Process Information

1 Name of legal owner of facility:

Alabama Power Company

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

3 Address of _X__ legal owner or ____ operator:

600 North 18th Street

Birmingham, AL 35291-0830

4a Plant Name (as reported on U.S. DOE/EIA Form-860 (2007), "Annual Electric Generator Report", schedule 2, line 1, page 37, question 1)

OR Plant Name (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report", schedule 2, page 1, question 1):

Gorgas

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

DOE/EIA Form EIA-923 (2008), schedule 2, page 1, question 2):

Plant Code - 8

5 Complete street address of facility (physical location):

460 Gorgas Road

Parrish, AL 35580

6 Provide mailing address if different:

600 North 18th Street

Birmingham, AL 35291-0830

7 Name and title of contact(s) able to answer technical questions about the completed survey:

Sarah Markham, Engineer II

8 Contact(s) telephone number(s):

(205) 257-6780

and e-mail address(es):

sasander@southernco.com

9 Is this facility considered to be owned or operated by a small entity as defined by the Regulatory Flexibility Act? 

____ Yes _X__ No ____ Don't know

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

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

_X__ other (specify in question 14 below)

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

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

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

_X__ other (specify in question 14 below)

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

12 If coal or solid fuel, as described below, derived from a fossil source is fired, indicate which rank of coal or solid fuel was utilized

during the previous 12 months prior to the receipt of this ICR:2,3

____ lignite (% _____) ____ subbituminous (% _____)

_X__ bituminous (% _100_) ____ anthracite (% _____)

____ coal refuse (including gob, culm, and subbituminous-derived coal refuse) (% _____)

____ synfuel (including, but not limited to, briquettes, pellets, or extrusions which are formed by binding materials, or processes

 that recycle materials) (%_____)

 (please specify the type or form of synfuel used ___________________________________________)

____ petroleum coke (% _____)

1

 "Permitted" in this context, refers to the fuels that the permit anticipates will be combusted at the facility.

2

 If the boiler is fired by a blend of coal ranks, please specify percentage (separately, on both a mass and on a Btu basis) of each coal rank

(e.g., 85% subbituminuous/15% bituminous).

3

 In reference to footnote 1, if necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting 

the reason the fuel type was combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research

purposes").
13 If oil is fired, indicate which type of oil was utilized during the previous 12 months prior to the receipt of this ICR:4

_X__ distillate (% _100_)

____ other (specify _______________) (% _____)

____ residual or bunker C (% _____)

14a If "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited to, 

plastics, treated wood, rubber belting or gaskets, whole tires, tire-derived fuel, boiler cleaning solutions, animal wastes, etc.) is 

either utilized or permitted to be used, please indicate below what materials are combusted in the boiler and in what quantities

(specify whether this quantity is on a weight percentage or heat [Btu] basis). Also indicate (yes/no) whether you are permitted5 to 

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

1

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

14b If "other" was checked in questions 10 or 11 above indicating that any non-fossil fuel or other material (including, but not limited to,

plastics, treated wood, rubber belting or gaskets, whole tires, tire-derived fuel, boiler cleaning solutions, animal wastes, etc.) is 

either utilized or permitted to be used, were such material to be classified as "solid waste" under the Resource Conservation and 

Recovery Act and, thus make the utilizing unit subject to CAA section 129, would you continue to utilize (i.e., use as a fuel) the 

material? ____ Yes ____ No _X__ Neither

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

4

 If the boiler is fired by a blend of fuel oil ranks, please specify percentage (separately, on both a volume and on a Btu basis) of each

fuel oil rank (e.g., 85% residual oil/15% distillate).

5

 If necessary, a notation can be added to a utilized fuel type that is not listed in the operating permit noting the reason the fuel was

combusted (e.g., "the permitting agency allowed this fuel to be combusted for special testing and research purposes").

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

No1
15 Identification (or designation) of all coal- and oil-fired steam generating units (boilers) (as defined by Clean Air Act section 112(a)(8))

located at this facility. Boiler ID

6

Original design fuel (i.e., 

coal rank or type of oil)

Design heat input, 

(MMBtu/hr)

7

Present maximum heat 

input, (MMBtu/hr)

8

MWe Gross capacity

summer

MWe Net Capacity

summer

Original design gross 

efficiency (%, HHV)

Present operating gross 

efficiency (%, HHV)

Design steam pressure 

(psig)

Operating steam pressure 

(psig)

Design steam temperature 

(

oF)

temperature (

Operating steam 

oF)

Design steam reheat 

temperature (

oF)

9

Operating steam reheat 

temperature (

oF)10

Fuel11

Hours/year operated12

Average annual capacity 

factor for the past 3 years

Applicable NSPS

Estimated year of 

retirement13

6 bituminous CBI CBI 110 103 88.8 87.25 1250 1259 950 944 N/A N/A bituminous 

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/A bituminous 

coal, No. 2 

fuel oil

CBI CBI none not 

available

8 bituminous CBI CBI 175 161 88.52 not 

available

1800 1824 1000 997 1000 981 bituminous 

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 981 bituminous 

coal, No. 2 

fuel oil

CBI CBI none not 

available

10 bituminous CBI CBI 720 677 89.1 88.67 3500 3500 1000 1000 1000 986 bituminous 

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.

6

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

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

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

7

 Per fuel burned in the boiler. Report this based on higher heating value (HHV).

8

 Per fuel burned in the boiler. Report this based on higher heating value (HHV).

9

 Please indicate if more than one steam reheat cycle is utilized, and, if so, please provide information for both.

10 Please indicate if more than one steam reheat cycle is utilized, and, if so, please provide information for both.

11 Indicate the fuels utilized for the indicated boiler, and percentages, as indicated in questions 11 - 13.

12 The "hours/year operated" would be the average of the actual number of hours the unit operated in 1 year based on the last 3 years of operation.

13 This can be treated as CBI and can be submitted through the proper CBI procedure if desired.
16 For each boiler noted in Part I, question 15, provide the following information for each current emission control device installed

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

for the second control following the boiler, etc.):

Boiler ID14 Type15 NOx control16 SO2 control17 PM control18 Other control19

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.

1

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

2

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

3

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

4

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

etc.).

Name Telephone Address

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.

20 A control technology demonstration project is defined as a U.S. Government (e.g., U.S. Department of Energy program) sponsored

(in whole or in part) project or mandate (e.g., as a result of a consent decree) that adds a HAP control technology to a facility's unit to

demonstrate the technology's HAP removal performance.

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

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

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

Company (vendor) contact information Boiler ID21 Company (vendor) name
18 For the control technologies identified in Part I, question 17, provide the date of actual start-up of the demonstration (if the control

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

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

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

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

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

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

Boiler ID22

Demonstration 

activity actual startup date

Demonstration 

activity projected 

start-up date

Demonstration 

activity end-date or 

projected end-date

Type of control (e.g., 

sorbent and type; 

chemical additive23)

Desired HAP emission 

reduction (%) or 

emission rate

Coal rank(s) in use

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.

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

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

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

23 If additive is used, please indicate injection point.
19 For each boiler noted in Part I, question 15, provide the company (prime vendor) name and company contact information for each

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

for the purpose of provide a non-demonstration, full-scale operating system.

Name Telephone Address

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.

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

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

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

Company (vendor) contact information

Boiler ID24 Company (vendor) name
20 For the control technologies identified in Part I, question 19, provide the date of actual start-up (if the control is currently operating), the

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

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

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

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

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

"inlet" and "outlet" are).

Boiler ID25 Actual start-up date Expected or projected 

start-up date

Type of control (e.g., 

sorbent and type; 

chemical additive)26

Guaranteed HAP 

emission reduction 

(%) or emission rate

Sorbent or additive 

feed rate on which 

guarantee is based

Coal rank(s) upon 

which guarantee is 

based

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.

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

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

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

26 If additive is used, please indicate injection point.
21 For each boiler noted in Part I, question 15, provide the following information:

PM28 PM10

(29) PM2.5(30) SO2

HCl and/or 

HF

HCN

Metal 

HAP31 Hg CO

Other 

organics 

(specify)

Other pollutant 

(specify)

6 0.12 lb/MMBtu

(Title V permit; annual 

Reference Method 5 or 17)

N/A N/A 4.0 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A NOx: 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/A 4.0 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A NOx: 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/A 4.0 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A NOx: 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/A 4.0 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A NOx: 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/A 4.0 lb/MMBtu

(Title V permit; 24-hour rolling 

average)

N/A N/A N/A N/A N/A N/A NOx: 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.

