percent 8.6 7.4 7.8 8.2 8.0

Average Stack Gas Velocity Feet per second 51.0 50.0 52.4 50.4 50.8

Stack Gas Flow Rate Actual Cubic 711,699698,188365,709351,548709,048 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 490,608485,644254,390238,374489,672 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 448,463449,884234,423218,781450,517 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 33,59033,69617,55816,38733,744 Per Minute Particulate Concentration Grains per Standard 0.00650.00920.00740.00840.0079 Dry Cubic Foot Particulate Concentration Grains per Actual 0.00410.00590.00470.00530.0050 Cubic Foot Particulate Emission Rate Pounds per Hour 24.9 35.4 14.8 15.8 30.3

Particulate Emission Rate Pounds per Million 0.016 0.022 0.009 0.0100.019 Allowable Particulate Emission RateBtu (Heat Input) 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 95.5 100.0 95.4 99.9 97.0

Post Test Meter Correction Factordimensionless 1.03 1.04 1.00 1.04 1.03

Percent Difference Allowed 5% 7.03 3.01 4.51 3.14 4.42 TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 9

CalculationsATTACHMENT 10 - Gorgas Report 10 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 6/13/20066/13/20066/13/2006 6/13/20066/13/20066/13/2006 Sampling Time -Start Military 0827 1003 1137 0827 1003 1137 Sampling Time -Stop Military 0944 1115 1250 0944 1115 1250 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Heat Input Million Btu per Hour 6,494 6,528 6,520 6,494 6,528 6,520 Stack Static Pressure Inches Water -24.00 -24.00 -24.00 -24.00 -24.00 -24.00 Barometric Pressure Inches Mercury 30.02 30.02 30.02 30.02 30.02 30.02 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 7.5 7.5 6.5 7.0 7.0 Carbon Dioxide Concentration Mole Percent CO2 10.0 11.0 11.0 12.0 11.5 12.0 Volume of Gas Metered Actual Cubic Feet 41.651 41.495 41.848 40.093 42.964 44.496 Volume of Water Collected Milliliters 70 67 70 57 68 66 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.230 0.230 0.230 0.230 0.232 0.232 Weight of Solids Collected Milligrams 29.5 23.5 20.8 33.3 18.7 23.8 Area of Stack Square Feet 370.000370.000370.000 370.000370.000370.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.9022 0.8874 0.8937 0.8218 0.8854 0.9210 Average Orifice Pressure(DH) Inches Water 1.6880 1.6290 1.6570 1.7100 2.1213 2.2730 Average Stack Temperature Degrees F 314 316 319 300 301 302 Average Meter Temperature Degrees F 74 78 83 81 90 97 Average Generation MW 696 696 696 696 696 696

A Side A Side A SideA Side B Side B Side B Side B Side RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average

Volume of Gas Sampled Standard Dry 40.164 39.695 39.67639.845 37.006 39.039 39.89938.648 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.92 30.06 30.06 30.01 30.18 30.12 30.20 30.17

Water vapor in Stack Gas Percent 7.6 7.4 7.7 7.5 6.8 7.6 7.2 7.2

Average Stack Gas Velocity Feet per second 62.9 61.8 62.4 62.4 56.5 61.0 63.4 60.3

Stack Gas Flow Rate Actual Cubic 1,396,9031,372,6161,385,4701,384,9961,253,6841,355,1681,408,2861,339,046 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 900,154881,502886,786889,481822,471887,920920,786877,059 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 831,907816,623818,789822,440766,873820,636854,270813,926 Feet Per Minute Particulate Concentration Grains per Standard 0.0113 0.0091 0.00810.0095 0.0139 0.0074 0.00920.0101 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0067 0.0054 0.00480.0056 0.0085 0.0045 0.00560.0062 Cubic Foot Particulate Emission Rate Pounds per Hour 80.7 63.8 56.7 67.0 91.1 51.9 67.3 70.1

Particulate Emission Rate Pounds per Million 0.012 0.010 0.009 0.010 0.014 0.008 0.010 0.011 Btu (Heat Input) Isokinetic Rate Percent 103.2 103.9 103.5 103.5 103.1 99.9 98.1 100.4

Post Test Meter Correction Factor dimensionless 0.98 0.97 0.97 0.97 0.94 0.99 0.99 0.97

Percent Difference Allowed 5% 1.01 -0.19 0.24 0.35 0.30 4.87 5.35 3.51

Combined Particulate Emission RatePounds per Million 0.026 0.018 0.019 0.021 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 TABLE I. PARTICULATE EMISSIONS TEST RESULTS

ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 10

Calculations

### ATTACHMENT 11 - Gorgas 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 7/10/20077/10/20077/10/20077/10/20077/10/20077/10/2007 Sampling Time -Start Military 0743 0908 1034 0743 0908 1034 Sampling Time -Stop Military 0843 1008 1134 0843 1008 1134 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 1,116 1,097 1,094 1,116 1,097 1,094 Stack Static Pressure Inches Water 1.05 1.05 1.05 0.75 0.75 0.75 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 0.937 0.937 0.937 Oxygen Concentration Mole Percent O2 9.3 9.0 8.0 9.3 9.5 6.5 Carbon Dioxide Concentration Mole Percent CO2 11.8 11.5 10.3 11.5 11.5 10.0 Volume of Gas Metered Actual Cubic Feet 35.181 40.326 36.912 34.216 38.876 32.324 Volume of Water Collected Milliliters 57 59 67 58 60 60 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.221 0.230 0.222 0.219 0.233 0.219 Weight of Solids Collected Milligrams 89.1 48.2 103.9 49.3 39.2 40.3 Area of Stack Square Feet 81.00 81.00 81.00 81.00 81.00 81.00 Avg. Sqr. Root Velocity Pressure Inches Water 0.8248 0.8459 0.8521 0.7567 0.7856 0.7737 Average Orifice Pressure(DH) Inches Water 1.2 1.5 1.3 1.2 1.7 1.3 Average Stack Temperature Degrees F 318 319 322 309 311 311 Average Meter Temperature Degrees F 81 86 92 85 91 92 Average Generation MW 115 115 115 115 115 115

Side A Side A Side A Side B Side B Side BSide ASide B Combined RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AverageAverageAverage/Total

Volume of Gas Sampled Standard Dry 33.991 38.609 34.954 31.350 35.289 29.24735.85131.962 33.907 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.25 30.20 29.96 30.21 30.22 29.8630.1430.10 30.12

Water vapor in Stack Gas Percent 7.3 6.7 8.3 8.0 7.4 8.8 7.4 8.1 7.8

Average Stack Gas Velocity Feet per second 55.5 56.9 57.8 50.7 52.7 52.3 56.8 51.9 54.3

Stack Gas Flow Rate Actual Cubic 269,660276,704281,138246,570255,985254,271275,834252,275 528,109 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 184,607189,065191,521170,660176,686175,518188,398174,288 362,686 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 171,102176,379175,671156,989163,594160,062174,384160,215 334,599 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 12,816 13,211 13,158 11,758 12,253 11,98913,06112,000 25,061 Per Minute Particulate Concentration Grains per Standard 0.040 0.019 0.046 0.024 0.017 0.0210.0350.021 0.028 Dry Cubic Foot Particulate Concentration Grains per Actual 0.026 0.012 0.029 0.015 0.011 0.0130.0220.013 0.018 Cubic Foot Particulate Emission Rate Pounds per Hour 59.2 29.1 68.9 32.6 24.0 29.1 52.428.6 81.0

Particulate Emission Rate Pounds per Million 0.053 0.026 0.063 0.029 0.022 0.0270.0480.026 0.073 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.120.120.12 0.12 Isokinetic Rate Percent 100.7 102.4 99.9 103.0 98.3 94.3

Post Test Meter Correction Check (Yqa)dimensionless 0.99 0.96 0.99 0.93 0.95 1.01 0.980.96

Percent Difference Allowed 5% 0.4 -2.2 1.2 -0.5 1.6 7.1 -0.2 2.7 Calculations TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 6

### ATTACHMENT 12 - Gorgas 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 7/11/20077/11/20077/11/20077/11/20077/11/20077/11/2007 Sampling Time -Start Military 0744 0906 1029 0744 0906 1029 Sampling Time -Stop Military 0844 1006 1129 0844 1006 1129 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 1,119 1,112 1,096 1,119 1,112 1,096 Stack Static Pressure Inches Water 0.95 0.95 0.95 0.60 0.60 0.60 Barometric Pressure Inches Mercury 30.00 30.00 30.00 30.00 30.00 30.00 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 8.3 8.0 7.8 8.0 8.0 7.0 Carbon Dioxide Concentration Mole Percent CO2 9.5 9.5 8.5 10.0 11.0 12.0 Volume of Gas Metered Actual Cubic Feet 39.848 40.297 39.389 42.140 40.111 42.798 Volume of Water Collected Milliliters 70 62 61 86 76 79 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.221 0.219 0.219 0.219 0.233 0.219 Weight of Solids Collected Milligrams 33.2 10.4 33.5 91.3 130.9 78.1 Area of Stack Square Feet 81.00 81.00 81.00 81.00 81.00 81.00 Avg. Sqr. Root Velocity Pressure Inches Water 0.9163 0.9318 0.9252 0.9331 0.9520 0.9422 Average Orifice Pressure(DH) Inches Water 1.9 1.9 1.8 1.8 1.6 1.8 Average Stack Temperature Degrees F 325 325 326 316 322 323 Average Meter Temperature Degrees F 83 82 82 88 88 90 Average Generation MW 114 114 114 114 114 114

