### Process Information

1Name of legal owner of facility:

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

Gulf Power Company 3Address of _

__ legal owner or ____ operator: One Energy Place Pensacola, FL 32520 - 0100 4aPlant Name (as reported on U.S. DOE/EIA Form-860 (2007), "Annual Electric Generator Report", schedule 2, line 1, page 37, question 1) OR Plant Name (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report", schedule 2, page 1, question 1):

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

643 5Complete street address of facility (physical location):

4300 County Road 2300 Southport, FL 32409 6Provide mailing address if different:

One Energy Place Pensacola, FL 32520 - 0350 7Name and title of contact(s) able to answer technical questions about the completed survey:

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

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

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

_X__ No____ Don't know

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

__X

_ coal

__X__ oil (including pet coke)

_ __ natural gas

_X_ other (specify in question 14 below)

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

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

__X

_ coal

__X__ oil (including pet coke)

_ __ natural gas

_X_ other (specify in question 14 below)

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

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

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

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



### _X__ distillate (% _96.8_)

_X__ other (specifyon spec used oil_) (% _3.2_) ____ residual or bunker C (% _____)

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

plastics, treated wood, rubber belting or gaskets, whole tires, tire-derived fuel, boiler cleaning solutions, animal wastes, etc.) is either utilized or permitted to be used, please indicate below what materials are combusted in the boiler and in what quantities (specify whether this quantity is on a weight percentage or heat [Btu] basis). Also indicate (yes/no) whether you are permitted5

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

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

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

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").
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").



### Other Material On Specification Used Oil which meets 40 CFR 279 and less than 50 ppm PCB for energy recovery purposes.

On Site Generated Oil Contaminated Soil which meets 40 CFR 279 and less than 50 PCB for energy recovery purposes.

Boiler cleaning wastes that are not hazardous as defined in 40 CFR Part 261, Subpart B. 89,872 gallons burned in 2009 

### Quantity/year 7,365 gallons burned in 2009

No Oil Contaminated Soil was burned in 2009. 

### Permitted to burn Yes; Lansing Smith 1-2 are permitted to burn at each unit's permitted heat input for oil but not to exceed 50,000 gallons/yr per unit
Yes; Lansing Smith 1-2 are permitted to burn at each unit's permitted heat input for oil but not to exceed 50,000 gallons/yr per unit

Yes; Lansing Smith 1-2 are permitted to burn non hazardous boiler cleaning wastes not to exceed 50 gallons per minute. 

### Actually burn Yes

No

Yes

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

located at this facility.Boiler ID6Original design fuel (i.e.,coal rank or type of oil)rDesign heat input,(MMBtu/hr)7, qPresent maximum heatinput, (MMBtu/hr)8,pMWe Gross capacitysummeroMWe Net CapacitysummernOriginal design grossefficiency (%, HHV)mPresent operating grossefficiency (%, HHV)lDesign steam pressure(psig)kOperating steam pressure(psig)jDesign steam temperature(oF)IOperating steamtemperature (oF)hDesign steam reheattemperature (oF)9, gOperating steam reheattemperature (oF)10, fFuel11, eHours/year operated12, dAverage annual capacityfactor for the past 3 yearscApplicable NSPSbEstimated year ofretirement13, a



### 1 bituminous CBI CBI 172 162 89.33 85.96 1800 1786 1000 994 1000 998 bituminus coal,No. 2 fuel oil, onspec used oil, boiler cleaning waste. CBI CBI none N/A

2 bituminous CBI CBI 205 195 89.1 87.61 1800 1788 1000 1000 1000 996 bituminus coal,No. 2 fuel oil, onspec used oil, boiler cleaning waste. CBI CBI none N/A

Notes "N/A" means not available.

a

### Gulf Power has not committed to actual retirement dates for Plant Lansing Smith. Gulf 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 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. b

### Where no NSPS is identified, the unit is not currently subject to any NSPS.

c

### CBI d

### CBI

e

### Indicates the fuels burned in the previous calendar year (January to December 2009). . f 

### Represents the average reheat steam temperature when the unit operated at gross normal full load over a three year period (January 2007 to December 2009).
g

### Based on the thermal design of the unit as represented on the turbine heat balance sheet. h

### Represents the average steam temperature when the unit operated at gross normal full load over a three year period (January 2007 to December 2009).
i

### Based on the thermal design of the unit as represented on the turbine heat balance sheet. j

### Represents the average throttle pressure when the unit operated at gross normal full load over a three year period (January 2007 to December 2009). k

### Based on the thermal design of the unit as represented on the turbine heat balance sheet. l

### 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.

m

### Taken directly from the original contract boiler data sheet.

n

### Identifies the net normal full load as of May 2009; taken directly from the 2009 installed and authorized document. Gulf Power does not change units capacities from season to season.

o

### Identifies the gross normal full load as of May 2009. Gulf Power does not change unit capacities season from season.
p

### CBI
q

### CBI

r

### 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.

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.

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

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

Boiler ID14 

## Type15 

## NOx control16 

## SO2 control17 

## PM control18 

## Other control19


### 1 tangential - fired 1) low NOx burner tips (1999) 2) SNCR (6/23/2009) N/A 3) hot side ESP (rebuilt in 05/2007) 4) Cold side ESP (01/1977) N/A

2 tangential - fired 1) low NOx burners /OFA (1991) 2) SNCR (6/24/2009) N/A 3) hot side ESP (rebuilt in 04/2005) 4) Cold side ESP (01/1976) N/A

Note: "N/A" means not applicable.

14

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
15

### Examples: tangential-fired; cyclone; wall-fired; circulating fluidized bed (CFB)
16

### Examples: low-NOx burners; selective catalytic reduction (SCR); selective non-catalytic reduction (SNCR); over-fire air (OFA). Include specific date that control went online or planned operational date for new installation. If this boiler's control configuration utilizes a SCR, please include the type of material from which the catalyst is manufactured and the type of reductant used in with the SCR (e.g., anhydrous ammonia, urea, other). Also, please note if the catalyst is specifically designed to reduce SO3 formation?
17

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

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

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

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

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

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

Name Telephone Address 1 N/A N/A N/A N/A 2 N/A N/A N/A N/A

Note: "N/A" means not applicable.

20

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

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

## Company (vendor) contact information Boiler ID21 

## Company (vendor) name

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

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

Boiler ID22 

## Demonstration

activity actual startup date Demonstration

activity projected start-up date Demonstration

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

sorbent and type; chemical additive23

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

1 N/A N/A N/A N/A N/A N/A 2 N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

22

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

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

## 19For each boiler noted in Part I, question 15, provide the company (prime vendor) name and company contact information for each

HAP (e.g., mercury, hydrogen chloride, etc.) control technology that you have either contracted for, are installing, or have installed for the purpose of provide a non-demonstration, full-scale operating system.

Name Telephone Address 1 N/A N/A N/A N/A 2 N/A N/A N/A N/A

Note: "N/A" means not applicable.

24

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

## Company (vendor) contact information Boiler ID24 

## Company (vendor) name

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

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

Boiler ID25

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

sorbent and type; chemical additive)26 

### Guaranteed HAP

emission reduction (%) or emission rateSorbent or additive

feed rate on which guarantee is based Coal rank(s) upon

which guarantee is based
1 N/A N/A N/A N/A N/A N/A 2 N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

25

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

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

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

PM28 

## PM10(29) 

## PM2.5(30) 

## SO2 HCl and/or HF HCN Metal

HAP31 

## Hg CO Other organics (specify) Other

pollutant (specify) 1 Steady-State 0.10 lb/mmbtu Soot-blow 0.30 lb/mmbtu Title V permit; annual test Reference Method by 5 or 17 N/A N/A 2.1 lb/mmbtu when operated alone: or 4.5 lb/mmbtu when combined with Unit 2; 24- hrdaily average.; #2 Oil & Onspec Used Oil not to exceed 0.5% by weight; Title V Permit N/A N/A N/A N/A N/A N/A N/A

2 Steady-State 0.10 lb/mmbtu Soot-blow 0.30 lb/mmbtu Title V permit; annual test Reference Method by 5 or 17 N/A N/A 2.7 lb/mmbtu when operated alone: or 4.5 lb/mmbtu when combined with Unit 2; 24- hrdaily average.; #2 Oil & Onspec Used Oil not to exceed 0.5% by weight; Title V Permit N/A N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

27

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

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

### List the compliance test method utilized.
30

### List the compliance test method utilized.
31

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

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

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

PM33 

## PM10 

## PM2.5 

## SO2 HCl and/or HF HCN Metal HAP34 

## Hg CO Other organics (specify) Other

pollutant (specify) 1 CS-ESP: 0.06 lb/MMBtu, filterable1 

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


## 2 CS-ESP: 0.0636 lb/MMBtu, filterable2 

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

Note: "N/A" means not applicable.

1

### Cold Side ESP guarantee expired 2008
2

### Cold Side ESP guarantee expired Not Available



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

_X__ No Please elaborate.

32

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

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

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

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

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

PM36 

## PM10 

## PM2.5 

## SO2 HCl and/or HF HCN Metal

HAP37 

## Hg CO Other organics (specify) 1 Particulate emission tests for steady state and soot blow are conducted annually. Results are required to be reported to FDEP within forty five days of completion of testing. FDEP must be notified at least 14 days in advance of all emission tests. Compliance Assurance Monitoring (CAM) reports for Particulate are reported on a semi-annual basis. All records must be maintained for 5 years. N/A N/A Sulfur Dioxide emissions tests are conducted annually. Results are required to be reported to FDEP within forty five days of completion of testing. FDEP must be notified at least 14 days in advance of all emission tests. Daily compliance is determined by fuel sampling or by continuous emission monitoring systems certified under 40 CFR Part 75. Excess Emissions are required on a quarterly basis to FDEP. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A

2 Particulate emission tests for steady state and soot blow are conducted annually. Results are required to be reported to FDEP within forty five days of completion of testing. FDEP must be notified at least 14 days in advance of all emission tests. Compliance Assurance Monitoring (CAM) reports for Particulate are reported on a semi-annual basis. All records must be maintained for 5 years. N/A N/A Sulfur Dioxide emissions tests are conducted annually. Results are required to be reported to FDEP within forty five days of completion of testing. FDEP must be notified at least 14 days in advance of all emission tests. Daily compliance is determined by fuel sampling or by continuous emission monitoring systems certified under 40 CFR Part 75. Excess Emissions are required on a quarterly basis to FDEP. All records must be maintained for 5 years. N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

35

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

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

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

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

## 25For the control technologies identified in Part I, questions 17 and 19, provide the cost information requested.38



## Facility Name/Unit No.: N/A Retrofit to existing boiler? Installation on a new boiler? Total Capital Investment:

- $ Total Annual Operating and Maintenance Costs:

- $ (Include base year for operating costs [e.g., 2006]
Note: "N/A" means not applicable.



## 26Are any other means of emission control (for any pollutant) employed on any boiler noted in Part I, question 15 (e.g., low-ash coal, coal or oil with low trace constituents, etc.)? Please specify.

Plant Lansing Smith currently utilizes a blend of coals to meet the plant SIP SO2 limits.

38

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

## Fuel Analysis39



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

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

Plant Code - 643

39

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

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

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

D.B. D.B. D.B. State/Country County42 

## Coal seam43 

## % Sulf % Ash Btu/lb 3,605 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.8 8.39 13,468 3,656 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.72 8.22 13,485 3,846 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 8.21 13,566 3,564 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.61 8.21 13,517 3,804 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.63 8.32 13,509 3,595 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.74 8.08 13,581 3,850 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.78 8.43 13,509 3,456 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.66 8.18 13,518 3,799 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.68 8.01 13,595 3,454 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.71 8.08 13,593 3,746 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 8.08 13,580 3,476 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.76 8.27 13,513 3,715 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.83 8.25 13,576 3,402 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.83 8.26 13,566 3,728 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.72 8.18 13,525 3,412 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.76 8.14 13,544 3,717 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.81 8.41 13,522 3,339 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.79 8.34 13,519 3,797 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.77 8.22 13,537 3,417 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.68 7.78 13,598 3,803 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.71 7.81 13,566 3,595 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.65 7.85 13,597 3,803 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.74 7.8 13,608 3,630 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.7 7.9 13,566 3,805 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 7.8 13,589 3,624 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 7.92 13,585 3,740 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.74 8.01 13,596 3,621 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.64 8.09 13,513 3,852 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.66 8.19 13,459 3,584 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 8.36 13,474 3,765 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.72 8.32 13,468 3,479 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 7.96 13,613 3,776 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 7.86 13,637 3,877 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 8.11 13,585 3,885 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 8.07 13,565 3,873 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.68 8.44 13,447 3,731 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.67 8.22 13,498 3,608 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.7 8.6 13,481 3,595 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.71 8.9 13,391 3,661 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.93 8.55 13,458 3,643 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.72 8.58 13,454 3,667 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.62 8.63 13,456 3,566 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 8.45 13,448 3,549 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 8.84 13,402 

## 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 3,642 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.66 8.87 13,413 3,586 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.65 8.67 13,468 3,567 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.63 9.28 13,304 3,506 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.65 9.09 13,404 3,560 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.65 8.87 13,428 3,561 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.67 9.22 13,382 3,582 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.63 9.24 13,357 3,455 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.65 8.69 13,443 3,666 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.65 9.22 13,352 3,628 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.62 8.91 13,434 3,584 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 9.02 13,371 3,645 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.68 8.85 13,469 3,751 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.72 9.17 13,428 3,991 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.68 9.23 13,405 3,914 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.64 8.46 13,487 3,817 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.7 8.69 13,505 3,830 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.71 8.59 13,511 3,991 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.69 8.42 13,459 3,910 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.72 8.32 13,530 3,707 1, 2 IL SALINE HARRISBURG #5 TRAIN 1.67 8.09 13,568 32,193 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.48 6.17 13,138 25,159 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.54 6.87 13,043 25,083 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.43 5.67 13,277 3,982 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 0.86 14.42 12,489 3,949 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.2 17.07 12,123 3,847 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.27 12.08 13,025 3,948 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.36 13.7 12,657 3,922 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.27 11.77 13,056 4,012 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.24 12.85 12,838 3,975 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.33 12.87 12,898 4,034 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.29 13.67 12,667 3,715 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.34 11.99 13,044 4,077 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.3 12.73 12,880 4,049 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.26 12.35 12,920 4,122 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.29 11.06 13,212 4,126 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.24 10.99 13,161 4,175 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.34 11.6 13,149 4,119 1, 2 UT CARBON UPPER SUNNYSIDETRAIN 1.28 11.73 13,063 3,997 1, 2 CO GUNNISON D SEAM TRAIN 0.51 11.14 12,733 3,990 1, 2 CO GUNNISON D SEAM TRAIN 0.5 9.13 13,029 4,036 1, 2 CO GUNNISON D SEAM TRAIN 0.5 10.05 12,981 4,039 1, 2 CO GUNNISON D SEAM TRAIN 0.53 10.14 13,019 3,703 1, 2 CO GUNNISON D SEAM TRAIN 0.45 7.76 13,570 3,581 1, 2 CO GUNNISON D SEAM TRAIN 0.45 9.41 13,222 3,619 1, 2 CO GUNNISON D SEAM TRAIN 0.45 8.17 13,424 3,619 1, 2 CO GUNNISON D SEAM TRAIN 0.45 8.17 13,424 3,635 1, 2 CO GUNNISON D SEAM TRAIN 0.45 11.61 12,866