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

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

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

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

Also include the compliance test method utilized.

29 List the compliance test method utilized.

30 List the compliance test method utilized.

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

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

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

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

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

Other organics 

(specify)

Other 

pollutant 

(specify)

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)

10

ESP: 0.06 lb/MMBtu, 

filterable (expired in 

2006); FGD: CBI

N/A N/A FGD: 98% instantaneous 

removal efficiency to meet a 

95% 30-day rolling average 

removal efficiency1

N/A N/A N/A N/A N/A N/A LNB: 0.45 

lb/MMBtu NOx 

guarantee 

(expired in 

2000)

Note: "N/A" means not applicable.

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

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

Please elaborate.

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

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

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

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

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

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

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

Boiler ID32
24 For each boiler noted in Part I, question15, provide the following information:

PM36 PM10 PM2.5 SO2

HCl 

and/or 

HF

HCN

Metal 

HAP37 Hg CO

Other 

organics 

(specify)

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/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

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

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

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

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours 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/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

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

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

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

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours 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/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

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

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

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

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours 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

HCN

Metal 

HAP37 Hg CO

Other 

organics 

(specify)

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

Boiler ID35

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/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

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

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

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

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours 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

10 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/A The installed Continuous Sulfur Dioxide Emissions Monitor will 

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

procedures. Data from this monitor will also be used to 

provide an indication of the sulfur dioxide emissions from 

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

hour rolling average.

A summary emission report will be submitted to ADEM within 

thirty days of the end of each calendar quarter.

Deviations from permit requirements shall be reported within 

48 hours 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.

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

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

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

36 If the boiler's monitoring, recordkeeping, and reporting requirements require your company to monitoring, keep records, and report filterable

and condensable PM separately, please describe the separate actions required.

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

indicate permit level for all metal HAP for which a permit level has been developed.
25 For the control technologies identified in Part I, questions 17 and 19, provide the cost information requested.38

Facility Name/Unit No.: N/A

Retrofit to existing boiler? 

Installation on a new boiler?

Total Capital Investment: $ -

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

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

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

No.

38 This can be treated as CBI and can be submitted through the proper CBI procedure if desired.
Fuel Analysis39

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

Gorgas

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

Plant Code - 8

39 The respondent should reply to this ICR with separate pages 18 through 24 (Part II) for each of their facilities.
2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

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

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

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

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

Method
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,669
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,111
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,879
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,897
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 11,864
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,834
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,768
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,811
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,537
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,571
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,715
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,544
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,537
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,997
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,558
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,917
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,010
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,882
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,285
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,938
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,485
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,621
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,205
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,782
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,707
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,915
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,891
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,196
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,381
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 12,539
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,615
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,713
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,577
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,613
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,506
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,135
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,506
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,495
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,374
D.B. D.B. D.B.

State/Country County42 Coal seam43 % Sulf % Ash Btu/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 13,350
3 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information44

, as

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

09-600 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 1.2 AL 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 1.9 AL 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 2.1 AL 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 0.8 IN 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 1.1 AL 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 1.1 AL 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 1.7 AL 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 1.5 AL 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 1.4 AL 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 2.1 AL 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 0.8 AL 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 1.2 AL 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 1.0 IN 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 2.3 AL 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 0.9 AL 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 1.5 AL 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 1.4 AL 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 2.0 AL 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 0.8 AL 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 2.1 AL 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 1.3 AL 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 1.7 AL 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 1.8 AL 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 1.0 AL 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 2.2 AL 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 1.1 AL 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 1.5 AL 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 0.7 AL 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 0.9 IN 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 2.2 AL 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 1.6 AL 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 1.8 AL 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 1.0 AL 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 1.9 AL 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 1.3 AL 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 1.8 AL 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 1.0 IL 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.

44 To the extent that a vendor provides these data or that a facility is required by State or local agency to analyze its fuel for HAP constituents (e.g., Cl, F), 

and any metallic HAP (e.g., Hg, Pb, As, Se, etc.), EPA wishes the responding facility to provide those fuel analyses results. Otherwise, this 12-month fuel

analysis requirement can be bypassed by the respondent.

45 Metal HAP includes compounds of antimony, arsenic, beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, phosphorus, and selenium.

Sample ID # State/Country County Coal Seam

Fuel Shipment 

Method

Total amount of 

fuel represented 

by sample, tons

Total 

Sulfur, %

Ash 

Content, %

Heating Value, 

Btu/lb

Mercury, 

ppm

Chlorine, 

ppm

Fluorine, 

ppm

Nickel, 

ppm

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

____ permit requirements

____ contractual obligations

____ standard operational procedures

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

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

____ Fuel supplier (name and address)

_X__ Other (name and address)

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

Alabama Power Company, General Services Laboratory

744 Highway 87, GSC #8

Calera, AL 35040

6 Name and address of laboratory performing analyses:

Alabama Power Company, General Services Laboratory

744 Highway 87, GSC #8

Calera, AL 35040

7 In addition to the analyses required in Part II, question 3 above, for samples for which analyses of chlorine and/or any of the HAP metals were 

conducted, please provide copies of any analyses conducted over the preceding 12 calendar months for (a) complete proximate and ultimate 

analyses, (b) additional trace metals, and (c) the mineralogy of the ash that are readily available for the oil(s) or coal(s) listed in Part II, question

2 above. The Agency is requesting these data only as they may already be available; no additional sampling or analyses are required to provide

these data.

Total 

Moisture Volatiles Ash Fixed Carbon Carbon Hydrogen Nitrogen Total Sulfur Oxygen Barium Copper Magnesium Sodium Vanadium Zinc Al2O3 Fe2O3 CaO MgO MnO2 P2O5 K2O SiO2 Na2O SO3 TiO2

09-600 9.10 28.57 12.27 59.16 76.78 4.55 1.70 1.16 3.54 210 20.9 0.101 0.037 39.0 21.2 26.88 8.82 2.20 1.36 0.04564 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 0.110 0.048 47.5 21.1 29.58 9.43 1.48 1.14 0.04478 0.35 2.44 51.80 0.41 1.67 1.41

09-604 6.44 28.49 14.86 56.65 74.96 4.52 1.40 1.15 3.11 260 21.8 0.131 0.025 44.0 12.7 26.96 6.87 0.89 1.46 0.02962 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 0.034 0.065 21.1 20.2 23.70 10.88 2.39 0.85 0.02686 0.60 2.67 54.06 1.29 2.10 1.35

09-611 5.40 28.08 17.58 54.34 69.55 4.39 1.39 1.28 5.81 260 23.3 0.148 0.028 44.2 27.2 27.59 8.93 0.69 1.40 0.03005 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 0.097 0.031 37.4 15.0 28.00 6.40 0.85 1.12 0.03113 0.38 2.88 57.70 0.29 0.66 1.38

09-613 5.94 30.53 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 1.15 0.11987 0.57 2.71 51.63 0.27 1.32 1.29

09-614 5.01 30.17 16.36 53.47 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 1.15 0.07950 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 0.097 0.028 40.0 21.9 24.78 17.48 0.81 1.10 0.04148 0.45 2.80 49.70 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 1.15 0.04334 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 0.136 0.034 52.9 24.0 24.78 11.06 1.84 1.40 0.03733 0.33 3.23 53.73 0.28 2.00 1.18

09-620 6.84 29.30 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 1.11 0.02293 0.36 2.76 55.22 0.21 0.79 1.19

09-104 13.14 35.30 7.39 57.31 76.78 3.99 1.70 1.29 8.85 30 7.5 0.038 0.065 24.1 14.4 23.40 13.20 1.75 0.84 0.02409 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 0.094 0.020 45.5 16.9 29.18 8.06 0.90 1.16 0.02901 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 0.084 0.029 38.4 16.6 25.25 13.23 0.87 1.04 0.03089 0.43 2.75 53.29 0.30 1.19 1.30