Side A Side A Side A Side B Side B Side BSide ASide B Combined RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AverageAverageAverage/Total

Volume of Gas Sampled Standard Dry 36.657 37.163 36.280 40.157 38.141 40.58736.70039.628 38.164 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.85 29.84 29.67 29.92 30.08 30.2029.7930.07 29.93

Water vapor in Stack Gas Percent 8.2 7.3 7.3 9.2 8.6 8.4 7.6 8.7 8.2

Average Stack Gas Velocity Feet per second 62.6 63.5 63.3 63.4 64.7 63.9 63.1 64.0 63.6

Stack Gas Flow Rate Actual Cubic 304,114308,657307,512308,189314,464310,666306,761311,106 617,867 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 205,428208,524207,504210,496213,161210,389207,152211,349 418,501 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 188,486193,341192,286191,220194,882192,731191,371192,945 384,316 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 14,118 14,481 14,402 14,322 14,597 14,43614,33414,452 28,785 Per Minute Particulate Concentration Grains per Standard 0.014 0.004 0.014 0.035 0.053 0.0300.0110.039 0.025 Dry Cubic Foot Particulate Concentration Grains per Actual 0.009 0.003 0.009 0.022 0.033 0.0180.0070.024 0.016 Cubic Foot Particulate Emission Rate Pounds per Hour 22.5 7.1 23.4 57.4 88.3 49.0 17.7 64.9 82.6

Particulate Emission Rate Pounds per Million 0.020 0.006 0.021 0.051 0.079 0.0450.0160.058 0.074 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.120.120.12 0.12 Isokinetic Rate Percent 98.5 99.2 97.4 108.4 89.2 108.7

Post Test Meter Correction Check (Yqa)dimensionless 0.99 0.98 1.00 1.02 1.02 1.02 0.99 1.02

Percent Difference Allowed 5% 5.4 4.0 5.7 4.4 4.3 4.1 5.0 4.3 Calculations TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 7

### ATTACHMENT 13 - Gorgas Report 13 Test Results

Title of Run RUN 1RUN 2RUN 3ARUN 3B Date Month/Day/Year 6/5/20076/5/20076/5/20076/5/2007 Sampling Time -Start Military 0718 0718 0948 0948 Sampling Time -Stop Military 0928 0928 1052 1052 Number of Ports dimensionless 16 16 8 8 Number of Points per Port dimensionless 4 4 4 4 Heat Input Million Btu per Hour 1,573 1,573 1,600 1,600 Stack Static Pressure Inches Water -6.00 -6.00 -6.00 -6.00 Barometric Pressure Inches Mercury 30.07 30.07 30.07 30.07 Standard Orifice PressureDH@ Inches Water 2.418 1.939 1.939 2.418 Meter Correction Factor dimensionless 0.939 0.981 0.981 0.939 Oxygen Concentration Mole Percent O2 7 6 6 5 Carbon Dioxide Concentration Mole Percent CO2 11 13 13 11 Volume of Gas Metered Actual Cubic Feet 85.97983.09439.23044.755 Volume of Water Collected Milliliters 124 120 71 67 Sampling Time Minutes 128 128 64 64 Nozzle Diameter Inches 0.235 0.242 0.236 0.237 Weight of Solids Collected Milligrams 78.7 55.2 26.4 26.9 Area of Stack Square Feet 232.500232.500116.250116.250 Avg. Sqr. Root Velocity Pressure Inches Water 0.79150.78000.75120.8179 Average Orifice Pressure(DH) Inches Water 1.7 1.5 1.3 1.9 Average Stack Temperature Degrees F 297 301 289 315 Average Meter Temperature Degrees F 86 78 84 81 Average Generation MW 177 177 178 178

RUN 1RUN 2RUN 3ARUN 3BAVERAGE

Volume of Gas Sampled Standard Dry 78.79980.68237.66241.42379.522 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.04 30.32 30.32 29.96 30.23

Water vapor in Stack Gas Percent 6.9 6.5 8.2 7.1 7.2

Average Stack Gas Velocity Feet per second 53.2 52.2 50.1 55.6 51.8

Stack Gas Flow Rate Actual Cubic 741,453728,667349,396388,158606,505 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 511,984500,725243,769261,907506,128 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 476,676467,964223,901243,377470,640 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 35,70335,05016,77018,22935,251 Per Minute Particulate Concentration Grains per Standard 0.015 0.011 0.011 0.0100.012 Dry Cubic Foot Particulate Concentration Grains per Actual 0.010 0.007 0.007 0.0060.008 Cubic Foot Particulate Emission Rate Pounds per Hour 62.8 42.3 20.7 20.9 48.9

Particulate Emission Rate Pounds per Million 0.040 0.027 0.013 0.013 0.031 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 99.7 98.0 100.6 100.9 99.8

Post Test Meter Correction Factordimensionless 0.93 0.99 0.98 0.94 0.96

Percent Difference Allowed 5% -0.8 0.9 -0.3 0.2 0.0 TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 8

Calculations

### ATTACHMENT 14 - Gorgas Report 14 Test Results

Title of Run RUN 1 RUN 2RUN 3ARUN 3B Date Month/Day/Year 7/13/20077/13/20077/13/20077/13/2007 Sampling Time -Start Military 0738 0738 1002 1002 Sampling Time -Stop Military 0946 0946 1106 1106 Number of Ports dimensionless 16 8 16 8 Number of Points per Port dimensionless 4 4 4 4 Heat Input Million Btu per Hour 1,781 1,781 1,771 1,771 Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00 Barometric Pressure Inches Mercury 29.90 29.90 29.90 29.90 Standard Orifice PressureDH@ Inches Water 2.418 1.939 2.418 1.939 Meter Correction Factor dimensionless 0.939 0.981 0.939 0.981 Oxygen Concentration Mole Percent O2 9.0 9.0 6.5 9.0 Carbon Dioxide Concentration Mole Percent CO2 10.5 12.0 10.0 12.5 Volume of Gas Metered Actual Cubic Feet 102.731 94.051 48.482 43.952 Volume of Water Collected Milliliters 164 116 91 66 Sampling Time Minutes 128 128 64 64 Nozzle Diameter Inches 0.250 0.252 0.245 0.247 Weight of Solids Collected Milligrams 59.9 33.6 32.2 36.3 Area of Stack Square Feet 232.50 232.50 116.25 116.25 Avg. Sqr. Root Velocity Pressure Inches Water 0.8356 0.8041 0.8279 0.7835 Average Orifice Pressure(DH) Inches Water 2.5 1.9 2.2 1.6 Average Stack Temperature Degrees F 287 293 283 296 Average Meter Temperature Degrees F 77 81 72 78 Average Generation MW 187 187 186 186

RUN 1 RUN 2RUN 3ARUN 3BAVERAGE

Volume of Gas Sampled Standard Dry 95.467 90.372 45.382 42.429 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.04 30.28 29.86 30.36 30.14

Water vapor in Stack Gas Percent 7.5 5.7 8.6 6.8 7.0

Average Stack Gas Velocity Feet per second 56.4 54.1 56.0 52.8 55.0

Stack Gas Flow Rate Actual Cubic 786,532754,318390,666368,512766,676 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 539,224512,888269,176249,719523,669 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 498,884483,665245,961232,682487,064 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 37,366 36,227 18,422 17,42836,481 Per Minute Particulate Concentration Grains per Standard 0.010 0.006 0.011 0.013 0.009 Dry Cubic Foot Particulate Concentration Grains per Actual 0.006 0.004 0.007 0.0080.006 Cubic Foot Particulate Emission Rate Pounds per Hour 41.3 23.7 23.0 26.3 38.1

Particulate Emission Rate Pounds per Million 0.023 0.013 0.013 0.015 0.021 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 101.9 98.0 102.3 99.5

Post Test Meter Correction Check (Yqa)dimensionless 0.94 0.99 0.94 0.99

Percent Difference Allowed 5% 0.6 1.3 -0.2 0.6 TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 9