## 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 3,719 1, 2 N/A EMERY N/A TRAIN 1.08 10.51 12,902 4,067 1, 2 N/A EMERY N/A TRAIN 1.12 9.96 13,043 2,715 1, 2 N/A EMERY N/A TRAIN 1.36 10.35 12,940 4,088 1, 2 N/A EMERY N/A TRAIN 1.33 10.23 13,010 4,059 1, 2 N/A EMERY N/A TRAIN 1.26 10.13 13,073 3,978 1, 2 N/A EMERY N/A TRAIN 1.26 11.68 12,755 4,042 1, 2 N/A EMERY N/A TRAIN 1.24 10.37 13,021 4,062 1, 2 N/A EMERY N/A TRAIN 1.29 9.87 12,940 3,999 1, 2 N/A EMERY N/A TRAIN 1.25 10.07 13,086 4,045 1, 2 N/A EMERY N/A TRAIN 1.22 10.37 13,002 4,053 1, 2 N/A EMERY N/A TRAIN 1.21 9.8 13,032 4,063 1, 2 N/A EMERY N/A TRAIN 1.23 9.89 13,041 4,018 1, 2 N/A EMERY N/A TRAIN 1.18 9.71 13,127 4,020 1, 2 N/A EMERY N/A TRAIN 1.23 9.72 13,132 4,034 1, 2 N/A EMERY N/A TRAIN 1.2 9.05 13,202 3,962 1, 2 N/A EMERY N/A TRAIN 1.22 9.95 13,062 4,038 1, 2 N/A EMERY N/A TRAIN 1.29 9.78 13,096 4,008 1, 2 N/A EMERY N/A TRAIN 1.3 9.61 13,051 4,046 1, 2 N/A EMERY N/A TRAIN 1.18 9.15 13,105 3,972 1, 2 N/A EMERY N/A TRAIN 1.19 9.51 13,114 4,013 1, 2 N/A EMERY N/A TRAIN 1.16 9.91 13,108 3,938 1, 2 N/A EMERY N/A TRAIN 1.27 10.1 13,100 4,094 1, 2 N/A EMERY N/A TRAIN 1.26 10.26 12,980 29,510 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.52 6.3 13,064 29,729 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.63 6.06 13,107 24,914 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.43 6 13,147 23,455 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.36 5.4 13,176 25,019 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.41 5.51 13,180 22,910 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.53 5.86 13,246 29,047 1, 2 COLOMBIA N/A GRAN MADRE SHIP 0.57 6.07 13,114
Note: "N/A" means not available. 

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

40

### EPA recognizes that facilities have (sometimes) several months inventory and that the amount received is not necessarily the same as the amount fired.
41

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
42

### If known.
43

### If known.

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

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

State/Country County42 

## Coal seam43 

### 7,513 1, 2 Florida/USA N/A N/A Truck 7,521 1, 2 Florida/USA N/A N/A Truck 7,508 1, 2 Florida/USA N/A N/A Truck 7,478 1, 2 Florida/USA N/A N/A Truck 7,476 1, 2 Florida/USA N/A N/A Truck 7,464 1, 2 Florida/USA N/A N/A Truck 7,467 1, 2 Florida/USA N/A N/A Truck 7,376 1, 2 Florida/USA N/A N/A Truck 7,385 1, 2 Florida/USA N/A N/A Truck 7,406 1, 2 Florida/USA N/A N/A Truck 7,412 1, 2 Florida/USA N/A N/A Truck 7,447 1, 2 Florida/USA N/A N/A Truck 7,434 1, 2 Florida/USA N/A N/A Truck 7,416 1, 2 Florida/USA N/A N/A Truck 7,416 1, 2 Florida/USA N/A N/A Truck 7,413 1, 2 Florida/USA N/A N/A Truck 7,425 1, 2 Florida/USA N/A N/A Truck 7,418 1, 2 Florida/USA N/A N/A Truck 7,401 1, 2 Florida/USA N/A N/A Truck 7,418 1, 2 Florida/USA N/A N/A Truck 7,440 1, 2 Florida/USA N/A N/A Truck 7,489 1, 2 Florida/USA N/A N/A Truck 7,491 1, 2 Florida/USA N/A N/A Truck 7,502 1, 2 Florida/USA N/A N/A Truck 7,514 1, 2 Florida/USA N/A N/A Truck 7,520 1, 2 Florida/USA N/A N/A Truck 7,508 1, 2 Florida/USA N/A N/A Truck 7,507 1, 2 Florida/USA N/A N/A Truck 7,505 1, 2 Florida/USA N/A N/A Truck 7,543 1, 2 Florida/USA N/A N/A Truck


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

40

### EPA recognizes that facilities have (sometimes) several months inventory and that the amount received is not necessarily the same as the amount fired.
41

### Boiler ID (as reported on U.S. DOE/EIA Form EIA-860 (2007), "Annual Electric Generating Report," schedule 6, part A, line 1, page 53, [for plants equal to or greater than 10 MW but less than 100 MW] or on schedule 6, part B, line 1, page 54, [for plants greater than 100 MW]) OR Generator ID (as reported on U.S. DOE/EIA Form EIA-923 (2008), "Power Plant Operations Report," schedule 5, part A, page 8).
42

### If known.
43

### If known. FUEL OIL SHIPMENTS 

## Amount received, gallons40 

## ID # of boiler(s) firing fuel41 

## Fuel source Fuel shipment method3For 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
09-303 11,951 1.3 13.76 12,684 0.053 378 76 4.8 <1 1.3 0.9 0.05 8.9 2.0 6.2 17.5 0.9UT Carbon County Upper Sunnyside Train 09-707 79,833 0.57 6.76 13,037 0.118 37 85 5.2 1.2 6.1 0.5 0.17 6.2 2.2 2.9 15.3 5.3COLOMBIA Cesar / La Loma Gran Madre Ship 09-306 11,746 0.55 10.55 12,773 0.028 76 59 4.0 <1 0.9 0.7 0.06 5.3 2.3 6.0 13.2 1.0CO Gunnison D Train 09-801 11,240 1.84 8.42 13,467 0.173 4003 62 16.0 <1 24.6 1.2 0.10 10.3 5.6 42.5 16.0 1.0IL Saline Herron # 5 Seam Train 09-802 10,928 1.75 8.2 13,570 0.027 4047 37 19.2 1.3 23.0 1.5 0.20 11.6 6.2 57.9 16.1 1.0IL Saline Herron # 5 Seam Train 09-319 12,281 0.57 9.66 12,894 0.030 131 56 3.7 <1 1.0 0.6 0.03 5.0 2.1 5.4 21.7 0.9CO Gunnison D Train 09-320 12,193 1.14 10.21 13,040 0.017 140 ND 3.7 <1 1.4 0.4 <0.02 5.3 2.2 4.4 19.0 0.8UT Emery A,J, I Train 09-323 12,237 1.39 11.4 13,152 0.055 432 39 4.2 <1 0.8 0.6 0.09 8.5 1.8 5.2 11.9 1.2UT Carbon County Upper Sunnyside Train 09-715 79,489 0.43 5.83 13,132 0.068 40 43 4.8 1.0 2.2 0.5 0.05 4.5 1.9 1.9 16.4 5.4COLOMBIA Cesar / La Loma Gran Madre Ship 09-710 94,324 0.61 5.86 13,104 0.112 34 57 3.8 <1 4.4 0.4 0.15 5.0 1.6 2.3 14.3 5.8COLOMBIA Cesar / La Loma Gran Madre Ship 09-333 12,286 0.53 10.91 13,086 0.033 231 57 4.0 <1 1.0 0.7 0.03 5.9 2.2 5.6 13.7 0.9CO Gunnison D Train 09-803 11,375 1.7 8.26 13,516 0.153 3129 57 ND <1 <0.1 <0.1 <0.02 <0.1 ND ND ND 1.0IL Saline Herron # 5 seam Train 09-229 1,558 0.79 15.23 12,819 0.085 1845 84 17.0 1.3 5.8 3.1 <0.02 20.5 8.7 9.2 59.8 2.5WV Kanawha Eagle, Stockton, Winifrede Barge 09-221 1,600 1.03 15.41 12,817 0.130 2147 64 16.3 1.0 10.0 2.7 <0.02 21.6 9.7 9.6 57.7 3.4WV Kanawha Stockton, Eagle Barge 09-335 12,195 1.26 9.81 13,377 0.046 388 57 4.0 <1 0.9 0.8 0.05 7.8 1.8 4.8 12.5 1.1UT Carbon County Upper Sunnyside Train 09-336 12,184 1.25 9.65 13,135 0.174 141 31 2.9 <1 1.5 0.3 <0.02 4.5 1.7 4.2 17.9 0.9UT Emery "A","J", "I" Train 09-724 80,014 0.4 5.79 13,181 0.047 33 37 4.8 <1 2.1 0.4 0.11 5.4 2.2 2.6 18.5 5.2COLOMBIA Cesar / La Loma Gran Madre Ship 09-338 12,197 0.46 9.97 13,087 0.032 266 56 4.1 <1 1.1 0.6 0.05 6.4 2.9 6.5 16.9 0.9CO Gunnison "D" Train 09-339 12,192 1.18 10.07 13,013 0.174 161 26 3.3 <1 2.1 0.2 ND 5.7 2.2 4.6 19.3 0.9UT Emery "A","J", "I" Train 09-804 12,321 1.71 8.72 13,475 0.142 3347 57 15.6 1.0 21.9 1.3 0.16 11.1 5.7 49.9 20.8 1.0IL Saline Herron # 5 seam Train 09-350 12,181 1.36 11.53 13,153 0.051 472 33 3.9 <1 1.2 0.7 0.09 9.3 2.1 5.6 12.1 1.2UT Carbon County Upper Sunnyside Train 09-528 1,549 0.84 13.88 13,072 0.057 1795 85 14.0 <1 8.8 3.4 ND 19.3 8.4 8.6 58.2 2.7WV Kanawha Eagle, Stockton Barge

Note: "ND" means non-detect. Multiple seams may be listed to account for the flexibility written into the purchase orders. Actual shipments may not have originated from each seam listed. Note: Gulf Power collects this information on select coal shipments, but does not have this information available on a shipment by shipment basis. The information Gulf Power provides in this response cannot be linked to the information in Part II, Question 2 because the information comes from two separate databases. Thus, the information provided in this response represents only a very small portion of our actual shipments.

44To the extent that a vendor provides these data or that a facility is required by State or local agency to analyze its fuel for HAP constituents (e.g., Cl, F), and any metallic HAP (e.g., Hg, Pb, As, Se, etc.), EPA wishes the responding facility to provide those fuel analyses results. Otherwise, this 12-month fuel analysis requirement can be bypassed by the respondent.
45Metal HAP includes compounds of antimony, arsenic, beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, phosphorus, and selenium.

Total amount of fuel represented by sample, tons Sample ID # State/Country Nickel, ppm Other trace metal HAP, ppm45 Total Sulfur, % Fluorine, ppm Fuel Shipment Method Coal Seam Ash Content, % Heating Value,

Btu/lb Mercury,

ppm Chlorine,

ppm County

### 4Were the data provided in Part II, question 3 above, acquired pursuant to:

____ permit requirements ____ contractual obligations ____ standard operational procedures

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

5Analyses provided in Part II, question 3 above, supplied by ____ Fuel supplier (name and address)