09-629 5.11 30.61 14.06 55.33 72.85 4.67 1.66 0.86 5.90 270 18.2 0.089 0.030 36.1 20.1 28.18 5.90 1.26 1.04 0.03426 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 0.104 0.053 45.8 16.3 28.12 6.51 0.68 1.07 0.02608 0.44 2.48 57.95 0.45 0.69 1.42

09-631 7.06 33.02 15.64 51.34 70.92 4.76 1.68 1.52 5.48 590 23.1 0.108 0.044 42.8 25.1 24.41 11.82 1.29 1.14 0.09327 0.58 2.97 53.98 0.38 1.66 1.28

09-632 5.06 29.22 17.04 53.74 70.50 4.51 1.55 1.78 4.62 630 35.3 0.118 0.036 53.6 38.4 26.01 13.72 1.01 1.14 0.12788 0.65 2.82 51.07 0.28 1.45 1.37

09-647 5.47 31.74 11.50 56.76 75.55 4.64 1.62 1.19 5.50 820 35.8 0.070 0.028 43.5 17.0 27.00 8.79 1.50 1.01 0.03312 0.64 2.44 53.87 0.33 1.93 1.53

09-645 7.24 30.40 11.65 57.95 76.24 4.72 1.19 2.18 4.02 280 21.6 0.064 0.022 31.3 15.6 22.12 19.62 1.32 0.92 0.03049 0.35 2.61 49.66 0.26 1.63 1.17

09-644 5.17 29.97 13.26 56.77 74.48 4.60 1.23 0.97 5.15 210 19.8 0.084 0.021 32.4 12.8 26.69 8.80 1.42 1.04 0.03156 0.46 2.60 55.87 0.22 1.33 1.35

09-643 5.84 29.33 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 1.17 0.05175 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 0.106 0.024 37.9 18.5 25.05 7.88 1.65 1.20 0.02831 0.42 3.06 57.80 0.22 1.43 1.14

09-638 6.84 27.63 14.28 58.09 74.12 4.53 1.20 1.07 4.80 250 26.3 0.100 0.034 39.1 16.7 28.89 9.15 1.10 1.16 0.03540 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 1.19 0.03738 0.42 2.76 52.45 0.31 2.35 1.33

09-648 6.55 30.16 15.26 54.58 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 1.11 0.04645 0.38 2.76 56.87 0.33 0.67 1.41

09-649 5.20 34.06 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 0.92 0.05017 0.75 2.38 48.92 0.40 4.08 1.21

09-105 14.39 34.98 8.04 56.98 75.91 4.79 1.32 1.38 8.56 30 7.5 0.039 0.060 22.6 21.5 22.09 12.26 1.69 0.80 0.02638 0.40 2.63 56.29 1.01 1.37 1.29

09-651 8.58 27.07 15.30 57.63 73.15 4.57 1.55 1.18 4.25 250 25.4 0.106 0.035 44.4 16.1 28.35 9.48 1.21 1.14 0.03763 0.30 2.75 53.36 0.31 1.47 1.39

09-653 7.62 31.23 11.60 57.17 74.96 4.85 1.90 1.09 5.60 410 21.9 0.081 0.035 36.2 17.3 27.14 9.08 1.79 1.16 0.08669 0.37 2.74 53.60 0.41 1.83 1.36

09-654 9.06 26.70 13.30 60.00 76.03 4.69 1.54 1.12 3.32 250 26.4 0.108 0.039 47.0 19.7 27.55 8.90 2.24 1.35 0.03920 0.38 3.05 52.19 0.39 2.35 1.28

09-657 11.74 32.25 12.96 54.79 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 1.31 0.03228 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 0.091 0.036 48.8 20.8 25.86 14.23 0.94 1.05 0.03064 0.51 2.71 51.51 0.34 1.06 1.31

09-659 7.10 29.72 14.18 56.10 72.67 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 0.99 0.02238 0.49 2.86 52.42 0.28 1.00 1.35

09-661 7.88 29.55 15.16 55.29 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 1.12 0.04315 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 0.82 0.02648 0.30 2.51 58.15 1.10 1.08 1.31

Sample ID 

#

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

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

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

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

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

Report 1 Unit 6 Particulate Emissions Test (June 15, 2005)

Report 2 Unit 7 Particulate Emissions Test (June 16, 2005)

Report 3 Unit 8 Particulate Emissions Test (June 8, 2005)

Report 4 Unit 9 Particulate Emissions Test (June 7, 2005)

Report 5 Unit 10 Particulate Emissions Test (June 9, 2005)

Report 6 Unit 6 Particulate Emissions Test (July 12, 2006)

Report 7 Unit 7 Particulate Emissions Test (July 11, 2006)

Report 8 Unit 8 Particulate Emissions Test (June 9, 2006)

Report 9 Unit 9 Particulate Emissions Test (June 8, 2006)

Report 10 Unit 10 Particulate Emissions Test (June 13, 2006)

Report 11 Unit 6 Particulate Emissions Test (July 10, 2007)

Report 12 Unit 7 Particulate Emissions Test (July 11, 2007)

Report 13 Unit 8 Particulate Emissions Test (June 5, 2007)

Report 14 Unit 9 Particulate Emissions Test (July 13, 2007)

Report 15 Unit 10 Particulate Emissions Test (June 6, 2007)

Report 16 Unit 6 Particulate Emissions Test (June 25, 2008)

Report 17 Unit 7 Particulate Emissions Test (June 27, 2008)

Report 18 Units 8, 9, and 10 Particulate Emissions Test (June 27, 2008)

Report 19 Unit 6 Particulate Emissions Test (July 1, 2009)

Report 20 Unit 7 Particulate Emissions Test (July 1, 2009)

Report 21 Units 8, 9, and 10 Particulate Emissions Test (July 30, 2009)

Report 22 Unit 6 Compliance Assurance Monitoring Test (September 6, 2007)

Report 23 Unit 7 Compliance Assurance Monitoring Test (July 12, 2007)

Report 24 Unit 9 Compliance Assurance Monitoring Test (November 30, 2007)

Report 25 Unit 10 Compliance Assurance Monitoring Test (June 7, 2007)

Report 26 Units 8, 9, and 10 Scrubber Performace Test (January 21 - February 1, 2008)

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

air pollutants) sampled for:

Report 1 Date: 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

8c Do any of these test reports reflect testing at a location before any emission control devices?

Yes _X__ No ____ If yes, please note which reports and provide a detailed description of the location of the emissions sampling point(s).

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.

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

Yes ____ No _X__ If yes, please not which reports and identify the other material(s) or non-fossil fuels used.

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

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

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

Yes _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.

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

2

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

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.

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

2

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

3

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

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 

SO3 formation3

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 - 

SO3 injection (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 

SO3 formation2

N/A (2) flue gas conditioning - 

SO3 injection (04/1985)

(4) cold-side ESP 

(10/27/1972)

N/A

8g Do any of these test reports reflect testing at a location before a post combustion SO2 emission control device (e.g., FGD, SDA, Dry Scrubber)?

Yes _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.
9 What type of deviation reporting is required for violations of permit requirements?

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

those attributable to upset conditions as defined in the permit. The report will include the probable cause of said deviations,

and any corrective actions or preventive measures that were taken.

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

reports submitted to ADEM.

Note: Not all reported deviations are considered violations of permit requirements.

10 Are deviation reports available for malfunctions or other periods of noncompliance with permit terms and conditions?

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

Deviation cause and corrective action reports are also 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.

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

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

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

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

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

Units 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.