Calculations

### ATTACHMENT 15 - Gorgas Report 15 Test Results

Side ASide ASide A Side BSide BSide B

Title of Run RUN 1 RUN 2RUN 3 RUN 1 RUN 2RUN 3 Date Month/Day/Year 6/6/20076/6/20076/6/2007 6/6/20076/6/20076/6/2007 Sampling Time -Start Military 0740 1025 1200 0740 1025 1200 Sampling Time -Stop Military 0910 1133 1308 0906 1125 1300 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Heat Input Million Btu per Hour 7,186 7,313 7,369 7,186 7,313 7,369 Stack Static Pressure Inches Water -24.00-24.00-24.00 -24.00-24.00-24.00 Barometric Pressure Inches Mercury 30.06 30.06 30.06 30.06 30.06 30.06 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 6.0 5.5 5.0 8.5 6.0 5.0 Carbon Dioxide Concentration Mole Percent CO2 12.0 11.5 11.5 11.0 12.0 13.0 Volume of Gas Metered Actual Cubic Feet 46.29646.22450.920 42.36643.35545.837 Volume of Water Collected Milliliters 61 73 62 59 68 59 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.235 0.234 0.235 0.234 0.236 0.236 Weight of Solids Collected Milligrams 18.6 48.7 38.1 23.2 25.3 28.5 Area of Stack Square Feet 370.000370.000370.000 370.000370.000370.000 Avg. Sqr. Root Velocity Pressure Inches Water 0.96040.94371.0292 0.90210.89010.9414 Average Orifice Pressure(DH) Inches Water 2.4 2.2 2.8 1.7 1.7 1.9 Average Stack Temperature Degrees F 320 325 322 307 312 316 Average Meter Temperature Degrees F 73 83 87 75 87 91 Average Generation MW 716 716 716 716 716 716

Side ASide ASide ASide ASide BSide BSide BSide B RUN 1 RUN 2RUN 3AVERAGE RUN 1 RUN 2RUN 3AVERAGETOTAL

Volume of Gas Sampled Standard Dry 43.54342.60846.70344.28541.39341.46243.53442.13043.207 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.16 30.06 30.04 30.09 30.10 30.16 30.28 30.18 30.13

Water vapor in Stack Gas Percent 6.2 7.5 5.9 6.5 6.3 7.2 6.0 6.5 6.5

Average Stack Gas Velocity Feet per second 66.8 66.1 71.7 68.2 62.2 61.7 65.1 63.0 65.6

Stack Gas Flow Rate Actual Cubic 1,482,0221,466,6951,592,3331,513,6841,381,7951,369,7831,445,7441,399,1072,912,791 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 948,588933,3111,016,456966,118899,825885,244929,958905,0091,871,127 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 889,907863,661956,675903,414843,250821,804874,192846,4151,749,829 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 66,65464,68871,65567,66663,15961,55365,47763,39665,531 Per Minute Particulate Emission Rate Pounds per Hour 50.2 130.3 103.0 94.5 62.4 66.2 75.5 68.0 162.5

Particulate Emission Rate Pounds per Million 0.007 0.018 0.014 0.013 0.009 0.009 0.010 0.009 0.022 Btu (Heat Input) Combined Particulate Emission Rate 0.016 0.027 0.024 0.022 Allowable 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 100.2 101.8 99.9 100.6 101.3 102.4 101.1 101.6101.12

Post Test Meter Correction Factor dimensionless 0.95 0.93 0.94 0.94 0.98 0.98 0.98 0.98 0.96

Percent Difference Allowed 5% 0.6 -0.9 -0.1 -0.1 0.0 -0.5 -0.3 -0.2 -0.17 TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 10

Calculations

### ATTACHMENT 16 - Gorgas Report 16 Test Results

Side A Side A Side ASide B Side B Side B Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/25/20086/25/20086/25/20086/25/20086/25/20086/25/2008 Sampling Time -Start Military 0828 0954 1112 0828 0954 1112 Sampling Time -Stop Military 0928 1054 1212 0928 1054 1212 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 1,161 1,166 1,167 1,161 1,166 1,167 Stack Static Pressure Inches Water 1.20 1.20 1.20 1.00 1.00 1.00 Barometric Pressure Inches Mercury 29.94 29.94 29.94 29.94 29.94 29.94 Standard Orifice Pressure DH@ Inches Water 1.858 1.858 1.858 2.258 2.258 2.258 Meter Correction Factor dimensionless 0.978 0.978 0.978 0.982 0.982 0.982 Oxygen Concentration Mole Percent O2 7.0 6.5 5.5 8.0 6.0 6.0 Carbon Dioxide Concentration Mole Percent CO2 10.0 10.0 10.0 12.0 11.0 11.0 Volume of Gas Metered Actual Cubic Feet 41.664 42.907 42.605 35.420 37.709 38.195 Volume of Water Collected Milliliters 62.8 65.2 68.1 52.0 55.0 64.0 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.236 0.234 0.238 0.240 0.245 0.240 Weight of Solids Collected Milligrams 73.4 62.2 83.7 53.6 44.5 51.9 Area of Stack Square Feet 81.000 81.000 81.000 81.000 81.000 81.000 Avg. Sqr. Root Velocity PressureInches Water 0.8511 0.8677 0.8337 0.7144 0.7138 0.7299 Average Orifice Pressure (DH) Inches Water 1.6 1.6 1.6 1.5 1.7 1.7 Average Stack Temperature Degrees F 306 308 311 308 314 319 Average Meter Temperature Degrees F 84 91 94 88 97 105 Average Generation MW 115 115 115 115 115 115 Flowrate Weighted Side ASide BTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE

Volume of Gas Sampled Standard Dry 39.723 40.405 39.919 33.683 35.286 35.25740.01634.74274.757 Cubic Feet Molecular Wt. of Stack Gas (dry)LB/LB-MOLE 29.88 29.86 29.82 30.24 30.00 30.0029.8530.08 29.85

Water vapor in Stack Gas Percent 6.9 7.1 7.4 6.8 6.8 7.9 7.1 7.2 7.14

Average Stack Gas Velocity Feet per second 57.3 58.5 56.4 47.8 48.2 49.5 57.4 48.5 57.38

Stack Gas Flow Rate Actual Cubic 278,328284,227274,019232,435234,109240,793278,858235,779514,637 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 192,390196,066188,289160,365160,204163,587192,248161,385353,633 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 179,065182,225174,293149,501149,254150,710178,528149,821328,349 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 13,412 13,649 13,055 11,198 11,179 11,28813,37211,22224,593 Per Minute Particulate Concentration Grains per Standard 0.028 0.024 0.032 0.025 0.019 0.0230.0280.022 0.03 Dry Cubic Foot Particulate Concentration Grains per Actual 0.018 0.015 0.021 0.016 0.012 0.0140.0180.014 0.02 Cubic Foot Particulate Emission Rate Pounds per Hour 43.7 37.0 48.2 31.4 24.8 29.3 43.0 28.5 71.49

Particulate Emission Rate Pounds per Million 0.038 0.032 0.041 0.027 0.021 0.0250.0370.024 0.061 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 98.6 100.2 100.1 96.8 97.5 100.5 99.6 98.3 99.61

Post Test Meter Correction Checkdimensionless 0.99 0.99 0.99 1.02 1.04 1.03 0.99 1.03 0.99

Percent Difference Allowed 5% Average 0.9 1.0 1.5 4.2 5.4 5.0 1.1 4.9 TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 6

Calculations

### ATTACHMENT 17 - Gorgas Report 17 Test Results

Side A Side A Side ASide B Side B Side B Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/27/20086/27/20086/27/20086/27/20086/27/20086/27/2008 Sampling Time -Start Military 0826 0952 1114 0826 0952 1114 Sampling Time -Stop Military 0926 1052 1214 0926 1052 1214 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 1,194 1,186 1,190 1,194 1,186 1,190 Stack Static Pressure Inches Water 0.75 0.75 0.75 0.70 0.70 0.70 Barometric Pressure Inches Mercury 29.78 29.78 29.78 29.78 29.78 29.78 Standard Orifice Pressure DH@Inches Water 1.858 1.858 1.858 2.258 2.258 2.258 Meter Correction Factor dimensionless 0.978 0.978 0.978 0.982 0.982 0.982 Oxygen Concentration Mole Percent O2 8.0 10.0 8.0 8.5 9.0 7.0 Carbon Dioxide ConcentrationMole Percent CO2 10.0 10.5 10.5 12.0 12.5 11.0 Volume of Gas Metered Actual Cubic Feet 44.804 42.383 44.745 41.295 35.841 44.597 Volume of Water Collected Milliliters 67.5 68.0 67.7 67.0 52.0 72.0 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.236 0.234 0.238 0.245 0.240 0.243 Weight of Solids Collected Milligrams 35.7 26.8 23.9 217.5 120.3 109.3 Area of Stack Square Feet 81.000 81.000 81.000 81.000 81.000 81.000 Avg. Sqr. Root Velocity PressureInches Water 0.9268 0.8667 0.8833 0.8174 0.7101 0.8428 Average Orifice Pressure (DH) Inches Water 2.0 1.7 1.9 2.3 1.7 2.3 Average Stack Temperature Degrees F 320 322 324 311 317 319 Average Meter Temperature Degrees F 87 93 96 97 110 112 Average Generation MW 110 110 110 110 110 110 Flowrate Weighted Side ASide BTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE

Volume of Gas Sampled Standard Dry 42.351 39.590 41.580 38.459 32.617 40.51041.17437.19578.369 Cubic Feet Molecular Wt. of Stack Gas (dry)LB/LB-MOLE 29.92 30.08 30.00 30.26 30.36 30.0430.0030.22 30.11

Water vapor in Stack Gas Percent 7.0 7.5 7.1 7.6 7.0 7.7 7.2 7.4 7.19

Average Stack Gas Velocity Feet per second 63.1 59.0 60.2 55.1 47.9 57.3 60.8 53.4 60.75

Stack Gas Flow Rate Actual Cubic 306,582286,602292,594267,788232,793278,495295,259259,692554,951 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 206,884192,981196,521182,714157,739188,230198,796176,228375,023 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 192,447178,546182,532168,867146,728173,698184,508163,098347,606 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 14,414 13,373 13,672 12,648 10,990 13,01013,82012,21626,036 Per Minute Particulate Concentration Grains per Standard 0.013 0.010 0.009 0.087 0.057 0.0420.0110.062 0.01 Dry Cubic Foot Particulate Concentration Grains per Actual 0.008 0.006 0.006 0.055 0.036 0.0260.0070.039 0.01 Cubic Foot Particulate Emission Rate Pounds per Hour 21.4 16.0 13.8 126.1 71.4 61.9 17.1 86.5 103.5

Particulate Emission Rate Pounds per Million 0.018 0.013 0.012 0.106 0.060 0.0520.0140.073 0.087 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 97.8 100.2 99.5 93.9 95.5 97.7 99.2 95.7 99.17 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 7

CalculationsATTACHMENT 18 - Gorgas Report 18 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/27/20086/27/20086/27/2008 Sampling Time -Start Military 0840 1035 1232 Sampling Time -Stop Military 0952 1143 1342 Number of Ports dimensionless 4 4 4 Number of Points per Port dimensionless 3 3 3 Heat Input Million Btu per Hour 9,966 9,926 9,810 Stack Static Pressure Inches Water 0.80 0.80 0.80 Barometric Pressure Inches Mercury 29.40 29.40 29.40 Standard Orifice Pressure DH@ Inches Water 2.211 2.211 2.211 Meter Correction Factor dimensionless 0.927 0.927 0.927 Oxygen Concentration Mole Percent O2 8.0 8.5 8.5 Carbon Dioxide Concentration Mole Percent CO2 11.0 12.0 12.0 Volume of Gas Metered Actual Cubic Feet 42.450 43.562 44.047 Volume of Water Collected Milliliters 201.4 140.0 141.5 Sampling Time Minutes 60 60 60 Nozzle Diameter Inches 0.225 0.225 0.225 Weight of Solids Collected Milligrams 18.7 17.3 18.6 Area of Stack Square Feet 1,134.111,134.111,134.11 Avg. Sqr. Root Velocity Pressure Inches Water 0.8329 0.8548 0.8602 Average Orifice Pressure (DH) Inches Water 1.7 1.7 1.8 Average Stack Temperature Degrees F 126 126 127 Average Meter Temperature Degrees F 72 78 84 Average Generation, Unit 8 MW 175 174 174 Average Generation, Unit 9 MW 183 184 184 Average Generation, Unit 10 MW 719 719 719

RUN 1 RUN 2 RUN 3AVERAGE

Volume of Gas Sampled Standard Dry 38.569 39.114 39.15738.947 Cubic Feet Molecular Wt. of Stack Gas (dry)LB/LB-MOLE 30.08 30.26 30.26 30.20

Water vapor in Stack Gas Percent 13.7 13.6 14.0 13.7 SaturatedSaturatedSaturated Average Stack Gas Velocity Feet per second 50.0 51.2 51.6 50.9

Stack Gas Flow Rate Actual Cubic 3,404,1173,481,4853,509,8533,465,152 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 3,019,2983,090,5583,109,9833,073,280 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 2,604,5252,671,7052,675,9662,650,732 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 195,079200,111200,430198,540 Per Minute Particulate Concentration Grains per Standard 0.007 0.007 0.007 0.007 Dry Cubic Foot Particulate Concentration Grains per Actual 0.006 0.005 0.006 0.006 Cubic Foot Particulate Emission Rate Pounds per Hour 166.7 156.0 167.8 163.5

Particulate Emission Rate Pounds per Million 0.017 0.016 0.017 0.017 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 101.4 100.2 100.2 100.6

Post Test Meter Correction Checkdimensionless 0.91 0.91 0.91 0.91

Percent Difference Allowed 5% Average -1.3 -1.5 -1.5 -1.4

TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 8, 9, & 10

Calculations

### ATTACHMENT 19 - Gorgas Report 19 Test Results

Side ASide ASide ASide BSide BSide B Title of Run RUN 1RUN 2RUN 3RUN 1RUN 2RUN 3 Date Month/Day/Year 7/1/20097/1/20097/1/20097/1/20097/1/20097/1/2009 Sampling Time -Start Military 1411 1545 1735 1411 1545 1735 Sampling Time -Stop Military 1518 1652 1843 1518 1652 1843 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 1,091 1,094 1,097 1,091 1,094 1,097 Stack Static Pressure Inches Water 0.75 0.75 0.75 0.70 0.70 0.70 Barometric Pressure Inches Mercury 29.95 29.95 29.95 29.95 29.95 29.95 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 6.5 6.0 9.0 6.0 9.0 9.0 Carbon Dioxide ConcentrationMole Percent CO2 9.0 9.0 12.0 9.50 10.50 12.00 Volume of Gas Metered Actual Cubic Feet 36.92540.69148.26743.31042.71543.500 Volume of Water Collected Milliliters 52.0 55.0 60.0 65.5 71.3 56.0 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.239 0.240 0.265 0.239 0.239 0.240 Weight of Solids Collected Milligrams 25.8 27.0 31.0 10.6 13.0 18.5 Area of Stack Square Feet 81.00081.00081.00081.00081.00081.000 Avg. Sqr. Root Velocity PressureInches Water 0.70390.76400.75260.87360.88070.8815 Average Orifice Pressure(DH) Inches Water 1.2 1.4 2.0 2.1 2.0 2.1 Average Stack Temperature Degrees F 323 325 327 352 362 338 Average Meter Temperature Degrees F 93 95 93 110 110 110 Combined Average Generation MW 106 106 106 106 106 106 Flowrate Weighted Side ASide BTOTAL or RUN 1RUN 2RUN 3RUN 1RUN 2RUN 3AVERAGEAVERAGEAVERAGE

Volume of Gas Sampled Standard Dry 34.59438.06245.34640.32539.75940.54239.33440.20879.542 Cubic Feet Molecular Wt. of Stack Gas (dry)LB/LB-MOLE 29.70 29.68 30.28 29.76 30.04 30.2829.8930.03 29.96

Water vapor in Stack Gas Percent 6.6 6.4 5.9 7.1 7.8 6.1 6.3 7.0 6.6

Average Stack Gas Velocity Feet per second 48.0 52.1 50.9 60.7 61.3 60.1 50.3 60.7 55.5

Stack Gas Flow Rate Actual Cubic 233,337253,429247,281294,796298,136291,877244,682294,936539,618 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 157,675170,975166,445192,280192,036193,647165,031192,654357,686 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 147,256160,087156,686178,623177,088181,825154,676179,179333,855 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 11,02911,99011,73613,37913,26413,61911,58513,42025,006 Per Minute Particulate Concentration Grains per Standard 0.01150.01090.01050.00400.00500.00700.01100.00540.0080 Dry Cubic Foot Particulate Concentration Grains per Actual 0.00720.00690.00670.00250.00300.00440.00690.00330.0050 Cubic Foot Particulate Emission Rate Pounds per Hour 14.5 15.0 14.1 6.2 7.6 11.0 14.5 8.3 22.8

Particulate Emission Rate Pounds per Million 0.013 0.014 0.013 0.006 0.007 0.0100.0130.008 0.021 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 101.8 102.1 102.0 97.8 97.3 95.8102.0 97.0 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 6