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

Total MoistureVolatiles Ash Fixed Carbon CarbonHydrogenNitrogen Total Sulfur Oxygen Barium CopperMagnesiumSodiumVanadium Zinc Al2O3 Fe2O3 CaO MgO MnO2 P2O5 K2O SiO2 Na2O SO3 TiO2
09-303 6.64 35.56 13.76 50.68 73.51 4.72 1.5 1.3 5.21 100 5.0 0.161 0.033 10.3 10.4 13.34 4.28 5.76 1.940.02018 0.5 0.82 65.01 0.33 7.56 0.62 09-707 12.18 38.71 6.76 54.53 76.46 4.64 1.46 0.57 10.11 250 6.3 0.060 0.122 18.9 9.9 20.53 6.94 3.21 1.470.03578 0.28 1.51 56.92 2.42 5.39 0.8 09-306 8.8 38.09 10.55 51.36 74.14 4.84 1.54 0.55 8.38 240 8.5 0.081 0.050 15.5 11.0 27.37 5.02 3.32 1.270.01981 0.62 1.35 55.88 0.63 3.3 0.86 09-801 11.23 34.57 8.42 57.01 76.35 4.98 1.78 1.84 6.63 30 7.2 0.046 0.066 18.2 17.8 19.58 19.25 1.9 0.91 0.0301 0.48 2.38 51.3 1.05 1.81 1.22 09-802 11.89 34.32 8.2 57.48 76.87 4.98 1.75 1.75 6.45 40 8.6 0.046 0.065 20.8 33.2 19.88 17.13 2.07 0.930.03108 0.55 2.48 52.67 1.06 1.81 1.25 09-319 8.81 37.86 9.66 52.48 72.92 5.03 1.64 0.57 10.18 250 8.2 0.075 0.051 14.2 14.4 25.88 6.26 4.06 1.3 0.0355 0.68 1.37 54.6 0.72 3.76 0.9 09-320 6.97 38.51 10.21 51.28 74.04 5.02 1.26 1.14 8.33 120 7.0 0.151 0.121 9.5 3.7 16.51 6.43 10.19 2.460.02948 0.17 0.36 47.95 1.6 13.04 0.95 09-323 5.84 36.06 11.4 52.54 73.68 4.99 1.56 1.39 6.98 170 4.7 0.078 0.035 10.2 9.7 16.05 4.29 4.73 1.130.01657 0.43 0.94 66.25 0.42 4.73 0.83 09-715 11.77 39.36 5.83 54.81 75.74 5.05 1.51 0.43 11.44 230 4.9 0.055 0.117 13.1 6.8 18.89 7.21 3.29 1.580.04447 0.17 1.29 57.59 2.7 5.77 0.92 09-710 12.44 39.1 5.86 55.04 76.29 4.93 1.51 0.61 10.8 230 5.6 0.054 0.107 16.2 6.6 20.85 8.66 3.72 1.540.03871 0.38 1.38 54.11 2.47 5.31 0.99 09-333 7.58 36.91 10.91 52.18 73.35 5.03 1.34 0.53 8.84 240 9.0 0.079 0.074 15.5 10.6 23.62 5.05 3.01 1.20.01991 0.52 1.83 59.66 0.92 2.96 0.89 09-803 10.29 34.27 8.26 57.47 76.93 4.94 1.68 1.7 6.49 30 0.0 0.049 0.060 ND ND 20.47 15.45 1.9 0.98 0.0311 0.57 2.55 53.58 0.98 2.13 1.25 09-320 6.97 38.51 10.21 51.28 74.04 5.02 1.26 1.14 8.33 120 7.0 0.151 0.121 9.5 3.7 16.51 6.43 10.19 2.460.02948 0.17 0.36 47.95 1.6 13.04 0.95 09-229 8.43 30.75 15.23 54.02 72.98 4.66 1.26 0.79 5.08 110 17.7 0.101 0.050 34.6 21.5 26.09 6.18 1.06 1.10.06211 0.14 3.67 58.63 0.45 1.05 1.47 09-221 6.75 30.44 15.41 54.15 72.9 4.66 1.37 1.03 4.63 80 20.4 0.088 0.045 33.9 20.7 25.01 7.14 1.21 0.950.05926 0.09 2.8 59.26 0.39 1.54 1.47 09-335 5.25 36.46 9.81 53.73 75.43 5.05 1.49 1.26 6.96 140 4.6 0.064 0.032 9.0 8.7 15.19 4.69 5.03 1.070.02019 0.75 0.79 65.79 0.45 5.19 0.81 09-336 6.97 38.51 9.65 51.84 74.2 5.04 1.12 1.25 8.74 130 6.5 0.129 0.101 8.2 3.5 14.59 7 10.56 2.230.02931 0.14 0.38 49.99 1.42 12.94 0.9 09-724 12.5 39.34 5.79 54.87 75.63 5.22 1.48 0.4 11.48 240 6.2 0.060 0.107 16.1 8.5 20.16 7.34 3.96 1.710.05069 0.19 1.49 55.4 2.5 5.7 0.97 09-338 7.8 37.33 9.97 52.7 73.85 5.15 1.71 0.46 8.86 220 9.9 0.078 0.071 17.6 13.6 24.33 5.36 4.07 1.3 0.0269 0.54 1.55 56.81 0.96 3.78 0.93 09-339 6.94 38.03 10.07 51.9 73.71 5.04 1.36 1.18 8.64 130 6.7 0.125 0.111 9.6 5.5 14.64 7.67 9.81 2.060.03026 0.12 0.43 50.38 1.48 12.16 0.94 09-804 10.35 34.75 8.72 56.53 75.97 4.97 1.85 1.71 6.78 20 8.0 0.052 0.065 18.3 29.4 19.18 14.88 2.33 0.990.03776 0.56 2.39 54.67 1.01 2.64 1.21 09-350 5.18 35.68 11.53 52.79 73.64 5.11 1.65 1.36 6.71 140 4.4 0.082 0.033 10.3 11.0 15.33 4.58 4.77 1.170.01657 0.54 1.08 66.26 0.39 4.85 0.81 09-528 8.19 31.76 13.88 54.35 73.22 4.55 1.31 0.84 6.2 91 16.8 0.084 0.045 30.5 18.1 22.6 6.04 1.77 0.992 ND ND 2.65 56.4 0.498 1.15 1.53

Note: "ND" means non-detect. 

### Ash Mineralogy, % by wt Sample ID # Proximate Analyses, % by wt Ultimate Analyses, % by wt Other Trace Metals, ppm

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

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

Report 1 

## Unit 1 5/25/2005 Unit 1 SO2 Test Report 2 

## 5/25/2005 Particulate Soot Blow Test Report 3 

## 5/25/2005 Particulate Steady State Test Report 4 

## Unit 2 5/25/2005 Unit 2 SO2 Test Report 5 

## 5/31/2005 Particulate Steady State Test Report 6 

## 6/1/2005 Particulate Soot Blow Test Report 7 

## 6/1/2005 Particulate Inlet Test Test Report 8 

## 6/2/2005 Particulate Outlet Side A Test Report 9 

## 6/2/2005 Particulate Outlet Side B Test Report 10 

## 6/2/2005 Particulate Outlet Combined A/B Test Report 11 

## Unit 1 5/10/2006 Unit 1 SO2 Test Report 12 

## 5/10/2006 Particulate Steady State Test Report 13 

## 5/11/2006 Particulate Soot Blow Test Report 14 

## Unit 2 5/22/2006 Unit 2 SO2 Test Report 15 

## 5/22/2006 Particulate Soot Blow Test Report 16 

## 5/22/2006 Particulate Steady State Test Report 17 

## Unit 1 6/11/2007 Unit 1 SO2 Test Report 18 

## 6/11/2007 Particulate Soot Blow Test Report 19 

## 6/12/2007 Particulate Steady State Test Report 20 

## Unit 2 5/8/2007 Unit 2 SO2 Test Report 21 

## 5/8/2007 Particulate Soot Blow Test Report 22 

## 5/8/2007 Particulate Steady State Test Report 23 

## Unit 1 2/6/2008 Boiler Test - SNCR Baseline Report 24 

## 5/5/2008 Unit 1 SO2 Test Report 25 

## 5/5/2008 Particulate Soot Blow Test Report 26 

## 5/6/2008 Particulate Steady State Test Report 27 

## Unit 2 2/18/2008 Boiler Test - SNCR Baseline Report 28 

## 3/17/2008 Unit 2 SO2 Test Report 29 

## 3/17/2008 Particulate Soot Blow Test Report 30 

## 3/18/2008 Particulate Steady State Test Report 31 

## Unit 1 8/18/2009 Unit 1 SO2 Test Report 32 

## 8/18/2009 Particulate Soot Blow Test Report 33 

## 8/19/2009 Particulate Steady State Test Report 34 

## Unit 2 5/19/2009 Unit 2 SO2 Test Report 35 

## 5/19/2009 Particulate Soot Blow Test Report 36 

## 5/20/2009 Particulate Steady State Test

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

air pollutants) sampled for:

Report 1 

## Date: 5/25/2005 Type: Duct Constituents: SO2 Report 2 

## Date: 5/25/2005 Type: Duct Constituents: PM Report 3 

## Date: 5/25/2005 Type: Duct Constituents: PM Report 4 

## Date: 5/25/2005 Type: Duct Constituents: SO2 Report 5 

## Date: 5/31/2005 Type: Duct Constituents: PM Report 6 

## Date: 6/1/2005 Type: Duct Constituents: PM Report 7 

## Date: 6/1/2005 Type: Duct Constituents: PM Report 8 

## Date: 6/2/2005 Type: Duct Constituents: PM Report 9 

## Date: 6/2/2005 Type: Duct Constituents: PM Report 10 

## Date: 6/2/2005 Type: Duct Constituents: PM Report 11 

## Date: 5/10/2006 Type: Duct Constituents: SO2 Report 12 

## Date: 5/10/2006 Type: Duct Constituents: PM Report 13 

## Date: 5/11/2006 Type: Duct Constituents: PM Report 14 

## Date: 5/22/2006 Type: Duct Constituents: SO2 Report 15 

## Date: 5/22/2006 Type: Duct Constituents: PM Report 16 

## Date: 5/22/2006 Type: Duct Constituents: PM Report 17 

## Date: 6/11/2007 Type: Duct Constituents: SO2 Report 18 

## Date: 6/11/2007 Type: Duct Constituents: PM Report 19 

## Date: 6/12/2007 Type: Duct Constituents: PM Report 20 

## Date: 5/8/2007 Type: Duct Constituents: SO2 Report 21 

## Date: 5/8/2007 Type: Duct Constituents: PM Report 22 

## Date: 5/8/2007 Type: Duct Constituents: PM Report 23 

## Date: 2/6/2008 Type: Duct Constituents:O2,CO,CO2 Report 24 

## Date: 5/5/2008 Type: Duct Constituents: SO2 Report 25 

## Date: 5/5/2008 Type: Duct Constituents: PM Report 26 

## Date: 5/6/2008 Type: Duct Constituents: PM Report 27 

## Date: 2/18/2008 Type: Duct Constituents:O2,CO,CO2 Report 28 

## Date: 3/17/2008 Type: Duct Constituents: SO2 Report 29 

## Date: 3/17/2008 Type: Duct Constituents: PM Report 30 

## Date: 3/18/2008 Type: Duct Constituents: PM Report 31 

## Date: 8/18/2009 Type: Duct Constituents: SO2 Report 32 

## Date: 8/18/2009 Type: Duct Constituents: PM Report 33 

## Date: 8/19/2009 Type: Duct Constituents: PM Report 34 

## Date: 5/19/2009 Type: Duct Constituents: SO2 Report 35 

## Date: 5/19/2009 Type: Duct Constituents: PM Report 36 

## Date: 5/20/2009 Type: Duct Constituents: PM

## 8cDo any of these test reports reflect testing at a location upstream of 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 7 Attachment 7 Smith 2 6/1/2005Particulate Inlet Test

8dWere any of these test reports conducted when use of other material(s) or non-fossil fuels were fired in the boiler? Yes ____ No _X_

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

8eDo any of these test reports reflect testing during periods of startup, shutdown, and malfunction? Yes ____ No _X_

_ If yes, please note which reports.

8fDid the unit's control configuration differ from that shown in Part I, question 16, at the time of these test results? Yes __X_ No ____ If yes, please list the unit's complete control configuration at time of testing in a similar format to Part I, question 16.
All tests presented in Test Reports 1-36 were conducted with the same control configuration as outlined in the table 8f-1 below: Table 8f-1 Boiler ID14 

## Type15 

## NOx control16

## SO2 control17 

## PM control18

## Other control19 

### 1 tangential - fired1) low NOx burner tips (1999) N/A 3) hot side ESP

(rebuilt in 05/2007) 4) Cold side ESP (01/1977) N/A

2 tangential - fired1) low NOx burners/OFA (1991) N/A 3) hot side ESP

(rebuilt in 04/2005) 4) Cold side ESP (01/1976) N/A

Note: "N/A" means not applicable.


## No tests were conducted after 6/23/09 (with SNCR control)s as outlined in the table 8f-2 below: Table 8f-2 Boiler ID14 

## Type15 

## NOx control16

## SO2 control17 

## PM control18

## Other control19 

### 1 tangential - fired1) low NOx burner tips (1999) 2) SNCR (6/23/2009) N/A 3) hot side ESP (rebuilt in 05/2007) 4) Cold side ESP (01/1977) N/A

2 tangential - fired1) low NOx burners/OFA (1991) 2) SNCR (6/24/2009) N/A 3) hot side ESP (rebuilt in 04/2005) 4) Cold side ESP (01/1976) N/A

Note: "N/A" means not applicable.


## 8gDo any of these test reports reflect testing at a location upstream of a post combustion SO2 emission control device (e.g., FGD, SDA, Dry Scrubber)? Yes ____ No _X

__ If yes, please note which reports and, in addition to the detailed description of the location of the sampling point(s) (question 8c above), include detail about how much, if any, bypass of unscrubbed flue gas was utilized at at the time of testing (including percentage of total scrubber flue gas flow). Note by diagram where sampling ports were located in relation to the bypass ductwork.

## 9What type of deviation reporting is required for violations of permit requirements? Deviations which constitute a violation from permit conditions shall be reported immediately to FDEP. Immediately shall mean the same workday (i.e. 8:00 am to 5:00 pm), or first business day after the incident,excluding weekends and holidays. This report shall contain a description of and cause of noncompliance; and the period of noncompliance, including dates and times; weekends and holidays. This report shall contain a description of and cause of noncompliance; and the period of noncompliance, including dates and times; or if not corrected, the anticipated time the noncompliance is expected to continue, and steps being taken to reduce, eliminate, and prevent the recurrence of the noncompliance. The permittee shall be responsible for any and all damages which may result and may be subjext to enforcement action by the Department for penalties or revocation of the permit. Deviations which do not constitute a violation as allowable excess emissions are reported quarterly or semi-annual under the Excess Emissions, Semi-annual Monitoring and Annual Title V Certification Reports. 10Are deviation reports available for malfunctions or other periods of noncompliance with permit terms and conditions? Yes _X

__No ____If yes, please note which reports.

Deviations from any permit condition is reported in the Semi-annual monitoring reports submitted to FDEP.

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

_ No _

___If yes46

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

01/01/05 - 12/31/09Unit 1: Continuous Opacity Monitoring Information is available upon request 01/01/05 - 12/31/09Unit 2: Continuous Opacity Monitoring Information is available upon request
1

## Gulf Power considers CEMS data "available" only if it is maintained and subject to quality assurance/quality control

Note: Gulf Power considers CEMS data "available" only if it is maintained and subject to quality assurance/quality control

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 CEM data by submitted by the respondent. The respondent should also mark the periods of start up, shut down and malfunction events (SSM) in the data sets.