46 Where units are monitored by CEMS (either following CAMR, State, or NIST QA/QC procedures), and where data are available, EPA requests

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

Test 

Report

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

(specify)

6 Report 1 6/15/2005 See Attachment 1 N/A N/A N/A N/A N/A N/A

7 Report 2 6/16/2005 See Attachment 2 N/A N/A N/A N/A N/A N/A

8 Report 3 6/8/2005 See Attachment 3 N/A N/A N/A N/A N/A N/A

9 Report 4 6/7/2005 See Attachment 4 N/A N/A N/A N/A N/A N/A

10 Report 5 6/9/2005 See Attachment 5 N/A N/A N/A N/A N/A N/A

6 Report 6 7/12/2006 See Attachment 6 N/A N/A N/A N/A N/A N/A

7 Report 7 7/11/2006 See Attachment 7 N/A N/A N/A N/A N/A N/A

8 Report 8 6/9/2006 See Attachment 8 N/A N/A N/A N/A N/A N/A

9 Report 9 6/8/2006 See Attachment 9 N/A N/A N/A N/A N/A N/A

10 Report 10 6/13/2006 See Attachment 10 N/A N/A N/A N/A N/A N/A

6 Report 11 7/10/2007 See Attachment 11 N/A N/A N/A N/A N/A N/A

7 Report 12 7/11/2007 See Attachment 12 N/A N/A N/A N/A N/A N/A

8 Report 13 6/5/2007 See Attachment 13 N/A N/A N/A N/A N/A N/A

9 Report 14 7/13/2007 See Attachment 14 N/A N/A N/A N/A N/A N/A

10 Report 15 6/6/2007 See Attachment 15 N/A N/A N/A N/A N/A N/A

6 Report 16 6/25/2008 See Attachment 16 N/A N/A N/A N/A N/A N/A

7 Report 17 6/27/2008 See Attachment 17 N/A N/A N/A N/A N/A N/A

8, 9, 10 Report 18 6/27/2008 See Attachment 18 N/A N/A N/A N/A N/A N/A

6 Report 19 7/1/2009 See Attachment 19 N/A N/A N/A N/A N/A N/A

7 Report 20 7/1/2009 See Attachment 20 N/A N/A N/A N/A N/A N/A

8, 9, 10 Report 21 7/30/2009 See Attachment 21 N/A N/A N/A N/A N/A N/A

6 Report 22 9/6/2007 See Attachment 22 N/A N/A N/A N/A N/A N/A

7 Report 23 7/12/2007 See Attachment 23 N/A N/A N/A N/A N/A N/A

9 Report 24 11/30/2007 See Attachment 24 N/A N/A N/A N/A N/A N/A

10 Report 25 6/7/2007 See Attachment 25 N/A N/A N/A N/A N/A N/A

8, 9, 10 Report 26 1/21 - 2/1/2008 See Attachment 26 See Attachment 29 See Attachment 27 N/A See Attachment 28 See Attachment 27 N/A

Note: "N/A" means not applicable.

47 Provide emission test data for all tests conducted since January 1, 2005. Please indicate test data acquired both before and after

any control device. Use additional pages as necessary. EPA may, at some future date, request a copy of one or more emission test reports.

Data generated to fulfill both Federal and State requirements must be provided. Note that data generated pursuant to CAA Title V

must be maintained and available for 5 years. Also include averaging times and measurement units for all pollutants.

48 For each emissions test run the respondent should provide the following process information: Unit Load (MW), Net generation during run (MWh net),

Flue gas moisture content (%), Flue gas flow rate (dscfm or Nm3/hr), Flue gas oxygen content (%, dry), Flue gas carbon dioxide content (%, dry), Flue gas

temperature at sampling point (oF), Flue gas pressure at sampling point (atm), Standard temperature (oF), Standard pressure (atm).

49 If emission testing recorded the emissions of filterable and condensable PM, separately, please include those separate emission results. 

Also, please include separate emission results for total PM, PM10, and PM2.5.

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

indicate emission level for all metal HAP for which an emission test has been conducted.

51 Please provide separate results for total Hg, elemental Hg, oxidized Hg, and particulate Hg, as available. If the emissions testing recorded

the amount of unburned carbon in fly ash (as reflected by the "Loss of Ignition" [L.O.I]) at the time of any Hg testing, please include these data.

Boiler ID

Emissions test results (indicate format of emission data)47,48
DIAGRAM 1 - Sampling Port Locations for Units 8, 9, and 10

Scrubber Performance Testing (Report 26)

FLUE GAS 

From Boilers

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 

TEST PORTS IN 

STACK
ATTACHMENT 1 - Gorgas Report 1 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/15/2005 6/15/2005 6/15/2005

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 162.000 162.000 162.000

Avg. Sqr. Root Velocity Pressure Inches 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 3 Average

Volume of Gas Sampled Standard Dry 64.205 60.190 58.890 61.095

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.35 29.29 29.35 29.33

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 522,653 529,511 525,236 525,800

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 363,659 366,671 363,593 364,641

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 339,282 339,830 338,940 339,351

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 25,412 25,453 25,387 25,417

Per Minute

Particulate Concentration Grains per Standard 0.0230 0.0343 0.0132 0.0235

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0149 0.0220 0.0085 0.0152

 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 0.032 0.057

 Btu (Heat Input)

Isokinetic Rate Percent 98.5 98.5 93.0 96.7

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 Pressure DH@ Inches Water 2.34 2.34 2.34

Date Month/Day/Year 6/16/2005 6/16/2005 6/16/2005

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 162.000 162.000 162.000

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 3 Average

Volume of Gas Sampled Standard Dry 58.519 62.797 57.639 59.652

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.25 29.28 29.31 29.28

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 524,766 538,651 507,360 523,592

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 369,401 378,522 356,635 368,186

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 341,646 351,148 331,461 341,418

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 25,589 26,301 24,826 25,572

Per Minute

Particulate Concentration Grains per Standard 0.0167 0.0159 0.0101 0.0142

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0109 0.0103 0.0066 0.0093

 Cubic Foot

Particulate Emission Rate Pounds per Hour 49.0 47.8 28.8 41.8

Particulate Emission Rate Pounds per Million 0.039 0.039 0.023 0.034

 Btu (Heat Input)

Isokinetic Rate Percent 101.9 101.3 99.5 100.9

Post Test Meter Correction Factor dimensionless 0.97 0.97 1.00 0.981

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 1 RUN 2 RUN 3a RUN 3b

Date Month/Day/Year 6/8/2005 6/8/2005 6/8/2005 6/8/2005

Sampling Time -Start Military 0758 0758 1021 1021

Sampling Time -Stop Military 1006 1006 1125 1124

Number of Ports dimensionless 16 16 8 8

Number of Points per Port dimensionless 4 4 4 4

Heat Input Million Btu per Hour 1,756 1,756 1,726 1,726

Stack Static Pressure Inches Water -12.00 -12.00 -12.00 -12.00

Barometric Pressure Inches Mercury 29.95 29.95 29.95 29.95

Meter Correction Factor dimensionless 1.046 1.011 1.011 1.046

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 73.646 76.535 38.649 38.891

Volume of Water Collected Milliliters 115 145 79 66

Sampling Time Minutes 128 128 64 64

Nozzle Diameter Inches 0.242 0.250 0.250 0.242

Weight of Solids Collected Milligrams 18.0 25.5 36.6 17.0

Area of Stack Square Feet 232.500 232.500 116.250 116.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.6804 0.6977 0.6951 0.7134

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 1 RUN 2 RUN 3a RUN 3b Average

Volume of Gas Sampled Standard Dry 76.164 75.873 37.820 40.061 63.659

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.48 29.27 29.18 29.16 29.308

Water vapor in Stack Gas Percent 6.6 8.3 9.0 7.2 7.654

Average Stack Gas Velocity Feet per second 46.3 47.3 47.0 48.9 47.166

Stack Gas Flow Rate Actual Cubic 645,365 660,047 327,554 340,940 657,969

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 430,623 446,053 223,679 226,476 442,277

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 402,049 409,240 203,655 210,177 408,374

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 30,113 30,652 15,254 15,742 30,587

Per Minute

Particulate Concentration Grains per Standard 0.0036 0.0052 0.0149 0.0065 0.00651

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0023 0.0032 0.0093 0.0040 0.00404

 Cubic Foot

Particulate Emission Rate Pounds per Hour 12.5 18.2 26.0 11.8 22.8

Particulate Emission Rate Pounds per Million 0.007 0.010 0.015 0.007 0.013

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

Isokinetic Rate Percent 107.7 98.8 98.9 108.4

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 1 RUN 2 RUN 3a RUN 3b

Date Month/Day/Year 6/7/2005 6/7/2005 6/7/2005 6/7/2005

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 74.459 74.890 41.130 36.839

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 232.500 232.500 116.250 116.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7333 0.7605 0.7594 0.7300

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 1 RUN 2 RUN 3a RUN 3b Average

Volume of Gas Sampled Standard Dry 73.527 76.679 40.394 37.725 63.089

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.02 29.07 29.11 28.76 29.01

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 694,032 720,384 360,140 346,499 707,019

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 472,453 488,865 243,374 236,584 480,425

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 432,576 450,942 225,749 213,658 440,975