Calculations

### ATTACHMENT 20 - Gorgas Report 20 Test Results

SIDE ASIDE ASIDE BSIDE B

Title of Run RUN 1RUN 2RUN 3RUN 2RUN 3 Date Month/Day/Year 7/1/20097/1/20097/1/20097/1/20097/1/2009 Sampling Time -Start Military 0812 1052 1218 1052 1218 Sampling Time -Stop Military 1028 1157 1326 1157 1325 Number of Ports dimensionless 12 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 Heat Input Million Btu per Hour 1,120 1,116 1,092 1,116 1,092 Stack Static Pressure Inches Water 0.75 0.70 0.70 0.75 0.75 Barometric Pressure Inches Mercury 29.95 29.95 29.95 29.95 29.95 Standard Orifice Pressure DH@Inches Water 2.088 1.858 1.858 2.088 2.088 Meter Correction Factor dimensionless 0.999 0.978 0.978 0.999 0.999 Oxygen Concentration Mole Percent O2 8.0 8.0 8.0 8.0 8.0 Carbon Dioxide ConcentrationMole Percent CO2 10.0 9.0 9.0 9.0 9.0 Volume of Gas Metered Actual Cubic Feet 84.35545.78845.31446.17048.170 Volume of Water Collected Milliliters 153.5 65.0 70.0 69.9 80.7 Sampling Time Minutes 120 60 60 60 60 Nozzle Diameter Inches 0.239 0.239 0.240 0.239 0.240 Weight of Solids Collected Milligrams 56.3 14.8 16.5 47.7 55.7 Area of Stack Square Feet 162.00081.00081.00081.00081.000 Avg. Sqr. Root Velocity PressureInches Water 0.88960.88880.86590.97800.9881 Average Orifice Pressure (DH) Inches Water 2.1 1.9 1.8 2.5 2.7 Average Stack Temperature Degrees F 330 326 329 331 326 Average Meter Temperature Degrees F 90 88 92 97 105 Average Generation MW 106 106 106 106 106

SIDE ASIDE ASIDE BSIDE B RUN 1RUN 2RUN 3RUN 2RUN 3AVERAGE

Volume of Gas Sampled Standard Dry 81.39943.40442.63044.03445.34656.369 Cubic Feet Molecular Wt. of Stack Gas (dry)LB/LB-MOLE 29.92 29.76 29.76 29.76 29.7629.813

Water vapor in Stack Gas Percent 8.2 6.6 7.2 7.0 7.77.458

Average Stack Gas Velocity Feet per second 60.9 60.7 59.3 67.0 67.662.727

Stack Gas Flow Rate Actual Cubic 591,943294,911288,147325,612328,508609,707 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 396,839198,497193,297218,042221,288409,321 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 364,486185,427179,429202,883204,184378,803 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 27,30013,88813,43915,19615,29328,372 Per Minute Particulate Concentration Grains per Standard 0.011 0.005 0.006 0.017 0.0190.011 Dry Cubic Foot Particulate Concentration Grains per Actual 0.007 0.003 0.004 0.010 0.0120.007 Cubic Foot Particulate Emission Rate Pounds per Hour 33.3 8.3 9.2 29.0 33.124.364

Particulate Emission Rate Pounds per Million 0.030 0.007 0.008 0.026 0.0300.034 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 96.8 101.4 102.1 94.0 95.4 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNIT 7

Calculations

### ATTACHMENT 21 - Gorgas Report 21 Test Results

Title of Run RUN 1 RUN 2 RUN 3 Date Month/Day/Year 7/30/20097/30/20097/30/2009 Sampling Time -Start Military 0858 1041 1221 Sampling Time -Stop Military 1005 1150 1337 Number of Ports dimensionless 4 4 4 Number of Points per Port dimensionless 3 3 3 Heat Input Million Btu per Hour 10,076 9,907 9,842 Stack Static Pressure Inches Water -0.90 -0.90 -0.90 Barometric Pressure Inches Mercury 30.00 30.00 30.00 Standard Orifice Pressure DH@ Inches Water 2.080 2.080 2.080 Meter Correction Factor dimensionless 1.051 1.051 1.051 Oxygen Concentration Mole Percent O2 9.0 8.0 9.0 Carbon Dioxide Concentration Mole Percent CO2 12.0 11.5 12.5 Volume of Gas Metered Actual Cubic Feet 35.593 36.407 35.987 Volume of Water Collected Milliliters 131.5 136.0 134.9 Sampling Time Minutes 60 60 60 Nozzle Diameter Inches 0.220 0.220 0.220 Weight of Solids Collected Milligrams 54.4 42.2 26.4 Area of Stack Square Feet 1,134.1101134.1101134.110 Avg. Sqr. Root Velocity PressureInches Water 0.8578 0.8678 0.8655 Average Orifice Pressure (DH) Inches Water 1.5 1.5 1.5 Average Stack Temperature Degrees F 140 141 133 Average Meter Temperature Degrees F 82 82 89 Average Generation, Unit 8 MW 171 171 171 Average Generation, Unit 9 MW 175 175 175 Average Generation, Unit 10 MW 699 699 699

RUN 1 RUN 2 RUN 3AVERAGE

Volume of Gas Sampled Standard Dry 36.665 37.500 36.63836.934 Cubic Feet Molecular Wt. of Stack Gas (dry)LB/LB-MOLE 30.28 30.16 30.36 30.27

Water vapor in Stack Gas Percent 14.4 14.6 14.8 14.6 0 Average Stack Gas Velocity Feet per second 51.7 52.4 51.8 51.9

Stack Gas Flow Rate Actual Cubic 3,514,8253,564,3843,523,8623,534,357 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 3,092,9543,134,3873,137,5143,121,618 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 2,646,2192,677,3432,674,0742,665,879 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic Feet4,647,5624,337,7114,696,4834,560,586 Per Minute @ 0% O2 Particulate Concentration Grains per Standard 0.023 0.017 0.011 0.017 Dry Cubic Foot Particulate Concentration Grains per Actual 0.017 0.013 0.008 0.013 Cubic Foot Particulate Emission Rate Pounds per Hour 518.3 397.7 254.3 390.1

Particulate Emission Rate Pounds per Million 0.051 0.040 0.026 0.039 Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 99.2 100.3 98.1 99.2

Post Test Meter Correction Checkdimensionless 1.06 1.05 1.06 1.06

Percent Difference Allowed 5% Average 1.1 -0.1 1.1 0.7

TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT UNITS 8, 9, AND 10

Calculations

### ATTACHMENT 22 - Gorgas Report 22 Test Results

A sideA sideA sideB sideB sideB side

Title of Run RUN 1RUN 2RUN 3RUN 1RUN 2RUN 3 Date Month/Day/Year 9/6/20079/6/20079/6/20079/6/20079/6/20079/6/2007 Sampling Time -Start Military 0838 1125 1403 0838 1125 1403 Sampling Time -Stop Military 0938 1225 1501 0938 1225 1503 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 1,133 1,135 1,137 1,133 1,135 1,137 Stack Static Pressure Inches Water 0.65 0.65 0.65 0.50 0.50 0.50 Barometric Pressure Inches Mercury 30.02 30.02 30.02 30.02 30.02 30.02 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 9.0 8.0 6.3 9.5 8.0 6.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 11.0 10.5 12.0 11.5 11.5 Volume of Gas Metered Actual Cubic Feet 40.77940.24839.31237.40736.53535.988 Volume of Water Collected Milliliters 72 88 69 67 66 59 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.242 0.242 0.242 0.228 0.228 0.228 Weight of Solids Collected Milligrams 56.6 87.5 119.3 49.3 47.5 74.5 Area of Stack Square Feet 81.00 81.00 81.00 81.00 81.00 81.00 Avg. Sqr. Root Velocity Pressure Inches Water 0.76260.76730.76140.77230.77660.7376 Average Orifice Pressure(DH) Inches Water 1.4 1.5 1.4 1.5 1.5 1.4 Average Stack Temperature Degrees F 327 327 327 306 309 308 Average Meter Temperature Degrees F 86 90 91 82 84 87

Side ASide B Combined RUN 1RUN 2RUN 3RUN 1RUN 2RUN 3AVERAGEAVERAGEAverage/Total

Volume of Gas Sampled Standard Dry 38.97538.15537.18734.47833.50832.86138.10533.616 35.861 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.28 30.08 29.93 30.30 30.16 30.1030.1030.19 30.14

Water vapor in Stack Gas Percent 8.0 9.8 8.0 8.4 8.5 7.8 8.6 8.2 8.4

Average Stack Gas Velocity Feet per second 51.8 52.4 52.0 51.7 52.2 49.6 52.0 51.2 51.6

Stack Gas Flow Rate Actual Cubic 251,545254,766252,539251,468253,892240,933252,950248,764 501,714 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 169,503171,805170,202174,064175,185166,344170,503171,864 342,368 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 155,943154,980156,531159,477160,321153,382155,818157,727 313,544 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 11,68011,60811,72411,94512,00811,48811,67111,814 23,484 Per Minute Particulate Concentration Grains per Standard 0.022 0.035 0.049 0.022 0.022 0.035 0.0360.026 0.031 Dry Cubic Foot Particulate Concentration Grains per Actual 0.014 0.021 0.031 0.014 0.014 0.022 0.022 0.017 0.019 Cubic Foot Particulate Emission Rate Pounds per Hour 29.9 46.9 66.3 30.1 30.0 45.9 47.7 35.3 83.0