### 12For each boiler noted in Part I, question 15, provide the following information:

Test Report Date of test PM49 

### SO2 HCl/HF/HCN Metal HAP50 

### Hg51 

### CO Other organics (specify) Unit 1 Report 1 

### 5/25/2005 N/A See Attachment 1 N/A N/A N/A N/A N/A

Report 2 

### 5/25/2005 See Attachment 2 N/A N/A N/A N/A N/A N/A Report 3 

### 5/25/2005 See Attachment 3 N/A N/A N/A N/A N/A N/A Unit 2 Report 4 

### 5/25/2005 N/A See Attachment 4 N/A N/A N/A N/A N/A

Report 5 

### 5/31/2005 See Attachment 5 N/A N/A N/A N/A N/A N/A Report 6 

### 6/1/2005 See Attachment 6 N/A N/A N/A N/A N/A N/A Report 7 

### 6/1/2005 See Attachment 7 N/A N/A N/A N/A N/A N/A Report 8 

### 6/2/2005 See Attachment 8 N/A N/A N/A N/A N/A N/A Report 9 

### 6/2/2005 See Attachment 9 N/A N/A N/A N/A N/A N/A Report 10 

### 6/2/2005 See Attachment 10N/A N/A N/A N/A N/A N/A Unit 1 Report 11 

### 5/10/2006 N/A See Attachment 11N/A N/A N/A N/A N/A

Report 12 

### 5/10/2006 See Attachment 12N/A N/A N/A N/A N/A N/A Report 13 

### 5/11/2006 See Attachment 13N/A N/A N/A N/A N/A N/A Unit 2 Report 14 

### 5/22/2006 N/A See Attachment 14N/A N/A N/A N/A N/A

Report 15 

### 5/22/2006 See Attachment 15N/A N/A N/A N/A N/A N/A Report 16 

### 5/22/2006 See Attachment 16N/A N/A N/A N/A N/A N/A Unit 1 Report 17 

### 6/11/2007 N/A See Attachment 17N/A N/A N/A N/A N/A

Report 18 

### 6/11/2007 See Attachment 18N/A N/A N/A N/A N/A N/A Report 19 

### 6/12/2007 See Attachment 19N/A N/A N/A N/A N/A N/A Unit 2 Report 20 

### 5/8/2007 N/A See Attachment 20N/A N/A N/A N/A N/A

Report 21 

### 5/8/2007 See Attachment 21N/A N/A N/A N/A N/A N/A Report 22 

### 5/8/2007 See Attachment 22N/A N/A N/A N/A N/A N/A Unit 1 Report 23 

### 2/6/2008 N/A N/A N/A N/A N/A See Attachment 23N/A

Report 24 

### 5/5/2008 N/A See Attachment 24N/A N/A N/A N/A N/A Report 25 

### 5/5/2008 See Attachment 25N/A N/A N/A N/A N/A N/A Report 26 

### 5/6/2008 See Attachment 26N/A N/A N/A N/A N/A N/A Unit 2 Report 27 

### 2/18/2008 N/A N/A N/A N/A N/A See Attachment 27N/A

Report 28 

### 3/17/2008 N/A N/A N/A N/A N/A N/A N/A Report 29 

### 3/17/2008 See Attachment 29N/A N/A N/A N/A N/A N/A Report 30 

### 3/18/2008 See Attachment 30N/A N/A N/A N/A N/A N/A Unit 1 Report 31 

### 8/18/2009 N/A See Attachment 31N/A N/A N/A N/A N/A

Report 32 

### 8/18/2009 See Attachment 32N/A N/A N/A N/A N/A N/A Report 33 

### 8/19/2009 See Attachment 33N/A N/A N/A N/A N/A N/A Unit 2 Report 34 

### 5/19/2009 N/A See Attachment 34N/A N/A N/A N/A N/A

Report 35 

### 5/19/2009 See Attachment 35N/A N/A N/A N/A N/A N/A Report 36 

### 5/20/2009 See Attachment 36N/A N/A N/A N/A N/A N/A
Note: "N/A" means not applicable.

47Provide emission test data for all tests conducted since January 1, 2005. Please indicate test data acquired both before and after any control device. Use additional pages as necessary. EPA may, at some future date, request a copy of one or more emission test reports. Data generated to fulfill both Federal and State requirements must be provided. Note that data generated pursuant to CAA Title V must be maintained and available for 5 years. Also include averaging times and measurement units for all pollutants.
48For each emissions test run the respondent should provide the following process information: Unit Load (MW), Net generation during run (MWh net), Flue gas moisture content (%), Flue gas flow rate (dscfm or Nm3/hr), Flue gas oxygen content (%, dry), Flue gas carbon dioxide content (%, dry), Flue gas temperature at sampling point (oF), Flue gas pressure at sampling point (atm), Standard temperature (oF), Standard pressure (atm).
49If emission testing recorded the emissions of filterable and condensable PM, separately, please include those separate emission results. Also, please include separate emission results for total PM, PM10, and PM2.5. 50Metal HAP include compounds of antimony, arsenic, beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, phosphorus, and selenium; indicate emission level for all metal HAP for which an emission test has been conducted.
51Please provide separate results for total Hg, elemental Hg, oxidized Hg, and particulate Hg, as available. If the emissions testing recorded the amount of unburned carbon in fly ash (as reflected by the "Loss of Ignition" [L.O.I]) at the time of any Hg testing, please include these data. 

### Boiler ID Emissions test results (indicate format of emission data)47,48

# ATTACHMENT 1 - Smith Report 1 Test Results

2005 SO2 Emissions Test (Based on RATA Results)



## Run Number Date- Start TimeDate- Stop TimeAverage Emissions (lbs/mmBTU SO2

## ) 1 5/23/05- 10:25 5/23/05- 10:46 1.44 2 5/23/05- 11:11 5/23/05- 11:32 1.361 3 5/23/05- 12:09 5/23/05- 12:29 1.446 4 5/23/05- 12:59 5/23/05- 13:20 1.289 5 5/23/05- 13:45 5/23/05- 14:06 1.283 6 5/23/05- 14:28 5/23/05- 14:49 1.302 7 5/23/05- 15:10 5/23/05- 15:31 1.202 8 5/23/05- 15:55 5/23/05- 16:16 1.345 9 5/23/05- 16:68 5/23/05- 16:59 1.536

Average: 1.356 Smith Unit 1 - 2005 Full Load ~171 MWs

### ATTACHMENT 2 - Smith Report 2 Test Results

Plant Load Indicator\Label Upper Upper Upper Lower Lower Lower 

### Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/24/20055/24/20055/24/2005 5/24/20055/24/20055/24/2005 Sampling Time -Start Military 0816 0943 1108 0816 0943 1108 Sampling Time -Stop Military 0920 1050 1214 0920 1050 1214 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.85 0.85 0.85 0.85 0.85 0.85 Barometric Pressure Inches Mercury 29.97 29.97 29.97 29.97 29.97 29.97 Meter Correction Factor dimensionless 1.011 1.011 1.011 1.046 1.046 1.046 Oxygen Concentration Mole Percent O2 6.2 6.3 6.5 6.5 6.3 6.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 12.0 12.0 12.0 12.0 Volume of Gas Metered Actual Cubic Feet 35.450 32.930 36.300 32.900 35.660 36.825 Volume of Water Collected Milliliters 66.00 56.00 57.00 62.00 61.00 62.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.238 0.241 0.241 0.241 0.240 0.237 Weight of Solids Collected Milligrams 15.6 16.5 19.6 10.8 15.3 10.5 Area of Stack Square Feet 99.9688 99.9688 99.9688 110.8975 110.8975 110.8975 Avg. Sqr. Root Velocity Pressure Inches Water 0.8016 0.7166 0.7475 0.7394 0.7795 0.8027 Average Orifice Pressure(H) Inches Water 1.6 1.3 1.3 1.4 1.6 1.6 Average Stack Temperature Degrees F 317 321 322 331 331 327 Average Meter Temperature Degrees F 84 92 92 90 92 94

3 Runs 3 Runs 

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

Volume of Gas Sampled Standard Dry 35.010 32.008 35.259 34.093 33.218 35.890 36.942 35.350 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.18 29.25 29.32 29.25 29.20 29.27 29.29 29.25
Water vapor in Stack Gas Percent 8.2 7.6 7.1 7.6 8.1 7.4 7.3 7.6
Average Stack Gas Velocity Feet per second 54.2 48.5 50.6 51.1 50.4 53.1 54.5 52.7

Stack Gas Flow Rate Actual Cubic 325,167 291,075 303,459306,567 335,381 353,301 362,629350,437 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 221,635 197,382 205,517208,178 224,807 236,599 244,277235,228 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 203,572 182,364 190,984192,307 206,652 219,073 226,393217,373 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 15,248 13,659 14,305 14,404 15,478 16,409 16,957 16,281 Per Minute Particulate Concentration Grains per Standard 0.0069 0.0079 0.0086 0.0078 0.0050 0.0066 0.0044 0.0053 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0043 0.0050 0.0054 0.0049 0.0031 0.0041 0.0027 0.0033 Cubic Foot Particulate Emission Rate Pounds per Hour 12.0 12.4 14.0 12.8 8.9 12.3 8.5 9.9

Particulate Emission Rate Pounds per Million 0.014 0.016 0.017 0.016 0.010 0.013 0.009 0.011 Btu (O2 F Factor) Combined Particulate Emission RatePounds per Million 0.0119 0.0145 0.0131 0.0132 Allowable Particulate Emission Rate Btu (O2 F Factor) 0.30 0.30 0.30 0.30 Heat Input (O2 F Factor) Million Btu per Hour 878 782 807 822 874 939 957 923

Isokinetic Rate Percent 92.7 92.3 97.1 94.0 93.8 96.4 98.4 96.2 

## Calculations TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS GULF POWER COMPANY PLANT SMITH UNIT 1 SOOT BLOWING OPERATIONS

### ATTACHMENT 3 - Smith Report 3 Test Results

Plant Load Indicator\Label Upper Upper Upper Lower Lower Lower 

### Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/25/20055/25/20055/25/2005 5/25/20055/25/20055/25/2005 Sampling Time -Start Military 0637 0806 0945 0637 0806 0945 Sampling Time -Stop Military 0745 0913 1049 0745 0913 1051 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.80 0.80 0.80 0.70 0.80 0.80 Barometric Pressure Inches Mercury 30.07 30.07 30.07 30.07 30.07 30.07 Meter Correction Factor dimensionless 1.011 1.011 1.011 1.046 1.046 1.046 Oxygen Concentration Mole Percent O2 6.5 6.8 6.7 6.5 6.5 6.7 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 12.0 12.0 12.0 12.0 Volume of Gas Metered Actual Cubic Feet 32.055 35.615 35.415 33.930 37.590 37.455 Volume of Water Collected Milliliters 56.00 58.00 64.00 53.00 64.00 62.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.241 0.238 0.240 0.238 0.241 0.236 Weight of Solids Collected Milligrams 14.8 17.1 19.6 12.0 13.7 13.2 Area of Stack Square Feet 99.9688 99.9688 99.9688 110.8975 110.8975 110.8975 Avg. Sqr. Root Velocity Pressure Inches Water 0.6983 0.7271 0.6994 0.7158 0.7597 0.7809 Average Orifice Pressure(H) Inches Water 1.2 1.3 1.2 1.3 1.6 1.5 Average Stack Temperature Degrees F 311 312 315 321 320 320 Average Meter Temperature Degrees F 79 86 88 82 88 93

3 Runs 3 Runs 

### RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 31.976 35.082 34.768 33.942 34.840 38.234 37.723 36.933 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.25 29.31 29.22 29.26 29.37 29.29 29.31 29.32
Water vapor in Stack Gas Percent 7.6 7.2 8.0 7.6 6.7 7.3 7.2 7.1
Average Stack Gas Velocity Feet per second 46.9 48.8 47.1 47.6 48.3 51.3 52.7 50.7

Stack Gas Flow Rate Actual Cubic 281,238 292,747 282,634285,540 321,213 341,220 350,593337,675 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 193,955 201,578 193,819196,451 218,688 232,545 238,933230,055 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 179,184 187,024 178,365181,524 204,076 215,561 221,776213,804 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 13,421 14,008 13,360 13,596 15,285 16,145 16,611 16,014 Per Minute Particulate Concentration Grains per Standard 0.0071 0.0075 0.0087 0.0078 0.0053 0.0055 0.0054 0.0054 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0045 0.0048 0.0055 0.0049 0.0034 0.0035 0.0034 0.0034 Cubic Foot Particulate Emission Rate Pounds per Hour 10.9 12.0 13.3 12.1 9.3 10.2 10.2 9.9

Particulate Emission Rate Pounds per Million 0.0145 0.0155 0.0179 0.0160 0.0108 0.0112 0.0111 0.0110 Btu (O2 F Factor) Combined Particulate Emission RatePounds per Million 0.0126 0.0134 0.0145 0.0135 Allowable Particulate Emission Rate Btu (O2 F Factor) 0.10 0.10 0.10 0.10 Heat Input (O2 F Factor) Million Btu per Hour 757 774 743 758 863 911 924 899

Isokinetic Rate Percent 93.8 101.1 103.4 99.4 102.1 103.5 103.5 103.0 

## Calculations TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS GULF POWER COMPANY PLANT SMITH UNIT 1 STEADY STATE OPERATIONS

# ATTACHMENT 4 - Smith Report 4 Test Results

2005 SO2 Emissions Test (Based on RATA Results)

Run Number Date- Start Time Date- Start Time Average Emissions (lbs/mmBTU SO2

## ) 1 5/25/05- 16:54 5/25/05- 17:15 1.61 2 5/25/05- 17:40 5/25/05- 18:01 1.646 3 5/25/05- 18:26 5/25/05- 18:47 1.632 4 5/25/05- 19:12 5/25/05- 19:33 1.633 5 5/25/05- 19:58 5/25/05- 20:19 1.657 6 5/25/05- 20:44 5/25/05- 21:05 1.595 7 5/26/05- 10:05 5/26/05- 10:26 1.645 8 5/26/05- 10:46 5/26/05- 11:07 1.643 9 5/26/05- 11:32 5/26/05- 11:53 1.619