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 32,400 33,776 16,909 16,003 33,029

Per Minute

Particulate Concentration Grains per Standard 0.0086 0.0088 0.0069 0.0082 0.0083

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0054 0.0055 0.0043 0.0050 0.0052

 Cubic Foot

Particulate Emission Rate Pounds per Hour 32.0 34.2 13.4 15.0 31.5

Particulate Emission Rate Pounds per Million 0.0194 0.0207 0.0081 0.0091 0.0191

Allowable Particulate Emission Rate Btu (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 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/9/2005 6/9/2005 6/9/2005 6/9/2005 6/9/2005 6/9/2005

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 39.217 41.212 41.887 37.569 40.460 42.554

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 0.9118 0.9228 0.9205 0.8221 0.8678 0.8815

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 A 3 Runs Side B Side B Side B 3 Runs

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 40.825 42.660 43.118 42.201 37.748 40.476 42.035 40.086

 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 1,391,900 1,407,048 1,391,657 1,396,868 1,226,978 1,312,581 1,346,879 1,295,480

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 909,651 931,483 932,348 924,494 836,732 881,177 891,190 869,700

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 853,555 849,044 867,038 856,546 782,117 813,097 815,404 803,539

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 63,931 63,593 64,941 64,155 58,581 60,901 61,074 60,185

Per Minute

Particulate Concentration Grains per Standard 0.0053 0.0104 0.0093 0.0083 0.0071 0.0100 0.0099 0.0090

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0033 0.0063 0.0058 0.0051 0.0046 0.0062 0.0060 0.0056

 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 0.0053 0.0103 0.0093 0.0083 0.0065 0.0094 0.0094 0.0084

 Btu (Heat Input)

Combined Particulate Emission Rate Pounds per Million 0.0118 0.0196 0.0187 0.0167

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 7/12/2006 7/12/2006 7/12/2006 7/12/2006 7/12/2006 7/12/2006

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 A Side A Side B Side B Side B Side B

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 31.773 34.422 34.453 33.549 34.919 35.217 34.352 34.830

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 29.21 29.13 29.16 29.17 28.93 29.27 29.24 29.15

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 276,729 264,844 268,591 270,054 280,281 285,206 284,113 283,200

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 183,749 179,666 179,032 180,816 188,253 190,539 187,486 188,759

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 170,841 164,381 165,678 166,967 170,343 177,713 174,125 174,060

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 12,796 12,312 12,409 12,506 12,759 13,311 13,042 13,037

Per Minute

Particulate Concentration Grains per Standard 0.0397 0.0238 0.0354 0.0330 0.0179 0.0123 0.0113 0.0139

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0245 0.0148 0.0218 0.0204 0.0109 0.0077 0.0070 0.0085

 Cubic Foot

Particulate Emission Rate Pounds per Hour 58.2 33.5 50.2 47.3 26.1 18.8 16.9 20.6

Particulate Emission Rate Pounds per Million 0.0514 0.0295 0.0442 0.0417 0.0231 0.0165 0.0149 0.0182

 Btu (Heat Input)

Combined Particulate Emission Rate Pounds per Million 0.0744 0.0461 0.0590 0.0599

Allowable Particulate Emission Rate Btu 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 7/11/2006 7/11/2006 7/11/2006 7/11/2006 7/11/2006 7/11/2006

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 A 3 Runs Side B Side B Side B 3 Runs

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 33.767 31.607 34.318 33.231 36.701 36.554 38.660 37.305

 Cubic Feet 

Molecular Wt. of Stack Gas LB/LB-MOLE 30.04 29.10 29.17 29.43 29.05 29.18 29.19 29.14

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 255,294 254,489 266,296 258,693 313,730 323,534 323,341 320,202

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 180,492 178,995 185,370 181,619 220,130 225,669 224,640 223,480

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 161,573 164,989 171,929 166,164 199,646 208,487 207,464 205,199

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 12,102 12,358 12,877 12,446 14,953 15,616 15,539 15,369

Per Minute

Particulate Concentration Grains per Standard 0.0185 0.0220 0.0166 0.0190 0.0280 0.0329 0.0263 0.0291

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0117 0.0143 0.0107 0.0122 0.0178 0.0212 0.0169 0.0186

 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 0.0210 0.0234 0.0414 0.0509 0.0403 0.0442

 Btu (Heat Input)

Combined Particulate Emission Rate Pounds per Million 0.0634 0.0779 0.0613 0.0675

Allowable Particulate Emission Rate Btu 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 1 RUN 2 RUN 3A RUN 3B

Date Month/Day/Year 6/9/2006 6/9/2006 6/9/2006 6/9/2006

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 Pressure DH@ 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 77.900 79.245 38.350 38.200

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 232.500 232.500 116.250 116.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7364 0.7100 0.6679 0.7244

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 1 RUN 2 RUN 3A RUN 3B AVERAGE

Volume of Gas Sampled Standard Dry 77.851 73.849 37.233 35.687 62.720

 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 687,199 671,814 311,120 344,974 671,702

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 476,276 458,730 216,304 231,827 461,046

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 442,561 416,518 201,527 213,521 424,709

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 33,148 31,197 15,094 15,993 31,811

Per Minute

Particulate Concentration Grains per Standard 0.0055 0.0036 0.0065 0.0087 0.0056

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0035 0.0022 0.0042 0.0054 0.0035

 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 0.010 0.013

Allowable Particulate Emission Rate Btu (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 Factor dimensionless 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 1 RUN 2 RUN 3A RUN 3B

Date Month/Day/Year 6/8/2006 6/8/2006 6/8/2006 6/8/2006

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 Pressure DH@ 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 80.045 81.500 42.455 40.100

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 232.500 232.500 116.250 116.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7574 0.7473 0.7814 0.7427

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 1 RUN 2 RUN 3A RUN 3B AVERAGE

Volume of Gas Sampled Standard Dry 74.128 81.128 38.685 39.421 64.770

 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 711,699 698,188 365,709 351,548 709,048

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 490,608 485,644 254,390 238,374 489,672

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 448,463 449,884 234,423 218,781 450,517

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 33,590 33,696 17,558 16,387 33,744

Per Minute

Particulate Concentration Grains per Standard 0.0065 0.0092 0.0074 0.0084 0.0079

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0041 0.0059 0.0047 0.0053 0.0050

 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 0.010 0.019

Allowable Particulate Emission Rate Btu (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 Factor dimensionless 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

Calculations
ATTACHMENT 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 6/13/2006 6/13/2006 6/13/2006 6/13/2006 6/13/2006 6/13/2006

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 Pressure DH@ Inches Water 2.008 2.008 2.008 2.378 2.378 2.378

Meter Correction Factor dimensionless 0.967 0.967 0.967 0.938 0.938 0.938

Oxygen Concentration Mole Percent O2 8.0 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 370.000 370.000 370.000 370.000 370.000 370.000

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 Side A Side B Side B Side B Side B Side

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 40.164 39.695 39.676 39.845 37.006 39.039 39.899 38.648

 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 1,396,903 1,372,616 1,385,470 1,384,996 1,253,684 1,355,168 1,408,286 1,339,046

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 900,154 881,502 886,786 889,481 822,471 887,920 920,786 877,059

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 831,907 816,623 818,789 822,440 766,873 820,636 854,270 813,926

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0113 0.0091 0.0081 0.0095 0.0139 0.0074 0.0092 0.0101

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0067 0.0054 0.0048 0.0056 0.0085 0.0045 0.0056 0.0062

 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 Rate Pounds 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 7/10/2007 7/10/2007 7/10/2007 7/10/2007 7/10/2007 7/10/2007

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 Pressure DH@ Inches Water 1.939 1.939 1.939 2.418 2.418 2.418

Meter Correction Factor dimensionless 0.981 0.981 0.981 0.937 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 B Side A Side B Combined

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Average Average Average/Total

Volume of Gas Sampled Standard Dry 33.991 38.609 34.954 31.350 35.289 29.247 35.851 31.962 33.907

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.25 30.20 29.96 30.21 30.22 29.86 30.14 30.10 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 269,660 276,704 281,138 246,570 255,985 254,271 275,834 252,275 528,109

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 184,607 189,065 191,521 170,660 176,686 175,518 188,398 174,288 362,686