Particulate Emission Rate Pounds per Million 0.026 0.041 0.058 0.027 0.026 0.0400.042 0.031 0.073 Btu (Heat Input) Isokinetic Rate Percent 105.6 104.0 100.4 102.9 99.5 102.0 103.3 101.5 102.41

Post Test Meter Correction Check (Yqa)dimensionless 0.95 0.97 0.98 0.93 0.95 0.94 0.96 0.94 1.0

Percent Difference Allowed 5% Average -3.5 -1.5 -0.3 -1.1 1.0 0.2 -1.8 0.0 -0.9 TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT, UNIT 6 COMPLIANCE ASSURANCE MONITORING

CalculationsATTACHMENT 23 - Gorgas Report 23 Test Reports

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 7/12/20077/12/20077/12/20077/12/20077/12/20077/12/2007 Sampling Time -Start Military 0808 1032 1240 0808 1032 1240 Sampling Time -Stop Military 0908 1132 1340 0908 1132 1340 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 1,105 1,110 1,106 1,105 1,110 1,106 Stack Static Pressure Inches Water 0.45 0.45 0.45 0.40 0.40 0.40 Barometric Pressure Inches Mercury 30.04 30.04 30.04 30.04 30.04 30.04 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 9.0 6.3 6.0 8.0 7.5 8.0 Carbon Dioxide Concentration Mole Percent CO2 9.5 9.0 10.0 11.0 11.0 10.0 Volume of Gas Metered Actual Cubic Feet 43.325 40.495 40.896 36.896 36.088 39.508 Volume of Water Collected Milliliters 64 58 62 57 53 77 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.230 0.221 0.222 0.221 0.216 0.219 Weight of Solids Collected Milligrams 20.4 26.5 47.6 46.7 58.7 90.6 Area of Stack Square Feet 81.00 81.00 81.00 81.00 81.00 81.00 Avg. Sqr. Root Velocity Pressure Inches Water 0.9017 0.9222 0.8923 0.8651 0.8771 0.9207 Average Orifice Pressure(DH) Inches Water 2.2 1.9 1.9 1.4 1.3 1.5 Average Stack Temperature Degrees F 322 324 326 310 308 310 Average Meter Temperature Degrees F 81 87 92 89 94 95

Side A Side A Side A Side B Side B Side BSide ASide B Combined RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AverageAverageAverage/Total

Volume of Gas Sampled Standard Dry 40.054 37.068 37.071 35.085 34.015 37.15338.06435.418 36.741 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.88 29.69 29.84 30.08 30.06 29.9229.8030.02 29.91

Water vapor in Stack Gas Percent 7.0 6.9 7.3 7.1 6.8 8.9 7.1 7.6 7.3

Average Stack Gas Velocity Feet per second 61.3 62.9 60.8 58.2 58.8 62.2 61.7 59.8 60.7

Stack Gas Flow Rate Actual Cubic 297,685305,662295,672282,630286,004302,528299,673290,387 590,060 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 201,982206,900199,654194,640197,640208,551202,845200,277 403,122 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 187,853192,707185,083180,813184,135190,015188,548184,988 373,535 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 14,070 14,434 13,863 13,543 13,792 14,23214,12213,856 27,978 Per Minute Particulate Concentration Grains per Standard 0.008 0.011 0.020 0.020 0.027 0.0380.0130.028 0.021 Dry Cubic Foot Particulate Concentration Grains per Actual 0.005 0.007 0.012 0.013 0.017 0.0240.0080.018 0.013 Cubic Foot Particulate Emission Rate Pounds per Hour 12.6 18.2 31.4 31.8 41.9 61.2 20.7 45.0 65.7

Particulate Emission Rate Pounds per Million 0.011 0.016 0.028 0.029 0.038 0.0550.0190.041 0.059 Btu (Heat Input) Isokinetic Rate Percent 99.7 97.5 100.6 98.3 98.0 100.9

Post Test Meter Correction Check (Yqa)dimensionless 0.98 1.00 0.99 1.02 1.01 1.01 0.99 1.01 1.00

Percent Difference Allowed 5% 4.3 5.8 5.2 3.5 3.3 3.0 5.1 3.3 4.2 TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT - UNIT 7 COMPLIANCE ASSURANCE MONITORING

Calculations

## ATTACHMENT 24 - Gorgas Report 24 Test Results

Title of Run RUN 1A RUN 1B RUN 2 RUN 3 Date Month/Day/Year 11/30/200711/30/200711/30/200711/30/2007 Sampling Time -Start Military 1550 1550 1920 1920 Sampling Time -Stop Military 1654 1654 2128 2028 Number of Ports dimensionless 16 16 16 16 Number of Points per Port dimensionless 4 4 4 4 Heat Input Million Btu per Hour 1,771 1,771 1,771 1,771 Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00 Barometric Pressure Inches Mercury 30.40 30.40 30.40 30.40 Standard Orifice PressureDH@Inches Water 2.418 1.939 2.418 1.939 Meter Correction Factor dimensionless 0.939 0.981 0.939 0.981 Oxygen Concentration Mole Percent O2 9.5 7.0 8.0 8.0 Carbon Dioxide Concentration Mole Percent CO2 10.5 14.0 12.5 12.5 Volume of Gas Metered Actual Cubic Feet 51.705 50.100 97.610 107.310 Volume of Water Collected Milliliters 90 90 123 139 Sampling Time Minutes 64 64 128 128 Nozzle Diameter Inches 0.247 0.260 0.247 0.265 Weight of Solids Collected Milligrams 14.4 20.2 26.9 31.4 Area of Stack Square Feet 116.25 116.25 232.50 232.50 Avg. Sqr. Root Velocity PressureInches Water 0.8456 0.7835 0.8085 0.7831 Average Orifice Pressure(DH) Inches Water 2.4 2.1 2.1 2.0 Average Stack Temperature Degrees F 275 265 268 266 Average Meter Temperature Degrees F 67 63 55 51

RUN 1A RUN 1B RUN 2 RUN 3AVERAGE

Volume of Gas Sampled Standard Dry 49.731 50.632 95.942 111.141 Cubic Feet Molecular Wt. of Stack Gas (dry)LB/LB-MOLE 30.06 30.52 30.32 30.32 30.31

Water vapor in Stack Gas Percent 7.8 7.7 5.7 5.6 6.3

Average Stack Gas Velocity Feet per second 56.1 51.3 53.0 51.2 52.6

Stack Gas Flow Rate Actual Cubic 391,547 357,767 739,093 714,405734,270 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 277,549 256,895 528,435 512,658525,179 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 255,762 237,060 498,361 484,156491,780 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 19,157 17,756 37,327 36,26336,834 Per Minute Particulate Concentration Grains per Standard 0.004 0.006 0.004 0.0040.005 Dry Cubic Foot Particulate Concentration Grains per Actual 0.003 0.004 0.003 0.0030.003 Cubic Foot Particulate Emission Rate Pounds per Hour 9.8 12.5 18.4 18.1 19.6

Particulate Emission Rate Pounds per Million 0.006 0.007 0.010 0.0100.011 Btu (Heat Input) Isokinetic Rate Percent 106.1 105.2 105.1 108.8 106.5 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT - UNIT 9 ALTERNATIVE OPACITY MONITORING

CalculationsATTACHMENT 25 - Gorgas Report 25 Test Results

A SideA SideA Side B Side B Side B Side

Title of Run RUN 1RUN 2RUN 3 RUN 1RUN 2RUN 3 Date Month/Day/Year 6/7/20076/7/20076/7/2007 6/7/20076/7/20076/7/2007 Sampling Time -Start Military 1005 1250 1416 1005 1250 1416 Sampling Time -Stop Military 1112 1358 1524 1112 1357 1524 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Heat Input Million Btu per Hour 7,371 7,351 7,349 7,371 7,351 7,349 Stack Static Pressure Inches Water -24.00-24.00-24.00 -24.00-24.00-24.00 Barometric Pressure Inches Mercury 29.97 29.97 29.97 29.97 29.97 29.97 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 5.0 5.0 5.5 5.0 5.0 5.0 Carbon Dioxide Concentration Mole Percent CO2 13.0 12.0 11.5 11.5 11.5 11.5 Volume of Gas Metered Actual Cubic Feet 49.18648.70245.665 40.48639.71436.698 Volume of Water Collected Milliliters 73 80 77 78 76 70 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.235 0.237 0.232 0.236 0.236 0.235 Weight of Solids Collected Milligrams 74.3 78.3 67.6 13.9 26.7 42.2 Area of Stack Square Feet 370.000370.000370.000 370.000370.000370.000 Avg. Sqr. Root Velocity Pressure Inches Water 1.02011.00640.9804 0.85580.81030.7324 Average Orifice Pressure(DH) Inches Water 2.7 2.7 2.4 1.6 1.5 1.2 Average Stack Temperature Degrees F 331 335 334 306 307 310 Average Meter Temperature Degrees F 81 88 89 84 90 94