Average: 1.631 Smith Unit 2 - 2005 Full Load ~ 203 MWs

### ATTACHMENT 5 - Smith Report 5 Test Results

Upper Upper Upper Lower Lower Lower

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/31/20055/31/20055/31/2005 5/31/20055/31/20055/31/2005 Sampling Time -Start Military 1252 1418 1540 1252 1418 1540 Sampling Time -Stop Military 1400 1523 1648 1400 1523 1648 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 1.95 1.95 1.95 2.00 2.00 2.00 Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10 30.10 30.10 Meter Correction Factor dimensionless 1.0110 1.0110 1.0110 1.0460 1.0460 1.0460 Oxygen Concentration Mole Percent O2 8.0 8.0 8.0 8.0 8.0 7.5 Carbon Dioxide Concentration Mole Percent CO2 11.5 11.5 11.0 11.0 11.0 11.0 Volume of Gas Metered Actual Cubic Feet 36.111 36.678 36.462 32.370 36.665 38.195 Volume of Water Collected Milliliters 69 70 70 60 63 67 Sampling Time Minutes 60.00 60.00 60.00 60.00 60.00 60.00 Nozzle Diameter Inches 0.245 0.245 0.240 0.240 0.245 0.245 Weight of Solids Collected Milligrams 17.6 13.7 11.4 14.7 10.0 11.4 Area of Stack Square Feet 122.910 122.910 122.910 122.840 122.840 122.840 Avg. Sqr. Root VelocityPressure Inches Water 0.7620 0.7772 0.7813 0.7326 0.7441 0.7377 Average Orifice Pressure(H) Inches Water 1.329 1.4 1.4 1.369 1.5 1.6 Average Stack Temperature Degrees F 379.80 346.9 350.6 317.07 292.5 290.7 Average Meter Temperature Degrees F 83.30 85.5 86.9 85.47 90.9 89.9

3 Runs 3 Runs 

### RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 35.817 36.236 35.92935.994 33.089 37.123 38.75436.322 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.15 29.15 29.07 29.12 29.13 29.19 29.15 29.16
Water vapor in Stack Gas Percent 8.3 8.3 8.4 8.3 7.9 7.4 7.5 7.6
Average Stack Gas Velocity Feet per second 53.4 53.4 53.9 53.6 49.4 49.3 48.9 49.2

Stack Gas FlowRate Actual Cubic 393,770 393,725 397,261394,919 364,076 363,511 360,197362,595 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic 250,190 260,364 261,493257,349 250,036 257,801 256,053254,630 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic 229,389 238,663 239,527235,860 230,373 238,731 236,784235,296 Feet Per Minute Particulate Concentration Grains per Standard 0.0076 0.0058 0.00490.0061 0.0068 0.0041 0.00450.0052 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0044 0.0035 0.00290.0036 0.0043 0.0027 0.00300.0033 Cubic Foot Particulate Emission Rate Pounds per Hour 14.9 11.9 10.0 12.3 13.5 8.5 9.2 10.4

Particulate Emission Rate Pounds per Million 0.0171 0.0132 0.0111 0.0138 0.0155 0.0094 0.00990.0116 Btu (O2 F Factor) Combined Particulate Emission RatePounds per Million 0.0163 0.0113 0.01050.0127 Allowable Particulate Emission Rate Btu (O2 F Factor) 0.1 0.1 0.1 0.1 Heat Input (O2 F Factor) Million Btu per Hour 869 904 907 893 872 904 931 903

Isokinetic Rate Percent 97.7 95.0 97.8 96.8 93.6 97.2 102.3 97.7 

## Calculations TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS GULF POWER COMPANY PLANT SMITH, UNIT 2, STEADY STATE

5/31/2005

### ATTACHMENT 6 - Smith Report 6 Test Results

Upper Upper Upper Upper Lower Lower Lower Lower

Title of Run RUN 1 RUN 2 RUN 3 Duct RUN 1 RUN 2 RUN 3 Duct Date Month/Day/Year 6/1/20056/1/20056/1/2005 Average 6/1/20056/1/20056/1/2005 Average Sampling Time -Start Military 0700 0845 1020Compliance 0700 0845 1020Compliance Sampling Time -Stop Military 0808 0951 1128 0808 0951 1128 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 1.95 1.95 1.95 2.00 2.00 2.00 Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10 30.10 30.10 Meter Correction Factor dimensionless 1.0110 1.0110 1.0110 1.0460 1.0460 1.0460 Oxygen Concentration Mole Percent O2 7.5 7.5 7.5 8.0 8.0 8.0 Carbon Dioxide Concentration Mole Percent CO2 11.0 11.5 11.5 11.0 11.0 11.0 Volume of Gas Metered Actual Cubic Feet 35.765 34.915 35.527 36.270 37.041 36.617 Volume of Water Collected Milliliters 62 65 62 68 70 64 Sampling Time Minutes 60.00 60.00 60.00 60.00 60.00 60.00 Nozzle Diameter Inches 0.240 0.240 0.240 0.245 0.245 0.245 Weight of Solids Collected Milligrams 13.3 15.9 14.5 10.8 16.3 12.4 Area of Stack Square Feet 122.910122.910122.910 122.840122.840122.840 Avg. Sqr. Root VelocityPressure Inches Water 0.7697 0.7584 0.7630 0.7460 0.7434 0.7610 Average Orifice Pressure(H) Inches Water 1.319 1.3 1.3 1.542 1.5 1.6 Average Stack Temperature Degrees F 317.13 319.3 343.5 315.03 303.0 317.2 Average Meter Temperature Degrees F 79.53 81.5 83.0 91.77 93.7 89.7

3 Runs 

### RUN 1 RUN 2 RUN 3 Average RUN 1 RUN 2 RUN 3 Average
Volume of Gas Sampled Standard Dry 35.721 34.740 35.255 35.239 36.668 37.314 37.166 37.049 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.15 29.16 29.21 29.17 29.11 29.10 29.17 29.13
Water vapor in Stack Gas Percent 7.6 8.1 7.6 7.8 8.0 8.1 7.5 7.9
Average Stack Gas Velocity Feet per second 51.9 51.2 52.2 51.8 50.2 49.7 51.3 50.4

Stack Gas FlowRate Actual Cubic 382,613377,473385,259 381,782 370,341366,230377,913 371,495 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic 262,712258,451255,855 259,006 255,006256,165259,505 256,892 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic 242,870237,531236,295 238,899 234,533235,381240,048 236,654 Feet Per Minute Particulate Concentration Grains per Standard 0.0057 0.0070 0.0063 0.0064 0.0045 0.0067 0.0051 0.0055 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0036 0.0044 0.0039 0.0040 0.0029 0.0043 0.0033 0.0035 Cubic Foot Particulate Emission Rate Pounds per Hour 11.9 14.4 12.8 13.0 9.1 13.6 10.6 11.1

Particulate Emission Rate Pounds per Million 0.0125 0.0154 0.0138 0.0139 0.0103 0.0152 0.0116 0.0124 Btu (O2 F Factor) Combined Particulate Emission RatePounds per Million 0.0114 0.0153 0.0127 0.0131 Allowable Particulate Emission Rate Btu (O2 F Factor) 0.3 0.3 0.3 0.3 Heat Input (O2 F Factor) Million Btu per Hour 955 934 929 940 888 891 909 896

Isokinetic Rate Percent 95.9 95.3 97.3 96.2 97.8 99.1 96.8 97.9 

## Calculations TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS GULF POWER COMPANY SMITH UNIT 2, SOOT BLOWING OPERATIONS

6/1/2005

### ATTACHMENT 7 - Smith Report 7 Test Results

Plant Load Indicator\Label Inlet A Inlet A Inlet A Inlet B Inlet B Inlet B 

### INLET Title of Run RUN 1 RUN 2Average RUN 1 RUN 2Average A+B Date Month/Day/Year 6/1/20056/1/2005 6/1/20056/1/2005 TOTAL Sampling Time -Start Military 1656 1835 1656 1835 Sampling Time -Stop Military 1805 1843 1805 1843 Number of Ports dimensionless 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water -7.50 -7.50 -8.00 -8.00 Barometric Pressure Inches Mercury 30.10 30.10 30.10 30.10 Meter Correction Factor dimensionless 1.011 1.011 1.046 1.046 Oxygen Concentration Mole Percent O2 4.5 4.5 4.5 4.5 Carbon Dioxide Concentration Mole Percent CO2 13.5 13.0 13.5 13.5 Volume of Gas Metered Actual Cubic Feet 39.715 40.542 28.482 32.855 Volume of Water Collected Milliliters 66.00 64.00 56.00 69.00 Sampling Time Minutes 60 60 60 60 Nozzle Diameter Inches 0.300 0.300 0.250 0.275 Weight of Solids Collected Milligrams 3,896.6 3,875.1 3,285.9 3,260.0 Area of Stack Square Feet 155.0 155.0 155.0 155.0 Avg. Sqr. Root Velocity PressureInches Water 0.6721 0.6887 0.6835 0.6599 Average Orifice Pressure(H) Inches Water 1.7 1.7 1.0 1.3 Average Stack Temperature Degrees F 752 750 751 740 750 745 748 Average Meter Temperature Degrees F 90 93 89 90



## Calculations Inlet A Inlet B Inlet

RUN 1 RUN 2Average RUN 1 RUN 2Average A & B Total Volume of Gas Sampled Standard Dry 38.944 39.549 39.247 28.908 33.326 31.117 35.18 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.43 29.39 29.41 29.31 29.24 29.28 29.34
Water vapor in Stack Gas Percent 7.4 7.1 7.2 8.4 8.9 8.6 7.9
Average Stack Gas Velocity Feet per second 57.0 58.4 57.7 57.8 56.1 57.0 57.3

Stack Gas Flow Rate Actual Cubic 529,750542,798536,274537,544521,745529,6451,065,919 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 227,899233,834230,867233,275224,485228,880459,747 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 211,063217,284214,173213,782204,551209,167423,340 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 15,809 16,275 16,042 16,012 15,321 15,667 31,708 Per Minute Particulate Concentration Grains per Standard 1.5409 1.5089 1.5249 1.7505 1.5064 1.6284 1.5767 Dry Cubic Foot Particulate Concentration Grains per Actual 0.6139 0.6040 0.6090 0.6962 0.5906 0.6434 0.6262 Cubic Foot Particulate Emission Rate Pounds per Hour 2,787.6 2,810.22,798.9 3,207.6 2,641.22,924.4 5,723.3

Particulate Emission Rate Pounds per Million 2.744 2.687 2.715 3.117 2.682 2.899 2.807 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 1,016 1,046 1,031 1,029 985 1,007 2,038

Isokinetic Rate Percent 97.1 95.8 102.5 102.0 

## INLET A INLET B 

# INLET A & B TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY SMITH UNIT 2,

Inlet A & B

### ATTACHMENT 8 - Smith Report 8 Test Results

Plant Load Indicator\Label Condition 1Condition 1Condition 2Condition 2Condition 3Condition 3 Condition 1Condition 2 Condition 3 

### Title of Run RUN 1 RUN 2 RUN 3 RUN 4 RUN 5 RUN 6OUTLET AOUTLET AOUTLET A Date Month/Day/Year 6/2/2005 6/2/2005 6/2/2005 6/2/2005 6/2/2005 6/2/2005 Average Average Average Sampling Time -Start Military 1200 1342 1540 1706 1843 1955 Sampling Time -Stop Military 1258 1436 1634 1800 1937 2049 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water -10.00 -10.00 -10.00 -10.00 -10.00 -10.00 Barometric Pressure Inches Mercury 30.15 30.15 30.15 30.15 30.15 30.15 Meter Correction Factor dimensionless 1.046 1.046 1.046 1.046 1.046 1.046 Oxygen Concentration Mole Percent O2 5.5 5.5 5.5 5.5 5.5 5.5 Carbon Dioxide Concentration Mole Percent CO2 13.0 13.0 13.0 13.0 13.0 13.0 Volume of Gas Metered Actual Cubic Feet 27.058 27.425 30.691 29.738 28.657 29.895 Volume of Water Collected Milliliters 44.00 48.00 63.00 65.00 54.00 59.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.250 0.260 0.260 0.260 0.260 0.260 Weight of Solids Collected Milligrams 37.9 26.9 31.6 92.4 50.2 50.1 Area of Stack Square Feet 84.3333 84.3333 84.3333 84.3333 84.3333 84.3333 Avg. Sqr. Root Velocity PressureInches Water 0.6871 0.6582 0.7348 0.6863 0.7022 0.6819 Average Orifice Pressure(H) Inches Water 1.0 1.1 1.3 1.2 1.2 1.2 Average Stack Temperature Degrees F 708 708 710 715 702 700 708 713 701 Average Meter Temperature Degrees F 88 89 88 89 85 82


## Calculations
Condition 1 Condition 2 Condition 3 

### RUN 1 RUN 2 RUN 3 RUN 4 RUN 5 RUN 6OUTLET AOUTLET AOUTLET A
Volume of Gas Sampled Standard Dry 27.573 27.882 31.257 30.240 29.358 30.781 27.728 30.748 30.070 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.44 29.38 29.23 29.17 29.32 29.28 29.41 29.20 29.30
Water vapor in Stack Gas Percent 7.0 7.5 8.7 9.2 8.0 8.3 7.2 8.9 8.1
Average Stack Gas Velocity Feet per second 57.3 54.9 61.5 57.7 58.5 56.8 56.1 59.6 57.7

Stack Gas Flow Rate Actual Cubic 289,861 278,014 311,394 291,770 296,145 287,529 283,937 301,582 291,837 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 128,825 123,513 138,106 128,852 132,247 128,621 126,169 133,479 130,434 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 119,825 114,254 126,139 117,013 121,710 117,977 117,039 121,576 119,843 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 8,975 8,558 9,448 8,764 9,116 8,836 8,766 9,106 8,976 Per Minute Particulate Concentration Grains per Standard 0.0212 0.0149 0.0156 0.0471 0.0263 0.0251 0.0180 0.0313 0.0257 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0088 0.0061 0.0063 0.0189 0.0108 0.0103 0.0074 0.0126 0.0106 Cubic Foot Particulate Emission Rate Pounds per Hour 21.7 14.6 16.8 47.2 27.5 25.3 18.1 32.0 26.4