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 171,102 176,379 175,671 156,989 163,594 160,062 174,384 160,215 334,599

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 12,816 13,211 13,158 11,758 12,253 11,989 13,061 12,000 25,061

Per Minute

Particulate Concentration Grains per Standard 0.040 0.019 0.046 0.024 0.017 0.021 0.035 0.021 0.028

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.026 0.012 0.029 0.015 0.011 0.013 0.022 0.013 0.018

 Cubic Foot

Particulate Emission Rate Pounds per Hour 59.2 29.1 68.9 32.6 24.0 29.1 52.4 28.6 81.0

Particulate Emission Rate Pounds per Million 0.053 0.026 0.063 0.029 0.022 0.027 0.048 0.026 0.073

Allowable Btu (Heat Input) 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12

Isokinetic Rate Percent 100.7 102.4 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 0.98 0.96

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 7/11/2007 7/11/2007 7/11/2007 7/11/2007 7/11/2007 7/11/2007

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 Pressure DH@ Inches Water 2.418 2.418 2.418 1.939 1.939 1.939

Meter Correction Factor dimensionless 0.939 0.939 0.939 0.981 0.981 0.981

Oxygen Concentration Mole Percent O2 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 B Side A Side B Combined

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Average Average Average/Total

Volume of Gas Sampled Standard Dry 36.657 37.163 36.280 40.157 38.141 40.587 36.700 39.628 38.164

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.85 29.84 29.67 29.92 30.08 30.20 29.79 30.07 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 304,114 308,657 307,512 308,189 314,464 310,666 306,761 311,106 617,867

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 205,428 208,524 207,504 210,496 213,161 210,389 207,152 211,349 418,501

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 188,486 193,341 192,286 191,220 194,882 192,731 191,371 192,945 384,316

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 14,118 14,481 14,402 14,322 14,597 14,436 14,334 14,452 28,785

Per Minute

Particulate Concentration Grains per Standard 0.014 0.004 0.014 0.035 0.053 0.030 0.011 0.039 0.025

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.009 0.003 0.009 0.022 0.033 0.018 0.007 0.024 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 0.045 0.016 0.058 0.074

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 98.5 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 1 RUN 2 RUN 3A RUN 3B

Date Month/Day/Year 6/5/2007 6/5/2007 6/5/2007 6/5/2007

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 Pressure DH@ 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 85.979 83.094 39.230 44.755

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 232.500 232.500 116.250 116.250

Avg. Sqr. Root Velocity Pressure Inches Water 0.7915 0.7800 0.7512 0.8179

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 1 RUN 2 RUN 3A RUN 3B AVERAGE

Volume of Gas Sampled Standard Dry 78.799 80.682 37.662 41.423 79.522

 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 741,453 728,667 349,396 388,158 606,505

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 511,984 500,725 243,769 261,907 506,128

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 476,676 467,964 223,901 243,377 470,640

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 35,703 35,050 16,770 18,229 35,251

Per Minute

Particulate Concentration Grains per Standard 0.015 0.011 0.011 0.010 0.012

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.010 0.007 0.007 0.006 0.008

 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 Factor dimensionless 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 2 RUN 3A RUN 3B

Date Month/Day/Year 7/13/2007 7/13/2007 7/13/2007 7/13/2007

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 Pressure DH@ 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 2 RUN 3A RUN 3B AVERAGE

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 786,532 754,318 390,666 368,512 766,676

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 539,224 512,888 269,176 249,719 523,669

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 498,884 483,665 245,961 232,682 487,064

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 37,366 36,227 18,422 17,428 36,481

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 0.008 0.006

 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 A Side A Side A Side B Side B Side B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/6/2007 6/6/2007 6/6/2007 6/6/2007 6/6/2007 6/6/2007

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 Pressure DH@ Inches Water 2.418 2.418 2.418 1.939 1.939 1.939

Meter Correction Factor dimensionless 0.939 0.939 0.939 0.981 0.981 0.981

Oxygen Concentration Mole Percent O2 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 46.296 46.224 50.920 42.366 43.355 45.837

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 370.000 370.000 370.000 370.000 370.000 370.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.9604 0.9437 1.0292 0.9021 0.8901 0.9414

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

RUN 1 RUN 2 RUN 3 AVERAGE RUN 1 RUN 2 RUN 3 AVERAGE TOTAL

Volume of Gas Sampled Standard Dry 43.543 42.608 46.703 44.285 41.393 41.462 43.534 42.130 43.207

 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 1,482,022 1,466,695 1,592,333 1,513,684 1,381,795 1,369,783 1,445,744 1,399,107 2,912,791

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 948,588 933,311 1,016,456 966,118 899,825 885,244 929,958 905,009 1,871,127

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 889,907 863,661 956,675 903,414 843,250 821,804 874,192 846,415 1,749,829

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 66,654 64,688 71,655 67,666 63,159 61,553 65,477 63,396 65,531

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 99.9 100.6 101.3 102.4 101.1 101.6 101.12

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 A Side B Side B Side B 

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/25/2008 6/25/2008 6/25/2008 6/25/2008 6/25/2008 6/25/2008

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 Pressure Inches 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 A Side B TOTAL or

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 39.723 40.405 39.919 33.683 35.286 35.257 40.016 34.742 74.757

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.88 29.86 29.82 30.24 30.00 30.00 29.85 30.08 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 278,328 284,227 274,019 232,435 234,109 240,793 278,858 235,779 514,637

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 192,390 196,066 188,289 160,365 160,204 163,587 192,248 161,385 353,633

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 179,065 182,225 174,293 149,501 149,254 150,710 178,528 149,821 328,349

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 13,412 13,649 13,055 11,198 11,179 11,288 13,372 11,222 24,593

Per Minute

Particulate Concentration Grains per Standard 0.028 0.024 0.032 0.025 0.019 0.023 0.028 0.022 0.03

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.018 0.015 0.021 0.016 0.012 0.014 0.018 0.014 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 0.025 0.037 0.024 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 Check dimensionless 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 A Side B Side B Side B 

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/27/2008 6/27/2008 6/27/2008 6/27/2008 6/27/2008 6/27/2008

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 Concentration Mole 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 Pressure Inches 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 A Side B TOTAL or

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 42.351 39.590 41.580 38.459 32.617 40.510 41.174 37.195 78.369

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.92 30.08 30.00 30.26 30.36 30.04 30.00 30.22 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 306,582 286,602 292,594 267,788 232,793 278,495 295,259 259,692 554,951

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 206,884 192,981 196,521 182,714 157,739 188,230 198,796 176,228 375,023

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 192,447 178,546 182,532 168,867 146,728 173,698 184,508 163,098 347,606

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 14,414 13,373 13,672 12,648 10,990 13,010 13,820 12,216 26,036

Per Minute

Particulate Concentration Grains per Standard 0.013 0.010 0.009 0.087 0.057 0.042 0.011 0.062 0.01

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.008 0.006 0.006 0.055 0.036 0.026 0.007 0.039 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 0.052 0.014 0.073 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

Calculations
ATTACHMENT 18 - Gorgas Report 18 Test Results

Title of Run RUN 1 RUN 2 RUN 3

Date Month/Day/Year 6/27/2008 6/27/2008 6/27/2008

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 1,134.11 1,134.11 1,134.11

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 3 AVERAGE

Volume of Gas Sampled Standard Dry 38.569 39.114 39.157 38.947

 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

Saturated Saturated Saturated

Average Stack Gas Velocity Feet per second 50.0 51.2 51.6 50.9

Stack Gas Flow Rate Actual Cubic 3,404,117 3,481,485 3,509,853 3,465,152

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 3,019,298 3,090,558 3,109,983 3,073,280

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 2,604,525 2,671,705 2,675,966 2,650,732

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 195,079 200,111 200,430 198,540

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 Check dimensionless 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 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 7/1/2009 7/1/2009 7/1/2009 7/1/2009 7/1/2009 7/1/2009

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 Concentration Mole Percent CO2 9.0 9.0 12.0 9.50 10.50 12.00

Volume of Gas Metered Actual Cubic Feet 36.925 40.691 48.267 43.310 42.715 43.500

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 81.000 81.000 81.000 81.000 81.000 81.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.7039 0.7640 0.7526 0.8736 0.8807 0.8815