A SideA SideA SideA Side B Side B Side B Side B Side RUN 1RUN 2RUN 3AverageRUN 1RUN 2RUN 3Average Total

Volume of Gas Sampled Standard Dry 45.43544.41741.54943.80038.80637.61534.46736.96340.382 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.28 30.12 30.06 30.15 30.04 30.04 30.04 30.04 30.10

Water vapor in Stack Gas Percent 7.0 7.8 8.0 7.6 8.6 8.7 8.7 8.7 8.2

Average Stack Gas Velocity Feet per second 71.5 71.0 69.2 70.6 59.5 56.3 51.0 55.6 63.1

Stack Gas Flow Rate Actual Cubic 1,587,3361,576,6271,536,6981,566,8871,320,0621,250,7231,132,8761,234,5542,801,441 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 998,968986,943963,685983,199857,524811,492732,071800,3621,783,561 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 928,731909,810886,366908,302783,407741,018668,195730,8731,639,176 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 69,56268,14566,38968,03258,67755,50250,04854,74261,387 Per Minute Particulate Concentration Grains per Standard 0.025 0.027 0.025 0.026 0.006 0.011 0.019 0.012 0.019 Dry Cubic Foot Particulate Concentration Grains per Actual 0.015 0.016 0.014 0.015 0.003 0.006 0.011 0.007 0.011 Cubic Foot Particulate Emission Rate Pounds per Hour 200.5 211.7 190.4 200.8 37.0 69.4 108.0 71.5 272.3

Particulate Emission Rate Pounds per Million 0.027 0.029 0.026 0.027 0.005 0.009 0.015 0.010 0.037 Btu (Heat Input) Combined Particulate Emission Rate 0.032 0.038 0.041 0.037 Allowable 0.12 0.12 0.12 0.12 Isokinetic Rate Percent 100.1 98.3 98.4 98.9 100.5 103.0 105.6 103.0 101.0

Post Test Meter Correction Factor dimensionless 0.95 0.98 0.97 0.97 1.00 0.99 0.97 0.98 0.98

Percent Difference Allowed 5% 1.6 3.6 3.5 2.9 1.7 0.6 -1.5 0.2 1.6 TABLE I. PARTICULATE EMISSIONS TEST RESULTS ALABAMA POWER COMPANY GORGAS STEAM PLANT - UNIT 10 COMPLIANCE ASSURANCE MONITORING

Calculations

## ATTACHMENT 26 - Gorgas Report 26 Test Results, Part I

UNITS 8-10 FGD PERFORMANCE TESTING PARTICULATE CONCENTRATION AND PARTICLE SIZE DISTRIBUTIONS

Run ID Pretest 1 2 3 4 5 6 Date 1/30/20081/30/20081/30/20081/31/20081/31/2008 Time 0819-11031231-15161610-18500800-10391200-1400 Volumetric Flow Rate (DSCFM, 68F) 3,147,0063,028,0882,925,3182,811,6172,804,351 Particulate (gr/dscf) 0.0166 N/A 0.0106 0.0087 0.0079 Particulate (lb/hr) 448.42 N/A 266.62 210.58 190.09

Run ID Pretest 1 2 3 4 5 6 Date 1/22/20081/29/20081/30/20081/30/20081/30/20081/31/20081/31/2008 Time 1100-14151225-15400800-11171200-15111600-19110800-11091200-1509 Volumetric Flow Rate (DSCFM, 68F) 2,651,8712,578,5492,677,5672,606,5772,717,0432,596,8822,679,632 Particulate (gr/dscf) 0.0024 0.0010 0.0015 0.0015 0.0016 0.0015 0.0017 Particulate (lb/hr) 55.16 22.53 33.96 33.41 37.20 33.86 40.12

Run ID 1 2 3 4 5 6 Average Date 1/25/20081/25/20081/25/20081/25/20081/25/20081/25/2008 Time 0932-09450934-10221054-11521217-12291251-13331355-1432 Port 1 2 3 4 5 6 Concentration (mg/dscm) 82.4 31.5000 74.8 70.3 202 3050 MMD (micrometers) 12.52 9.08 22.82 16.47 19.72 20.44 17.6 Scrubber Inlet Particulate Concentration Summary Data

Stack Particulate Concentration Summary Data

Scrubber Inlet Particle Size Distribution

## ATTACHMENT 27 - Gorgas Report 26 Test Results, Part II

UNITS 8-10 FGD PERFORMANCE TESTING PRIMARY FLUE GAS CONSTITUENTS

Run ID Pretest 1 2 3 4 5 6 Date 1/30/20081/30/20081/30/20081/31/20081/31/2008 Time 0819-11031231-15161610-18500800-10391200-1400 O2(%) 7.4 7.7 7.9 6.7 7.5 CO2(%) 12.2 11.9 11.8 13.8 11.9 SO2(ppm) 1262.7 1216.7 1166 1163.5 1135.7 NOx (ppm) 282.2 276.8 272.0 273.7 301.1 CO (ppm) 0.9 1.0 1.7 0.0 0 Moisture (%) 6.03 6.07 5.99 6.16 6.28

Run ID Pretest 1 2 3 4 5 6 Date 1/22/20081/29/20081/30/20081/30/20081/30/20081/31/20081/31/2008 Time 1100-14151225-15400800-11171200-15111600-19110800-11091200-1509 O2(%) 7.3 8.2 7.7 7.8 8.2 7.2 7.7 CO2(%) 12.2 11.4 11.9 12.0 11.6 11.8 11.3 CO (ppm) 0.0 4.9 2.4 1.0 1.7 3.2 3 Moisture (%) 11.14 12.06 9.29 11.94 9.34 11.89 12.31



### SUMMARY FTIR DATA FOR CHLORINE AND FLUORINE

Date TimeHCl (ppmv)HF (ppmv) 1/23/20081553-165118.58 15.59

Scrubber Inlet Flue Gas Concentration Summary Data

Stack Flue Gas Concentration Summary Data

### ATTACHMENT 28 - Gorgas Report 26 Test Results, Part III

UNITS 8-10 FGD PERFORMANCE TESTING MERCURY CONCENTRATIONS

Run Date Time Inlet O2Outlet O2 %, dry %, dryInlet Hg0Inlet Hg+2Inlet HgT% OxidizedOutlet Hg0Outlet Hg+2Outlet HgT% Oxidized

Preliminary 1/24/20081138-1238 7.3 7.5 8.70 8.34 17.04 48.9% 9.46 0.32 9.78 3.3% Run #1 1/27/20081053-1253 9.0 9.0 12.48 12.01 24.49 49.0% 10.92 0.34 11.27 3.0% Run #2 1/27/20081409-1609 9.0 9.0 12.49 31.76 44.25 71.8% 10.49 0.20 10.70 1.9% Run #3 1/28/20080900-10008.0 8.0 10.47 14.72 25.20 58.4% 10.81 0.93 11.74 7.9% Run #4 1/28/20081128-12288.0 8.0 10.03 17.97 28.00 64.2% 10.73 0.60 11.33 5.3% Run #5 1/28/20081313-1413 8.0 8.0 10.34 18.82 29.16 64.5% 7.45 0.28 7.74 3.6% Run #6 1/28/20081500-16008.0 8.0 9.56 21.61 31.17 69.3% 9.88 0.56 10.45 5.4%

Preliminary 1/24/20081138-1238 7.3 7.5 12.29 11.78 24.07 48.9% 13.56 0.46 14.02 3.3% Run #1 1/27/20081053-1253 9.0 9.0 20.15 19.39 39.53 49.0% 17.63 0.55 18.19 3.0% Run #2 1/27/20081409-1609 9.0 9.0 20.16 51.27 71.43 71.8% 16.93 0.32 17.27 1.9% Run #3 1/28/20080900-10008.0 8.0 15.59 21.92 37.53 58.4% 16.1 1.38 17.48 7.9% Run #4 1/28/20081128-12288.0 8.0 14.94 26.76 41.70 64.2% 15.98 0.89 16.87 5.3% Run #5 1/28/20081313-1413 8.0 8.0 15.4 28.03 43.42 64.5% 11.09 0.42 11.53 3.6% Run #6 1/28/20081500-16008.0 8.0 14.24 32.18 46.42 69.3% 14.71 0.83 15.56 5.4%

Date Inlet Hg0Inlet Hg+2Inlet HgT% OxidizedOutlet Hg0Outlet Hg+2Outlet HgT% OxidizedInlet Hg0Inlet HgTOutlet Hg0Outlet HgT