Particulate Emission Rate Pounds per Million 0.040 0.028 0.030 0.089 0.050 0.048 0.034 0.059 0.049 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 542 516 570 529 550 533 529 550 542

Isokinetic Rate Percent 94.9 93.0 94.4 98.5 91.9 99.4 

## 6/2/2005 

# OUTLET A THREE CONDITIONS TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY SMITH UNIT 2,

OUTLET A

### ATTACHMENT 9 - Smith Report 9 Test Results

Plant Load Indicator\Label Condition 1Condition 1Condition 2Condition 2Condition 3Condition 3 Condition 1Condition 2 Condition 3 

### Title of Run RUN 1 RUN 2 RUN 3 RUN 4 RUN 5 RUN 6OUTLET BOUTLET BOUTLET B Date Month/Day/Year 6/2/2005 6/2/2005 6/2/2005 6/2/2005 6/2/2005 6/2/2005 Average Average Average Sampling Time -Start Military 1200 1342 1540 1706 1843 1955 Sampling Time -Stop Military 1258 1430 1634 1800 1937 2049 Number of Ports dimensionless 6 6 6 6 6 6 Number of Points per Port dimensionless 5 5 5 5 5 5 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water -0.10 -0.10 -0.10 -0.10 -0.10 -0.10 Barometric Pressure Inches Mercury 30.15 30.15 30.15 30.15 30.15 30.15 Meter Correction Factor dimensionless 1.011 1.011 1.011 1.011 1.011 1.011 Oxygen Concentration Mole Percent O2 5.5 5.5 5.5 5.5 5.5 5.5 Carbon Dioxide Concentration Mole Percent CO2 13.0 13.0 13.0 13.0 13.0 13.0 Volume of Gas Metered Actual Cubic Feet 32.212 26.572 32.714 32.226 31.342 30.787 Volume of Water Collected Milliliters 39.00 43.00 66.00 61.00 49.00 52.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.250 0.250 0.250 0.250 0.250 0.250 Weight of Solids Collected Milligrams 42.9 52.8 37.0 152.2 50.9 48.5 Area of Stack Square Feet 84.3333 84.3333 84.3333 84.3333 84.3333 84.3333 Avg. Sqr. Root Velocity PressureInches Water 0.7772 0.7137 0.7813 0.7343 0.7567 0.6969 Average Orifice Pressure(H) Inches Water 1.4 1.1 1.4 1.4 1.3 1.2 Average Stack Temperature Degrees F 705 700 710 715 700 700 703 713 700 Average Meter Temperature Degrees F 86 87 84 85 82 82


## Calculations
Condition 1Condition 1Condition 2Condition 2Condition 3Condition 3 Condition 1 Condition 2 Condition 3 

### RUN 1 RUN 2 RUN 3 RUN 4 RUN 5 RUN 6OUTLET BOUTLET BOUTLET B
Volume of Gas Sampled Standard Dry 31.867 26.207 32.441 31.921 31.223 30.662 29.037 32.181 30.942 Cubic Feet Molecular Wt. of Stack Gas (wet)LB/LB-MOLE 29.63 29.42 29.23 29.28 29.45 29.39 29.52 29.25 29.42
Water vapor in Stack Gas Percent 5.4 7.2 8.7 8.3 6.9 7.4 6.3 8.5 7.1
Average Stack Gas Velocity Feet per second 63.7 58.6 64.7 60.8 62.1 57.3 61.2 62.7 59.7

Stack Gas Flow Rate Actual Cubic 322,570 296,563 327,136 307,805 314,239 289,713 309,567 317,471 301,976 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 147,176 135,945 148,678 139,297 144,048 132,806 141,561 143,988 138,427 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 139,160 126,199 135,685 127,801 134,139 122,988 132,679 131,743 128,564 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 10,423 9,452 10,163 9,572 10,047 9,212 9,938 9,868 9,629 Per Minute Particulate Concentration Grains per Standard 0.0207 0.0310 0.0176 0.0734 0.0251 0.0244 0.0259 0.0455 0.0247 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0089 0.0132 0.0073 0.0305 0.0107 0.0103 0.0111 0.0189 0.0105 Cubic Foot Particulate Emission Rate Pounds per Hour 24.7 33.6 20.4 80.4 28.9 25.7 29.1 50.4 27.3

Particulate Emission Rate Pounds per Million 0.039 0.059 0.033 0.139 0.048 0.046 0.049 0.086 0.047 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 629 570 613 578 606 556 600 596 581

Isokinetic Rate Percent 94.4 85.6 98.6 103.0 96.0 102.8 

## 6/2/2005 

# OUTLET B THREE CONDITIONS TABLE I. SUMMARY OF PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY SMITH UNIT 2,

OUTLET B

### ATTACHMENT 10 - Smith Report 10 Test Results

Plant Load Indicator\Label Combined Title of Run RUN 1 RUN 2 RUN 3 Outlet Date Month/Day/Year 6/2/20056/2/20056/2/2005Average Sampling Time -Start Military 0756 0900 0952 Sampling Time -Stop Military 0836 0940 1032 Number of Ports dimensionless 4 4 4 Number of Points per Port dimensionless 5 5 5 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 Stack Static Pressure Inches Water -9.00 -9.00 -9.00 Barometric Pressure Inches Mercury 30.15 30.15 30.15 Meter Correction Factor dimensionless 1.011 1.011 1.011 Oxygen Concentration Mole Percent O2 5.5 5.5 5.5 Carbon Dioxide Concentration Mole Percent CO2 13.0 13.0 13.0 Volume of Gas Metered Actual Cubic Feet 26.581 27.347 27.507 Volume of Water Collected Milliliters 38.00 43.00 47.00 Sampling Time Minutes 40 40 40 Nozzle Diameter Inches 0.250 0.250 0.250 Weight of Solids Collected Milligrams 11.1 10.2 19.5 Area of Stack Square Feet 310.0 310.0 310.0 Avg. Sqr. Root Velocity PressureInches Water 0.9177 0.9542 0.9473 Average Orifice Pressure(H) Inches Water 1.7 1.9 1.8 Average Stack Temperature Degrees F 698 695 697 697 Average Meter Temperature Degrees F 82 82 83


## Calculations Combined

RUN 1 RUN 2 RUN 3 Outlet Average Volume of Gas Sampled Standard Dry 26.498 27.270 27.389 27.052 Cubic Feet Molecular Wt. of Stack Gas LB/LB-MOLE 29.52 29.45 29.38 29.45
Water vapor in Stack Gas Percent 6.3 6.9 7.5 6.9
Average Stack Gas Velocity Feet per second 76.0 79.0 78.6 77.9

Stack Gas Flow Rate Actual Cubic 1,413,4901,469,4261,462,1501,448,355 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 635,031 661,934657,233 651,399 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 594,875 616,198 608,115 606,396 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 44,556 46,153 45,548 45,419 Per Minute Particulate Concentration Grains per Standard 0.0065 0.0058 0.0110 0.0077 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0027 0.0024 0.0046 0.0032 Cubic Foot Particulate Emission Rate Pounds per Hour 32.9 30.4 57.1 40.2

Particulate Emission Rate Pounds per Million 0.012 0.011 0.021 0.015 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 2,689 2,786 2,749 2,741

Isokinetic Rate Percent 101.2 100.6 102.4 101.4 

## 6/2/2005 

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

GULF POWER COMPANY SMITH UNIT 2,

Combined Outlet

# ATTACHMENT 11 - Smith Report 11 Test Results

2006 SO2 Emissions Test (Based on RATA Results)



## Run Number Date- Start TimeDate- Stop Time Average Emissions (lbs/mmBTU SO2

## ) 1 5/10/06- 11:44 5/10/06- 12:05 1.169 2 5/10/06- 12:28 5/10/06- 12:49 1.13 3 5/10/06- 13:18 5/10/06- 13:39 1.161 4 5/10/06- 14:02 5/10/06- 14:23 1.13 5 5/10/06- 14:44 5/10/06- 15:05 1.138 6 5/10/06- 15:28 5/10/06- 15:49 1.133 7 5/11/06- 07:03 5/11/06- 07:24 1.144 8 5/11/06- 07:51 5/11/06- 08:12 1.142 9 5/11/06- 08:35 5/11/06- 08:56 1.138 10 5/11/06- 09:19 5/11/06- 09:40 1.123 Average: 1.141 Smith Unit 1 -2006 Full Load ~ 171 MWs

### ATTACHMENT 12 - Smith 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 5/10/20065/10/20065/10/2006 5/10/20065/10/20065/10/2006 Sampling Time -Start Military 1044 1230 1400 1044 1230 1400 Sampling Time -Stop Military 1151 1337 1507 1151 1337 1507 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.85 0.85 0.85 0.85 0.85 0.85 Barometric Pressure Inches Mercury 29.96 29.96 29.96 29.96 29.96 29.96 Standard Orifice PressureH@ Inches Water 2.378 2.378 2.378 2.008 2.008 2.008 Meter Correction Factor dimensionless 0.938 0.938 0.938 0.967 0.967 0.967 Oxygen Concentration Mole Percent O2 7.0 6.5 6.5 7.5 7.0 7.0 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 12.0 11.5 12.0 12.0 Volume of Gas Metered Actual Cubic Feet 38.315 39.900 40.550 42.310 42.337 42.595 Volume of Water Collected Milliliters 64.00 70.00 67.00 75.00 80.00 79.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.240 0.240 0.240 0.245 0.245 0.245 Weight of Solids Collected Milligrams 23.5 13.3 9.5 14.1 10.3 8.7 Area of Stack Square Feet 96.900096.900096.9000 107.3800107.3800107.3800 Avg. Sqr. Root Velocity Pressure Inches Water 0.7555 0.7846 0.7845 0.8156 0.8076 0.8075 Average Orifice Pressure(H) Inches Water 1.8 1.9 1.9 1.9 1.8 1.8 Average Stack Temperature Degrees F 281 283.8 288 305 302 301 Average Meter Temperature Degrees F 83 84 82 82 84 86

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

Volume of Gas Sampled Standard Dry 35.144 36.551 37.28436.326 40.128 39.974 40.070 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.20 30.18 30.18 30.19 30.14 30.20 30.20
Water vapor in Stack Gas Percent 7.9 8.3 7.8 8.0 8.1 8.6 8.5
Average Stack Gas Velocity Feet per second 49.8 51.9 52.0 51.2 54.7 54.1 54.1

Stack Gas FlowRate Actual Cubic 289,660301,817302,339297,939 352,644 348,615 348,271 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic 207,207214,955214,117212,093 244,212 242,309 242,378 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic 190,848197,180197,418195,149 224,465 221,449 221,795 Feet Per Minute Particulate Concentration Grains per Standard 0.0103 0.0056 0.00390.0066 0.0054 0.0040 0.0033 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0068 0.0037 0.00260.0043 0.0034 0.0025 0.0021 Cubic Foot Particulate Emission Rate Pounds per Hour 16.8 9.5 6.6 11.0 10.4 7.5 6.4

Particulate Emission Rate Pounds per Million 0.022 0.011 0.008 0.014 0.012 0.008 0.007 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 779 833 834 816 883 904 905

Isokinetic Rate Percent 94.6 95.3 97.1 95.7 97.7 98.7 98.7

Post Test Meter Correction Factor dimensionless 1.00 1.00 0.98 1.00 1.02 1.00 1.00

Percent Difference Allowed 5% 6.50 6.32 4.45 5.76 4.85 3.48 2.91

Combinated Particulate Emission RatePounds per Million 0.017 0.010 0.008 0.012 Allowable Btu (O2 F Factor) 0.1 0.1 0.1 0.1 

## Calculations 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH UNIT 1 STEADY STATE OPERATIONS

### ATTACHMENT 13 - Smith Report 13 Test Results

no soot blow no soot blow Side A Side A Side A Side A Side B Side B Side B Side B Title of Run RUN 1 RUN 2 RUN 3 RUN 4 RUN 1 RUN 2 RUN 3 RUN 4 Date Month/Day/Year 5/11/2006 5/11/20065/11/20065/11/2006 5/11/20065/11/20065/11/20065/11/2006 Sampling Time -Start Military 0633 0843 1022 1155 0633 0843 1022 1155 Sampling Time -Stop Military 0740 0949 1129 1256 0740 0949 1129 1256 Number of Ports dimensionless 5 5 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.85 0.85 0.85 0.85 0.85 0.85 0.85 0.85 Barometric Pressure Inches Mercury 29.85 29.85 29.85 29.85 29.85 29.85 29.85 29.85 Standard Orifice PressureH@ Inches Water 2.378 2.378 2.378 2.378 2.008 2.008 2.008 2.008 Meter Correction Factor dimensionless 0.938 0.938 0.938 0.938 0.967 0.967 0.967 0.967 Oxygen Concentration Mole Percent O2 6.0 6.5 6.5 6.0 6.5 6.5 6.0 6.0 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 12.0 12.0 12.0 12.0 12.5 12.0 Volume of Gas Metered Actual Cubic Feet 40.675 39.600 39.780 39.500 42.207 42.371 43.412 43.185 Volume of Water Collected Milliliters 70.00 68.00 74.00 76.00 79.00 76.00 80.00 83.00 Sampling Time Minutes 60 60 60 60 60 60 60 60 Nozzle Diameter Inches 0.240 0.240 0.240 0.240 0.245 0.245 0.245 0.245 Weight of Solids Collected Milligrams 12.3 14.4 8.5 11.7 12.5 15.6 6.2 4.8 Area of Stack Square Feet 96.9000 96.9000 96.9000 96.9000 107.3800107.3800107.3800107.3800 Avg. Sqr. Root Velocity Pressure Inches Water 0.7804 0.7478 0.7551 0.7826 0.8011 0.7967 0.8254 0.8164 Average Orifice Pressure(H) Inches Water 1.9 1.7 1.8 1.9 1.9 1.9 2.0 1.9 Average Stack Temperature Degrees F 291 294.4 295 293 299 302 301 301 Average Meter Temperature Degrees F 79 77 77 79 76.8 79.0 80 83

no soot blow RUN 1 RUN 2 RUN 3 RUN 4Average RUN 1 RUN 2 RUN 3 RUN 4Average

Volume of Gas Sampled Standard Dry 37.489 36.600 36.782 36.36036.581 40.243 40.234 41.126 40.71040.690 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.16 30.18 30.18 30.16 30.17 30.18 30.18 30.24 30.16 30.19
Water vapor in Stack Gas Percent 8.1 8.0 8.7 9.0 8.5 8.5 8.2 8.4 8.8 8.4
Average Stack Gas Velocity Feet per second 52.0 49.9 50.5 52.3 50.9 53.6 53.4 55.3 54.8 54.5