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 A Side B TOTAL or

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE AVERAGE

Volume of Gas Sampled Standard Dry 34.594 38.062 45.346 40.325 39.759 40.542 39.334 40.208 79.542

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.70 29.68 30.28 29.76 30.04 30.28 29.89 30.03 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 233,337 253,429 247,281 294,796 298,136 291,877 244,682 294,936 539,618

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 157,675 170,975 166,445 192,280 192,036 193,647 165,031 192,654 357,686

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 147,256 160,087 156,686 178,623 177,088 181,825 154,676 179,179 333,855

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 11,029 11,990 11,736 13,379 13,264 13,619 11,585 13,420 25,006

Per Minute

Particulate Concentration Grains per Standard 0.0115 0.0109 0.0105 0.0040 0.0050 0.0070 0.0110 0.0054 0.0080

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0072 0.0069 0.0067 0.0025 0.0030 0.0044 0.0069 0.0033 0.0050

 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 0.010 0.013 0.008 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 95.8 102.0 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 A SIDE A SIDE B SIDE B

Title of Run RUN 1 RUN 2 RUN 3 RUN 2 RUN 3

Date Month/Day/Year 7/1/2009 7/1/2009 7/1/2009 7/1/2009 7/1/2009

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 Concentration Mole Percent CO2 10.0 9.0 9.0 9.0 9.0

Volume of Gas Metered Actual Cubic Feet 84.355 45.788 45.314 46.170 48.170

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 162.000 81.000 81.000 81.000 81.000

Avg. Sqr. Root Velocity Pressure Inches Water 0.8896 0.8888 0.8659 0.9780 0.9881

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 A SIDE A SIDE B SIDE B

RUN 1 RUN 2 RUN 3 RUN 2 RUN 3 AVERAGE

Volume of Gas Sampled Standard Dry 81.399 43.404 42.630 44.034 45.346 56.369

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.92 29.76 29.76 29.76 29.76 29.813

Water vapor in Stack Gas Percent 8.2 6.6 7.2 7.0 7.7 7.458

Average Stack Gas Velocity Feet per second 60.9 60.7 59.3 67.0 67.6 62.727

Stack Gas Flow Rate Actual Cubic 591,943 294,911 288,147 325,612 328,508 609,707

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 396,839 198,497 193,297 218,042 221,288 409,321

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 364,486 185,427 179,429 202,883 204,184 378,803

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 27,300 13,888 13,439 15,196 15,293 28,372

Per Minute

Particulate Concentration Grains per Standard 0.011 0.005 0.006 0.017 0.019 0.011

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.007 0.003 0.004 0.010 0.012 0.007

 Cubic Foot

Particulate Emission Rate Pounds per Hour 33.3 8.3 9.2 29.0 33.1 24.364

Particulate Emission Rate Pounds per Million 0.030 0.007 0.008 0.026 0.030 0.034

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 7/30/2009 7/30/2009 7/30/2009

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 1,134.110 1134.110 1134.110

Avg. Sqr. Root Velocity Pressure Inches 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 3 AVERAGE

Volume of Gas Sampled Standard Dry 36.665 37.500 36.638 36.934

 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 3,514,825 3,564,384 3,523,862 3,534,357

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 3,092,954 3,134,387 3,137,514 3,121,618

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 2,646,219 2,677,343 2,674,074 2,665,879

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic Feet 4,647,562 4,337,711 4,696,483 4,560,586

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 Check dimensionless 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 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 9/6/2007 9/6/2007 9/6/2007 9/6/2007 9/6/2007 9/6/2007

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 Pressure DH@ Inches Water 1.939 1.939 1.939 2.418 2.418 2.418

Meter Correction Factor dimensionless 0.981 0.981 0.981 0.939 0.939 0.939

Oxygen Concentration Mole Percent O2 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 40.779 40.248 39.312 37.407 36.535 35.988

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 0.7626 0.7673 0.7614 0.7723 0.7766 0.7376

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 A Side B Combined

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 AVERAGE AVERAGE Average/Total

Volume of Gas Sampled Standard Dry 38.975 38.155 37.187 34.478 33.508 32.861 38.105 33.616 35.861

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.28 30.08 29.93 30.30 30.16 30.10 30.10 30.19 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 251,545 254,766 252,539 251,468 253,892 240,933 252,950 248,764 501,714

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 169,503 171,805 170,202 174,064 175,185 166,344 170,503 171,864 342,368

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 155,943 154,980 156,531 159,477 160,321 153,382 155,818 157,727 313,544

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 11,680 11,608 11,724 11,945 12,008 11,488 11,671 11,814 23,484

Per Minute

Particulate Concentration Grains per Standard 0.022 0.035 0.049 0.022 0.022 0.035 0.036 0.026 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 0.040 0.042 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

Calculations
ATTACHMENT 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 7/12/2007 7/12/2007 7/12/2007 7/12/2007 7/12/2007 7/12/2007

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 Pressure DH@ Inches Water 2.418 2.418 2.418 1.939 1.939 1.939

Meter Correction Factor dimensionless 0.939 0.939 0.939 0.981 0.981 0.981

Oxygen Concentration Mole Percent O2 9.0 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 B Side A Side B Combined

RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Average Average Average/Total

Volume of Gas Sampled Standard Dry 40.054 37.068 37.071 35.085 34.015 37.153 38.064 35.418 36.741

 Cubic Feet 

Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 29.88 29.69 29.84 30.08 30.06 29.92 29.80 30.02 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 297,685 305,662 295,672 282,630 286,004 302,528 299,673 290,387 590,060

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 201,982 206,900 199,654 194,640 197,640 208,551 202,845 200,277 403,122

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 187,853 192,707 185,083 180,813 184,135 190,015 188,548 184,988 373,535

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 14,070 14,434 13,863 13,543 13,792 14,232 14,122 13,856 27,978

Per Minute

Particulate Concentration Grains per Standard 0.008 0.011 0.020 0.020 0.027 0.038 0.013 0.028 0.021

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.005 0.007 0.012 0.013 0.017 0.024 0.008 0.018 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 0.055 0.019 0.041 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 11/30/2007 11/30/2007 11/30/2007 11/30/2007

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 Pressure DH@ 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 Pressure Inches 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 3 AVERAGE

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 391,547 357,767 739,093 714,405 734,270

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 277,549 256,895 528,435 512,658 525,179

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 255,762 237,060 498,361 484,156 491,780

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 19,157 17,756 37,327 36,263 36,834

Per Minute

Particulate Concentration Grains per Standard 0.004 0.006 0.004 0.004 0.005

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.003 0.004 0.003 0.003 0.003

 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 0.010 0.011

 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

Calculations
ATTACHMENT 25 - Gorgas Report 25 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 6/7/2007 6/7/2007 6/7/2007 6/7/2007 6/7/2007 6/7/2007

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 Pressure DH@ Inches Water 2.418 2.418 2.418 1.939 1.939 1.939

Meter Correction Factor dimensionless 0.939 0.939 0.939 0.981 0.981 0.981

Oxygen Concentration Mole Percent O2 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 49.186 48.702 45.665 40.486 39.714 36.698

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 370.000 370.000 370.000 370.000 370.000 370.000

Avg. Sqr. Root Velocity Pressure Inches Water 1.0201 1.0064 0.9804 0.8558 0.8103 0.7324

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

RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average Total

Volume of Gas Sampled Standard Dry 45.435 44.417 41.549 43.800 38.806 37.615 34.467 36.963 40.382

 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 1,587,336 1,576,627 1,536,698 1,566,887 1,320,062 1,250,723 1,132,876 1,234,554 2,801,441

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 998,968 986,943 963,685 983,199 857,524 811,492 732,071 800,362 1,783,561

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 928,731 909,810 886,366 908,302 783,407 741,018 668,195 730,873 1,639,176

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 69,562 68,145 66,389 68,032 58,677 55,502 50,048 54,742 61,387

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 1/30/2008 1/30/2008 1/30/2008 1/31/2008 1/31/2008

Time 0819-1103 1231-1516 1610-1850 0800-1039 1200-1400

Volumetric Flow Rate (DSCFM, 68F) 3,147,006 3,028,088 2,925,318 2,811,617 2,804,351

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 1/22/2008 1/29/2008 1/30/2008 1/30/2008 1/30/2008 1/31/2008 1/31/2008