1/24/2008 10.7 13.0 23.7 55% 11.7 0.9 12.6 7% 60% 80% 62% 54% 1/27/2008 16.1 12.6 28.7 44% 15.0 0.6 15.6 4% 65% 71% 58% 53% 1/28/2008 14.9 12.1 27* 45% 14.2 0.4 14.6 3% 73% 67% 56% 53% 1/29/2008 13.7 8.8 22.5 39% 12.5 0.6 13.1 4% 57% 73% 49% 50% 1/30/2008 12.9 7.1 20.0 36% 12.4 1.8 14.2 13% 68% 57% 54% 52% 1/31/2008 11.6 1.2 12.8 9% 51% 55%

1/24/2008 17.4 11.3 28.6 39% 18.8 5.2 24.0 22% 1/27/2008 24.7 15.7 40.4 39% 25.7 4.0 29.7 13% 1/28/2008 20.4 20.6 41* 50% 25.3 2.2 27.5 8% 1/29/2008 24 6.8 30.8 22% 25.6 0.6 26.2 2% 1/30/2008 23.9 5.6 29.4 19% 23.7 1.8 25.5 7% 1/31/2008 22.7 0.5 23.2 2%*data estimated due to problems with probe filter

Run Date TimeInlet O2(%)Outlet O2 (%)Inlet Meter Temp (oC)Outlet

Meter Temp (oC)Inlet HgT

(μg/m3) (actual temp. and O2, dry)Outlet HgT

(μg/m3) (actual temp. and O2, dry)Inlet HgT

(μg/Nm3) (3% O2, dry, 0oC)Outlet HgT

(μg/Nm3) (3% O2, dry, 0oC)

1 1/28/20081125-1205 8.0 8.0 25.0 1.32 36.3 17.3 54.8 25.1 2 1/28/20081229-1309 8.0 8.0 27.4 17.2 34.5 17.0 52.5 25.0 3 1/28/20081328-14088.0 8.0 30.4 30.4 32.1 16.7 49.4 25.7 SRI Sorbent Trap Total Mercury Data

Ontario Hydro Test Results Summary

Scrubber Inlet Scrubber Outlet

UN-CORRECTED VALUES (μg/m3, actual O2, dry, 68oF)

CORRECTED VALUES (μg/Nm3, 3% O2, dry, 0oC)

Tekran CEMS Speciated Mercury Data Inlet Outlet Dynamic Spike Recovery Factors

DATA UN-CORRECTED FOR SPIKE (μg/Nm3, dry, 3% O2, 0oC)

DATA CORRECTED FOR SPIKE (μg/Nm3, dry, 3% O2, 0oC)

## ATTACHMENT 29 - Gorgas Report 26 Test Results, Part IV

UNITS 8-10 FGD PERFORMANCE TESTING SO2

### AND SO3

### MEASUREMENTS (CONTROLLED CONDENSATION)

Run Date Time Time SO3 SO2 SO3 SO2 1 1/29/20081230-143611.4 16491230-14185.7 26 2 1/30/20080813-103910.0 16710821-10085.7 27 3 1/30/20081202-14429.9 16081201-12125.7 27 4 1/30/20081600-183110.2 15351600-16106.3 31 5 1/31/20080803-1027N/A 14080802-09456.0 19

Run Date Time Time SO3 SO2 SO3 SO2 6 1/31/20081328-1525N/A 42 1329-15186.0 21 7 2/1/20081415-16303.5 14 1415-16285.8 18 Summary Data - Scrubber Inlet/Stack Inlet (ppm, Port 2) Stack (ppm)

Summary Data - Scrubber Outlet/Stack Outlet (ppm, Port 4) Stack (ppm)

## ATTACHMENT 30 - Gorgas Report 26, Test Results Part V

UNITS 8-10 FGD PERFORMANCE TESTING OPERATIONAL DATA

Test, Sample Location Run Date Flue Gas moisture content, % Flue gas flow

rate, dscfm Flue gas

oxygen content, %, dry Flue gas carbon

dioxide content, %, dry Flue gas

temperature, oF Flue gas

pressure, in Hg Particulate Testing, Stack Outlet Prelim1/22/2008 11.142,651,871 7.5 12.2 121.9 29.50 Particulate Testing, Stack Outlet 1 1/29/2008 12.062,578,549 8.2 11.4 123.6 29.51 Particulate Testing, Stack Outlet 2 1/30/2008 9.292,677,567 7.7 11.9 119.4 29.55 Particulate Testing, Stack Outlet 3 1/30/2008 11.942,606,577 7.8 12.0 120.7 29.54 Particulate Testing, Stack Outlet 4 1/30/2008 9.342,717,043 8.2 11.6 120.0 29.51 Particulate Testing, Stack Outlet 5 1/31/2008 11.892,596,882 7.2 11.8 120.6 29.55 Particulate Testing, Stack Outlet 6 1/31/2008 12.312,679,632 7.7 11.3 121.8 29.54 Particulate Testing, Scrubber Inlet 2 1/30/2008 6.033,147,006 7.4 12.2 290.5 30.58 Particulate Testing, Scrubber Inlet 3 1/30/2008 6.073,028,088 7.7 11.9 295.3 30.52 Particulate Testing, Scrubber Inlet 4 1/30/2008 5.992,925,318 7.9 11.8 295.4 30.56 Particulate Testing, Scrubber Inlet 5 1/31/2008 6.162,811,617 6.7 13.8 297.8 30.74 Particulate Testing, Scrubber Inlet 6 1/31/2008 6.282,804,351 7.5 11.9 304.5 30.75 Ontario Hydro - Mercury, Scrubber Outlet Prelim1/24/2008 12.252,461,706 7.5 12.2 121.3 30.00 Ontario Hydro - Mercury, Scrubber Outlet 1 1/27/2008 13.363,098,765 9.0 12.0 121.3 30.03 Ontario Hydro - Mercury, Scrubber Outlet 2 1/27/2008 13.353,067,753 9.0 12.0 123.8 30.04 Ontario Hydro - Mercury, Scrubber Outlet 3 1/28/2008 14.003,082,443 8.0 12.0 122.0 29.88 Ontario Hydro - Mercury, Scrubber Outlet 4 1/28/2008 14.683,087,664 8.0 12.0 121.6 29.88 Ontario Hydro - Mercury, Scrubber Outlet 5 1/28/2008 11.903,092,318 8.0 12.0 121.8 29.88 Ontario Hydro - Mercury, Scrubber Outlet 6 1/28/2008 13.883,081,469 8.0 12.0 122.1 29.88 Ontario Hydro - Mercury, Scrubber Inlet Prelim1/24/2008 5.192,402,782 7.3 12.2 283.4 30.72 Ontario Hydro - Mercury, Scrubber Inlet 1 1/27/2008 6.473,460,515 9.0 14.0 291.0 30.74 Ontario Hydro - Mercury, Scrubber Inlet 2 1/27/2008 7.393,746,703 9.0 14.0 297.3 30.78 Ontario Hydro - Mercury, Scrubber Inlet 3 1/28/2008 8.663,713,709 8.0 13.0 281.8 30.45 Ontario Hydro - Mercury, Scrubber Inlet 4 1/28/2008 9.273,708,255 8.0 13.0 292.2 30.46 Ontario Hydro - Mercury, Scrubber Inlet 5 1/28/2008 7.923,715,307 8.0 13.0 296.7 30.53 Ontario Hydro - Mercury, Scrubber Inlet 6 1/28/2008 11.763,481,080 8.0 13.0 300.3 30.55 SOx, Scrubber Inlet 1 1/29/2008 7.60 N/A 9.0 N/A 294.0 N/A SOx, Stack 1 1/29/2008 14.50 N/A 8.7 N/A 120.4 N/A SOx, Scrubber Inlet 2 1/30/2008 6.20 N/A 8.4 N/A 284.2 N/A SOx, Stack 2 1/30/2008 13.50 N/A 8.0 N/A 118.0 N/A SOx, Scrubber Inlet 3 1/30/2008 6.20 N/A 8.4 N/A 289.6 N/A SOx, Stack 3 1/30/2008 13.50 N/A 8.2 N/A 118.0 N/A SOx, Scrubber Inlet 4 1/30/2008 6.20 N/A 8.6 N/A 289.0 N/A SOx, Stack 4 1/30/2008 13.50 N/A 8.5 N/A 117.6 N/A SOx, Scrubber Inlet 5 1/31/2008 6.90 N/A 7.4 N/A 293.6 N/A SOx, Stack 5 1/31/2008 13.60 N/A 8.2 N/A 119.6 N/A SOx, Scrubber Outlet 6 1/31/2008 11.60 N/A 7.7 N/A 119.5 N/A SOx, Stack 6 1/31/2008 13.60 N/A 8.3 N/A 121.3 N/A SOx, Scrubber Outlet 7 2/1/2008 11.40 N/A 8.8 N/A 121.8 N/A SOx, Stack 7 2/1/2008 12.60 N/A 8.4 N/A 122.2 N/A