Stack Gas FlowRate Actual Cubic 302,219 290,100 293,435 304,034295,856 345,645 344,208 356,354 353,221351,261 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic 212,348 202,950 205,120 213,037207,036 240,438 238,547 247,040 244,836243,475 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic 195,193 186,629 187,376 193,955189,320 220,100 219,069 226,318 223,398222,928 Feet Per Minute Particulate Concentration Grains per Standard 0.0051 0.0061 0.0036 0.00500.0049 0.0048 0.0060 0.0023 0.00180.0034 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0033 0.0039 0.0023 0.00320.0031 0.0030 0.0038 0.0015 0.00110.0021 Cubic Foot Particulate Emission Rate Pounds per Hour 8.5 9.7 5.7 8.2 7.9 9.0 11.2 4.5 3.5 6.4

Particulate Emission Rate Pounds per Million 0.010 0.012 0.007 0.010 0.010 0.010 0.012 0.005 0.004 0.007 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 854 789 792 848 810 930 926 990 977 964

Isokinetic Rate Percent 98.7 100.8 100.9 96.4 99.3 99.9 100.4 99.3 99.6 99.8

Post Test Meter Correction Factor dimensionless 0.97 0.96 0.96 1.00 0.97 1.01 1.01 1.01 1.01 1.01

Percent Difference Allowed 5% 3.67 2.05 2.26 6.39 3.57 4.52 4.20 4.47 4.29 4.32

Combinated Particulate Emission RatePounds per Million 0.0122 0.0059 0.00660.0082 Allowable Btu (O2 F Factor) 0.3 0.3 0.3 0.3 

## Calculations 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH UNIT 1 SOOT BLOWING OPERATIONS

# ATTACHMENT 14 - Smith Report 14 Test Results

2006 SO2 Emissions Test (Based onRATA Results)

Run Number Date- Start Time Date- Start Time Average Emissions (lbs/mmBTU SO2

## ) 1 5/22/2006 7:16 5/22/2006 7:37 1.132 2 5/22/2006 7:58 5/22/2006 8:19 1.138 3 5/22/2006 8:42 5/22/2006 9:03 1.123 4 5/22/2006 9:43 5/22/2006 10:04 1.157 5 5/22/2006 10:27 5/22/2006 10:48 1.124 6 5/22/2006 11:08 5/22/2006 11:29 1.156 7 5/22/2006 11:52 5/22/2006 12:13 1.171 8 5/22/2006 12:36 5/22/2006 12:57 1.165 9 5/22/2006 14:34 5/22/2006 14:55 1.131

Average: 1.144 Smith Unit 2 - 2006 Full Load ~ 201 MWs

### ATTACHMENT 15 - Smith 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 5/22/2006 5/22/2006 5/22/2006 5/22/2006 5/22/2006 5/22/2006 Sampling Time -StartMilitary 1233 1355 1519 1233 1355 1519 Sampling Time -StopMilitary 1339 1459 1621 1336 1459 1621 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static PressureInches Water 1.45 1.45 1.45 1.65 1.65 1.65 Barometric Pressure Inches Mercury 30.21 30.21 30.21 30.21 30.21 30.21 Standard Orifice Pressure 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 ConcentrationMole Percent O2 6.5 6.5 7.0 7.5 8.0 7.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 11.5 11.5 11.5 11.5 Volume of Gas MeteredActual Cubic Feet 41.195 41.647 41.557 42.039 39.652 40.440 Volume of Water Collected Milliliters 74.00 75.00 77.00 54.00 73.00 71.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.240 0.240 0.240 0.245 0.240 0.240 Weight of Solids Collected Milligrams 21.7 22.2 14.9 13.4 20.2 13.9 Area of Stack Square Feet 122.9100 122.9100 122.9100 122.8400 122.8400 122.8400 Avg. Sqr. Root Velocity Pressure Inches Water 0.8134 0.8150 0.8150 0.7918 0.7674 0.7917 Average Orifice Pressure Inches Water 1.691 1.691 1.691 2.046 1.754 1.893 Average Stack Temperature Degrees F 322 322 322 337 337 337 Average Meter Temperature Degrees F 88 91 91 86 86 86

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

Volume of Gas SampledStandard Dry 38.888 39.134 39.049 39.024 38.718 36.463 37.246 37.476 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.18 30.18 30.12 30.16 30.14 30.16 30.14 30.15
Water vapor in Stack Gas Percent 8.2 8.3 8.5 8.3 6.2 8.6 8.2 7.7
Average Stack Gas Velocity Feet per second 54.9 55.0 55.1 55.0 53.7 52.3 54.0 53.4

Stack Gas FlowRateActual Cubic 404,860 405,723 406,314 405,633 396,135 385,745 397,792 393,224 Feet Per Minute Stack Gas FlowRateStandard Wet Cubic 276,985 277,587 277,944 277,505 266,030 259,095 267,154 264,093 Feet Per Minute Stack Gas FlowRateStandard Dry Cubic 254,215 254,618 254,337 254,390 249,641 236,782 245,156 243,860 Feet Per Minute Particulate Concentration Grains per Standard 0.0086 0.0087 0.0059 0.0077 0.0053 0.0085 0.0057 0.0065 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0054 0.0055 0.0037 0.0049 0.0034 0.0052 0.0035 0.0040 Cubic Foot Particulate Emission Rate Pounds per Hour 18.7 19.1 12.8 16.9 11.4 17.3 12.1 13.6

Particulate Emission Rate Pounds per Million 0.017 0.018 0.012 0.016 0.012 0.019 0.013 0.014 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 1,075 1,076 1,038 1,063 982 897 964 948

Isokinetic Rate Percent 99.7 100.2 100.1 100.0 97.0 100.3 99.0 98.8

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

Percent Difference Allowed 5% 2.80 1.96 2.26 2.34 4.53 2.77 4.53 3.94

Combined Particulate Emission Rate Pounds per Million 0.015 0.019 0.012 0.016 Allowable Btu (O2 F Factor) 0.3 0.3 0.3 0.3 

## Calculations 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT 2 SOOT BLOWING OPERATIONS

### ATTACHMENT 16 - Smith 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 5/22/20065/22/20065/22/2006 5/22/20065/22/20065/22/2006 Sampling Time -Start Military 0630 0801 0927 0630 0801 0927 Sampling Time -Stop Military 0735 0905 1033 0735 0905 1033 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 1.45 1.45 1.45 1.60 1.60 1.60 Barometric Pressure Inches Mercury 30.21 30.21 30.21 30.21 30.21 30.21 Standard Orifice PressureH@ 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 6.5 7.0 6.5 8.0 9.0 8.0 Carbon Dioxide Concentration Mole Percent CO2 12.0 11.5 11.5 11.5 11.0 10.0 Volume of Gas Metered Actual Cubic Feet 40.548 41.596 40.950 41.181 39.873 40.012 Volume of Water Collected Milliliters 75.00 79.00 77.00 66.00 76.00 72.00 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.240 0.240 0.240 0.245 0.240 0.240 Weight of Solids Collected Milligrams 19.3 12.4 23.2 17.9 14.1 18.7 Area of Stack Square Feet 122.9100 122.9100 122.9100 122.8400 122.8400 122.8400 Avg. Sqr. Root Velocity Pressure Inches Water 0.8100 0.8298 0.8122 0.7821 0.7902 0.7816 Average Orifice Pressure(H) Inches Water 1.653 1.714 1.667 1.989 1.849 1.832 Average Stack Temperature Degrees F 316 317.2 317 325 328 332 Average Meter Temperature Degrees F 74 80 86 78 82 86

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

Volume of Gas Sampled Standard Dry 39.292 39.855 38.82939.325 38.461 36.932 36.80337.399 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.18 30.12 30.10 30.13 30.16 30.12 29.92 30.07
Water vapor in Stack Gas Percent 8.2 8.5 8.5 8.4 7.5 8.8 8.4 8.2
Average Stack Gas Velocity Feet per second 54.5 55.9 54.8 55.1 52.8 53.7 53.3 53.3

Stack Gas FlowRate Actual Cubic 401,805 412,511 403,787406,035 389,331 395,507 392,972392,603 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic 276,795 283,890 278,018279,568 265,371 268,508 265,618266,499 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic 253,976 259,663 254,282255,974 245,538 244,796 243,221244,518 Feet Per Minute Particulate Concentration Grains per Standard 0.0076 0.0048 0.00920.0072 0.0072 0.0059 0.00780.0070 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0048 0.0030 0.00580.0045 0.0045 0.0036 0.00480.0043 Cubic Foot Particulate Emission Rate Pounds per Hour 16.5 10.7 20.1 15.7 15.1 12.3 16.3 14.6

Particulate Emission Rate Pounds per Million 0.015 0.010 0.019 0.015 0.016 0.014 0.018 0.016 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 1,074 1,059 1,075 1,069 930 855 921 902

Isokinetic Rate Percent 100.9 100.1 99.5 100.2 97.9 98.3 98.6 98.3

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

Percent Difference Allowed 5% 1.96 1.88 2.61 2.15 4.47 4.52 4.40 4.46

Combined Particulate Emission RatePounds per Million 0.016 0.012 0.018 0.015 Allowable Btu (O2 F Factor) 0.1 0.1 0.1 0.1 

## Calculations 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT 2 STEADY STATE OPERATIONS

# ATTACHMENT 17 - Smith Report 17 Test Results

2007 SO2 Emissions Test (Based onRATA Results)

Smith Unit 1 2007 Run Date Time Time Unit RM-6C (SO2) Number Started Stopped Load lbs/mmBtu

1 6/11/2007 

## 11:30 10:38 171 

## 1.272 2 6/11/2007 

## 12:17 9:21 172 

## 1.294 3 6/11/2007 

## 12:56 8:44 172 

## 1.289 4 6/11/2007 

## 13:35 7:57 171 

## 1.283 5 6/11/2007 

## 14:12 7:19 171 

## 1.285 6 6/11/2007 

## 14:58 6:41 172 

## 1.296 7 6/12/2007 

## 6:20 15:19 170 

## 1.271 8 6/12/2007 

## 6:58 14:33 171 

## 1.282 9 6/12/2007 

## 7:36 13:56 171 

## 1.3 10 6/12/2007 

## 8:23 13:17 171 

## 1.315 11 6/12/2007 

## 9:00 12:38 171 

## 1.318 12 6/12/2007 

## 10:17 11:54 170 

## 1.289 Avg 1.291166667

### ATTACHMENT 18 - Smith Report 18 Test Results

Lower Lower Lower Upper Upper Upper

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/11/20076/11/20076/11/2007 6/11/20076/11/20076/11/2007 Sampling Time -Start Military 1117 1249 1428 1117 1249 1428 Sampling Time -Stop Military 1225 1357 1536 1225 1357 1536 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.90 0.90 0.90 0.80 0.80 0.80 Barometric Pressure Inches Mercury 29.95 29.95 29.95 29.95 29.95 29.95 Standard Orifice PressureH@ 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 6.5 6.0 5.5 6.00 5.00 6.50 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 11.5 12.50 12.00 12.50 Volume of Gas Metered Actual Cubic Feet 43.320 43.364 47.360 45.543 41.652 41.294 Volume of Water Collected Milliliters 94 68 98 102 75 80 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.236 0.235 0.248 0.253 0.240 0.240 Weight of Solids Collected Milligrams 9.5 17.8 10.6 11.9 10.7 12.5 Area of Stack Square Feet 107.380 107.380 107.380 96.900 96.900 96.900 Avg. Sqr. Root Velocity Pressure Inches Water 0.8581 0.8644 0.8589 0.8190 0.8222 0.8154 Average Orifice Pressure(H) Inches Water 2.3 2.2 2.6 2.0 1.6 1.6 Average Stack Temperature Degrees F 315 316 317 316 318 320 Average Meter Temperature Degrees F 89 90 91 93 94 96

Lower Lower Lower Upper Upper Upper RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 39.416 39.338 42.941 40.565 42.934 39.122 38.69640.251 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.18 30.16 30.06 30.13 30.24 30.12 30.26 30.21
Water vapor in Stack Gas Percent 10.1 7.5 9.7 9.1 10.1 8.3 8.9 9.1
Average Stack Gas Velocity Feet per second 58.2 58.4 58.4 58.3 55.5 55.7 55.3 55.5

Stack Gas Flow Rate Actual Cubic 374,806 376,019 376,093375,639 322,693 323,829 321,262322,594 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 256,210 256,498 256,328256,345 220,295 220,426 218,090219,604 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 230,352 237,198 231,464233,004 198,138 202,182 198,750199,690 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 17,253 17,766 17,337 17,452 14,841 15,143 14,886 14,957 Per Minute Particulate Concentration Grains per Standard 0.004 0.007 0.004 0.005 0.004 0.004 0.005 0.004 Dry Cubic Foot Particulate Concentration Grains per Actual 0.002 0.004 0.002 0.003 0.003 0.003 0.003 0.003 Cubic Foot Particulate Emission Rate Pounds per Hour 7.3 14.2 7.5 9.7 7.2 7.3 8.5 7.7

Particulate Emission Rate Pounds per Million 0.008 0.014 0.007 0.009 0.008 0.008 0.010 0.009 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 974 1,037 1,046 1,019 867 944 840 883

Isokinetic Rate Percent 100.8 98.5 99.0 99.4 100.2 99.5 100.1 99.9

Post Test Meter Correction Factor dimensionless 1.01 0.99 0.99 1.00 1.00 0.99 0.99 1.00