Time 1100-1415 1225-1540 0800-1117 1200-1511 1600-1911 0800-1109 1200-1509

Volumetric Flow Rate (DSCFM, 68F) 2,651,871 2,578,549 2,677,567 2,606,577 2,717,043 2,596,882 2,679,632

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 1/25/2008 1/25/2008 1/25/2008 1/25/2008 1/25/2008 1/25/2008

Time 0932-0945 0934-1022 1054-1152 1217-1229 1251-1333 1355-1432

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 1/30/2008 1/30/2008 1/30/2008 1/31/2008 1/31/2008

Time 0819-1103 1231-1516 1610-1850 0800-1039 1200-1400

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 1/22/2008 1/29/2008 1/30/2008 1/30/2008 1/30/2008 1/31/2008 1/31/2008

Time 1100-1415 1225-1540 0800-1117 1200-1511 1600-1911 0800-1109 1200-1509

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 Time HCl (ppmv) HF (ppmv)

1/23/2008 1553-1651 18.58 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 O2 Outlet O2

%, dry %, dry Inlet Hg0

Inlet Hg+2 Inlet HgT % Oxidized Outlet Hg0Outlet Hg+2 Outlet HgT % Oxidized

Preliminary 1/24/2008 1138-1238 7.3 7.5 8.70 8.34 17.04 48.9% 9.46 0.32 9.78 3.3%

Run #1 1/27/2008 1053-1253 9.0 9.0 12.48 12.01 24.49 49.0% 10.92 0.34 11.27 3.0%

Run #2 1/27/2008 1409-1609 9.0 9.0 12.49 31.76 44.25 71.8% 10.49 0.20 10.70 1.9%

Run #3 1/28/2008 0900-1000 8.0 8.0 10.47 14.72 25.20 58.4% 10.81 0.93 11.74 7.9%

Run #4 1/28/2008 1128-1228 8.0 8.0 10.03 17.97 28.00 64.2% 10.73 0.60 11.33 5.3%

Run #5 1/28/2008 1313-1413 8.0 8.0 10.34 18.82 29.16 64.5% 7.45 0.28 7.74 3.6%

Run #6 1/28/2008 1500-1600 8.0 8.0 9.56 21.61 31.17 69.3% 9.88 0.56 10.45 5.4%

Preliminary 1/24/2008 1138-1238 7.3 7.5 12.29 11.78 24.07 48.9% 13.56 0.46 14.02 3.3%

Run #1 1/27/2008 1053-1253 9.0 9.0 20.15 19.39 39.53 49.0% 17.63 0.55 18.19 3.0%

Run #2 1/27/2008 1409-1609 9.0 9.0 20.16 51.27 71.43 71.8% 16.93 0.32 17.27 1.9%

Run #3 1/28/2008 0900-1000 8.0 8.0 15.59 21.92 37.53 58.4% 16.1 1.38 17.48 7.9%

Run #4 1/28/2008 1128-1228 8.0 8.0 14.94 26.76 41.70 64.2% 15.98 0.89 16.87 5.3%

Run #5 1/28/2008 1313-1413 8.0 8.0 15.4 28.03 43.42 64.5% 11.09 0.42 11.53 3.6%

Run #6 1/28/2008 1500-1600 8.0 8.0 14.24 32.18 46.42 69.3% 14.71 0.83 15.56 5.4%

Date

Inlet Hg0Inlet Hg+2 Inlet HgT % Oxidized Outlet Hg0Outlet Hg+2 Outlet HgT % Oxidized Inlet 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 Time Inlet 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, 

0 oC)

Outlet HgT 

(μg/Nm3)

(3% O2, dry, 

0 oC)

1 1/28/2008 1125-1205 8.0 8.0 25.0 1.32 36.3 17.3 54.8 25.1

2 1/28/2008 1229-1309 8.0 8.0 27.4 17.2 34.5 17.0 52.5 25.0

3 1/28/2008 1328-1408 8.0 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, 68 oF)

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

Tekran CEMS Speciated Mercury Data

Inlet Outlet Dynamic Spike Recovery Factors

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

DATA CORRECTED FOR SPIKE (μg/Nm3, dry, 3% O2, 0 oC)
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 1/29/2008 1230-1436 11.4 1649 1230-1418 5.7 26

2 1/30/2008 0813-1039 10.0 1671 0821-1008 5.7 27

3 1/30/2008 1202-1442 9.9 1608 1201-1212 5.7 27

4 1/30/2008 1600-1831 10.2 1535 1600-1610 6.3 31

5 1/31/2008 0803-1027 N/A 1408 0802-0945 6.0 19

Run Date Time Time 

SO3 SO2 SO3 SO2

6 1/31/2008 1328-1525 N/A 42 1329-1518 6.0 21

7 2/1/2008 1415-1630 3.5 14 1415-1628 5.8 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 Prelim 1/22/2008 11.14 2,651,871 7.5 12.2 121.9 29.50

Particulate Testing, Stack Outlet 1 1/29/2008 12.06 2,578,549 8.2 11.4 123.6 29.51

Particulate Testing, Stack Outlet 2 1/30/2008 9.29 2,677,567 7.7 11.9 119.4 29.55

Particulate Testing, Stack Outlet 3 1/30/2008 11.94 2,606,577 7.8 12.0 120.7 29.54

Particulate Testing, Stack Outlet 4 1/30/2008 9.34 2,717,043 8.2 11.6 120.0 29.51

Particulate Testing, Stack Outlet 5 1/31/2008 11.89 2,596,882 7.2 11.8 120.6 29.55

Particulate Testing, Stack Outlet 6 1/31/2008 12.31 2,679,632 7.7 11.3 121.8 29.54

Particulate Testing, Scrubber Inlet 2 1/30/2008 6.03 3,147,006 7.4 12.2 290.5 30.58

Particulate Testing, Scrubber Inlet 3 1/30/2008 6.07 3,028,088 7.7 11.9 295.3 30.52

Particulate Testing, Scrubber Inlet 4 1/30/2008 5.99 2,925,318 7.9 11.8 295.4 30.56

Particulate Testing, Scrubber Inlet 5 1/31/2008 6.16 2,811,617 6.7 13.8 297.8 30.74

Particulate Testing, Scrubber Inlet 6 1/31/2008 6.28 2,804,351 7.5 11.9 304.5 30.75

Ontario Hydro - Mercury, Scrubber Outlet Prelim 1/24/2008 12.25 2,461,706 7.5 12.2 121.3 30.00

Ontario Hydro - Mercury, Scrubber Outlet 1 1/27/2008 13.36 3,098,765 9.0 12.0 121.3 30.03

Ontario Hydro - Mercury, Scrubber Outlet 2 1/27/2008 13.35 3,067,753 9.0 12.0 123.8 30.04

Ontario Hydro - Mercury, Scrubber Outlet 3 1/28/2008 14.00 3,082,443 8.0 12.0 122.0 29.88

Ontario Hydro - Mercury, Scrubber Outlet 4 1/28/2008 14.68 3,087,664 8.0 12.0 121.6 29.88

Ontario Hydro - Mercury, Scrubber Outlet 5 1/28/2008 11.90 3,092,318 8.0 12.0 121.8 29.88

Ontario Hydro - Mercury, Scrubber Outlet 6 1/28/2008 13.88 3,081,469 8.0 12.0 122.1 29.88

Ontario Hydro - Mercury, Scrubber Inlet Prelim 1/24/2008 5.19 2,402,782 7.3 12.2 283.4 30.72

Ontario Hydro - Mercury, Scrubber Inlet 1 1/27/2008 6.47 3,460,515 9.0 14.0 291.0 30.74

Ontario Hydro - Mercury, Scrubber Inlet 2 1/27/2008 7.39 3,746,703 9.0 14.0 297.3 30.78

Ontario Hydro - Mercury, Scrubber Inlet 3 1/28/2008 8.66 3,713,709 8.0 13.0 281.8 30.45

Ontario Hydro - Mercury, Scrubber Inlet 4 1/28/2008 9.27 3,708,255 8.0 13.0 292.2 30.46

Ontario Hydro - Mercury, Scrubber Inlet 5 1/28/2008 7.92 3,715,307 8.0 13.0 296.7 30.53

Ontario Hydro - Mercury, Scrubber Inlet 6 1/28/2008 11.76 3,481,080 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