Percent Difference Allowed 5% 7.4 4.6 5.1 5.7 2.1 1.1 1.0 1.4

Combined Particulate Emission RatePounds per Million 

### 0.00790.01090.00850.0091 Allowable Btu (O2 F Factor) 

### 0.3 0.3 0.3 0.3 

### Calculations 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT 1 SOOT BLOWING OPERATION

### ATTACHMENT 19 - Smith Report 19 Test Results

Lower Lower Lower Upper Upper Upper

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 6/12/20076/12/20076/12/2007 6/12/20076/12/20076/12/2007 Sampling Time -Start Military 0600 0733 0906 0600 0733 0906 Sampling Time -Stop Military 0708 0840 1012 0708 0840 1012 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.90 0.90 0.90 0.80 0.80 0.80 Barometric Pressure Inches Mercury 29.88 29.88 29.88 29.88 29.88 29.88 Standard Orifice PressureH@ 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 6.5 5.5 5.0 4.0 4.5 5.0 Carbon Dioxide Concentration Mole Percent CO2 12.5 12.0 12.5 12.0 12.5 11.0 Volume of Gas Metered Actual Cubic Feet 43.547 43.907 42.790 37.453 41.125 42.805 Volume of Water Collected Milliliters 90 86 87 83 79 88 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.236 0.240 0.240 0.235 0.248 0.253 Weight of Solids Collected Milligrams 11.9 14.1 9.0 12.1 14.2 12.2 Area of Stack Square Feet 107.380 107.380 107.380 96.900 96.900 96.900 Avg. Sqr. Root Velocity Pressure Inches Water 0.8714 0.8538 0.8403 0.7791 0.7710 0.7710 Average Orifice Pressure(H) Inches Water 2.2 2.2 2.2 1.3 1.7 1.8 Average Stack Temperature Degrees F 306 308 317 310 302 316 Average Meter Temperature Degrees F 81 83 85 84 87 89

Lower Lower Lower Upper Upper Upper RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 40.070 40.261 39.12239.817 35.707 39.028 40.49838.411 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.26 30.14 30.20 30.20 30.08 30.18 29.96 30.07
Water vapor in Stack Gas Percent 9.6 9.1 9.5 9.4 9.9 8.7 9.3 9.3
Average Stack Gas Velocity Feet per second 58.7 57.6 57.0 57.8 52.8 51.8 52.5 52.3

Stack Gas Flow Rate Actual Cubic 378,064 371,313 367,337372,238 306,823 300,915 305,086304,275 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 260,673 255,296 249,852255,273 210,502 208,554 207,647208,901 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 235,749 231,972 226,177231,299 189,742 190,411 188,379189,511 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 17,658 17,375 16,941 17,324 14,212 14,262 14,11014,194 Per Minute Particulate Concentration Grains per Standard 0.005 0.005 0.004 0.005 0.005 0.006 0.005 0.005 Dry Cubic Foot Particulate Concentration Grains per Actual 0.003 0.003 0.002 0.003 0.003 0.004 0.003 0.003 Cubic Foot Particulate Emission Rate Pounds per Hour 9.2 10.7 6.9 8.945 8.5 9.1 7.5 8.374

Particulate Emission Rate Pounds per Million 0.009 0.010 0.007 0.009 0.009 0.010 0.009 0.009 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 997 1,049 1,056 1,034 941 917 879 912

Isokinetic Rate Percent 100.1 98.9 98.5 99.2 100.9 98.7 99.4 99.7

Post Test Meter Correction Factor dimensionless 0.98 0.98 1.00 0.99 1.00 1.01 1.01 1.00

Percent Difference Allowed 5% (average) 3.8 4.1 6.4 4.8 1.5 2.7 2.5 2.2

Combined Particulate Emission RatePounds per Million 

### 0.0092 0.0101 0.00740.0089 Allowable Btu (O2 F Factor) 0.1 0.1 0.1 0.1 

### Calculations 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH UNIT 1 STEADY STATE OPERATION

# ATTACHMENT 20 - Smith Report 20 Test Results

2007 SO2 Emissions Test (Based onRATA Results)

Smith Unit 2 2007 Run Date Time Time Unit RM-6C (SO2) Number Started Stopped Load lbs/mmBtu

1 5/8/2007 6:12 

## 6:33 203 

## 1.254 2 5/8/2007 6:51 

## 7:12 203 

## 1.232 3 5/8/2007 7:55 

## 8:16 203 

## 1.275 4 5/8/2007 8:34 

## 8:55 203 

## 1.273 5 5/8/2007 9:12 

## 9:33 203 

## 1.281 6 5/8/2007 9:52 

## 10:13 203 

## 1.284 7 5/8/2007 10:30 

## 10:51 203 

## 1.283 8 5/8/2007 11:08 

## 11:29 203 

## 1.281 9 5/8/2007 11:45 

## 12:06 203 

## 1.283 10 5/8/2007 12:22 

## 12:43 203 

## 1.287 11 5/8/2007 12:59 

## 13:20 203 

## 1.283 12 5/8/2007 13:36 

## 13:57 204 

## 1.282 Avg 1.275

### ATTACHMENT 21 - Smith Report 21 Test Results

Plant Load MW Upper Upper Upper Lower Lower Lower Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/8/20075/8/20075/8/2007 5/8/20075/8/20075/8/2007 Sampling Time -Start Military 0739 0919 1054 0739 0919 1054 Sampling Time -Stop Military 0854 1032 1206 0854 1032 1206 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 2.30 2.30 2.30 1.40 1.40 1.40 Barometric Pressure Inches Mercury 30.04 30.04 30.04 30.04 30.04 30.04 Standard Orifice PressureH@ 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 6.5 6.0 6.0 7.0 6.5 5.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.5 12.5 12.5 12.5 12.5 Volume of Gas Metered Actual Cubic Feet 37.845 37.970 37.576 36.276 35.715 33.953 Volume of Water Collected Milliliters 58 58 74 72 71 72 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.238 0.236 0.234 0.233 0.235 0.235 Weight of Solids Collected Milligrams 24.5 24.2 13.0 9.7 16.6 12.9 Area of Stack Square Feet 122.910 122.910 122.910 122.840 122.840 122.840 Avg. Sqr. Root Velocity Pressure Inches Water 0.7425 0.7465 0.7455 0.7696 0.7511 0.7103 Average Orifice Pressure(H) Inches Water 1.5 1.6 1.5 1.3 1.2 1.1 Average Stack Temperature Degrees F 315 320 324 312 321 329 Average Meter Temperature Degrees F 70 75 78 72 74 83


### Calculations Upper Upper Upper Upper Lower Lower Lower Lower RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average
Volume of Gas Sampled Standard Dry 35.698 35.462 34.911 35.357 35.580 34.895 32.601 34.359 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.18 30.24 30.24 30.22 30.28 30.26 30.22 30.25
Water vapor in Stack Gas Percent 7.1 7.1 9.1 7.8 8.7 8.7 9.4 9.0
Average Stack Gas Velocity Feet per second 49.9 50.3 50.5 50.2 51.7 50.8 48.4 50.3

Stack Gas Flow Rate Actual Cubic 367,756370,672372,656370,361 381,317374,475 356,554370,782 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 252,909253,246253,206253,120262,723 255,001 240,487252,737 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 234,941 235,143 230,235233,440239,874232,713 217,841230,143 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 17,597 17,612 17,245 17,485 17,967 17,430 16,316 17,238 Per Minute Particulate Concentration Grains per Standard 0.011 0.011 0.006 0.009 0.004 0.007 0.006 0.006 Dry Cubic Foot Particulate Concentration Grains per Actual 0.007 0.007 0.004 0.006 0.003 0.005 0.004 0.004 Cubic Foot Particulate Emission Rate Pounds per Hour 21.3 21.2 11.3 17.9 8.6 14.6 11.4 11.5

Particulate Emission Rate Pounds per Million 0.021 0.021 0.011 0.018 0.009 0.015 0.012 0.012 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 993 1,028 1,007 1,010 979 984 985 982

Isokinetic Rate Percent 100.7 101.7 104.0 102.1 102.5 101.9 101.7 102.0

Post Test Meter Correction Factor dimensionless 0.92 0.93 0.94 0.93 0.98 0.99 1.00 0.99

Percent Difference Allowed 5% -1.6 -0.6 0.0 -0.7 -0.3 1.1 1.6 0.8

Combined Particulate Emission RatePounds per Million 0.015 0.018 0.011 0.015 Allowable Btu (O2 F Factor) 0.1 0.1 0.1 0.1



## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT 2 SOOT BLOWING OPERATIONS

### ATTACHMENT 22 - Smith Report 22 Test Results

Plant Load MW Upper Upper Upper Lower Lower Lower Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day /Year 5/8/20075/8/20075/8/2007 5/8/20075/8/20075/8/2007 Sampling Time -Start Military 1344 1527 1658 1344 1527 1658 Sampling Time -Stop Military 1458 1637 1810 1458 1637 1810 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 2.30 2.30 2.30 1.40 1.40 1.40 Barometric Pressure Inches Mercury 29.98 29.98 29.98 29.98 29.98 29.98 Standard Orifice PressureH@ 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 6.5 6.5 6.0 5.5 6.0 6.0 Carbon Dioxide Concentration Mole Percent CO2 13.0 12.5 12.0 13.0 12.5 13.0 Volume of Gas Metered Actual Cubic Feet 36.450 37.175 37.752 35.023 34.871 34.051 Volume of Water Collected Milliliters 75 64 74 77 73 69 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.235 0.236 0.238 0.233 0.234 0.235 Weight of Solids Collected Milligrams 49.1 17.4 18.3 12.8 18.1 14.4 Area of Stack Square Feet 122.910 122.910 122.910 122.840 122.840 122.840 Avg. Sqr. Root Velocity Pressure Inches Water 0.7436 0.7301 0.7316 0.7462 0.7244 0.7059 Average Orifice Pressure(H) Inches Water 1.5 1.5 1.6 1.2 1.2 1.1 Average Stack Temperature Degrees F 325 327 329 326 329 332 Average Meter Temperature Degrees F 84 84 82 86 88 87


### Calculations Upper Upper Upper Upper Lower Lower Lower Lower RUN 1 RUN 2 RUN 3Average RUN 1 RUN 2 RUN 3Average

Volume of Gas Sampled Standard Dry 33.435 34.088 34.71734.080 33.411 33.136 32.41232.986 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.34 30.26 30.16 30.25 30.30 30.24 30.32 30.29
Water vapor in Stack Gas Percent 9.6 8.1 9.1 8.9 9.8 9.4 9.1 9.4
Average Stack Gas Velocity Feet per second 50.4 49.5 49.8 49.9 50.8 49.4 48.1 49.4

Stack Gas FlowRate Actual Cubic 371,961 364,991 367,546368,166374,150363,992354,752364,298 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic 252,157246,813 247,952248,974252,719244,870237,670245,086 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic 228,075226,772225,343226,730227,987221,863 216,023221,958 Feet Per Minute Stack Gas FlowRate Pounds of Dry Air 17,083 16,985 16,878 16,982 17,076 16,618 16,180 16,625 Per Minute Particulate Concentration Grains per Standard 0.023 0.008 0.008 0.013 0.006 0.008 0.007 0.007 Dry Cubic Foot Particulate Concentration Grains per Actual 0.014 0.005 0.005 0.008 0.004 0.005 0.004 0.004 Cubic Foot Particulate Emission Rate Pounds per Hour 44.2 15.3 15.7 25.1 11.5 16.0 12.7 13.4

Particulate Emission Rate Pounds per Million 0.046 0.016 0.016 0.026 0.011 0.016 0.013 0.014 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 964 959 986 969 1,031 970 945 982

Isokinetic Rate Percent 99.7 101.3 102.1 101.1 101.3 102.4 102.0 101.9

Post Test Meter Correction Factordimensionless 0.96 0.95 0.96 0.95 0.99 1.00 1.00 1.00

Percent Difference Allowed 5% 1.6 1.2 1.8 1.5 1.3 1.7 1.7 1.6



### Combined Particulate Emission Rate Pounds per Million 0.029 0.016 0.015 0.020 

### Allowable Btu (O2 F Factor) 0.3 0.3 0.3 0.3



## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT 2 STEADY STATE OPERATIONS

# ATTACHMENT 23 - Smith Report 23 Test Results

2008 SO2 Emissions Test

Smith Unit 1 Run Time Time Unit RM-6C (SO2)FUEL FLOWULTIMA TE ANALYSISMMBTU/HR NumberStarted Stopped Load lbs/mmBtu LBS BTU/LB

1 5/5/08 13:055/5/08 14:05 171 0.807 

## 150000 11047 1578.1 2 5/5/08 14:255/5/08 15:25 172 0.805 

## 157300 11352 1623.3 3 5/5/08 15:555/5/08 16:55 172 0.789 

## 151600 11405 1620.9 Avg 0.800

# ATTACHMENT 24 - Smith Report 24 Test Results

Title of Run Description Date Start TimeEnd TimeTest LoadAvg. Econ Gas Outlet CO Avg. Econ Gas Outlet O2 Avg. Econ Gas Outlet CO2 Avg. Econ Gas Outlet Temp 

## Military Military MW ppm % dry % dry DEGF 1 Full Load 1/31/2008 9:12 9:36 172 14.5 4.1 14.84 675 2 Full Load 1/31/2008 12:03 12:27 173 13.5 3.69 15.08 677 3 Full Load 2/1/2008 15:45 16:09 168 26.5 4.08 14.67 666.5 4 Full Load 2/1/2008 9:00 9:24 171 9 4.08 14.96 675.5 5 Full Load 2/1/2008 10:42 11:06 171 11 3.84 15.15 672.5 6 Full Load 2/4/2008 13:35 13:59 172 34 3.66 15.17 667 7 Full Load 2/5/2008 10:00 10:24 172 27 4.1 14.84 672 8 Full Load 2/5/2008 12:07 12:31 172 40 3.69 15.08 669 9 Full Load 2/5/2008 15:28 15:52 172 50.5 4.08 14.67 659.5 10 Full Load 2/6/2008 17:00 17:24 170 27 4.08 14.96 652 11 Full Load 2/6/2008 20:46 21:10 171 21.5 3.84 15.15 665 12 Full Load 2/6/2008 23:35 23:59 134 6.5 3.66 15.17 622 SNCR Baseline Test Results Summary

Smith Unit 1

### ATTACHMENT 25 - Smith Report 25 Test Results

LOWERLOWERLOWER UPPER UPPER UPPER

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/5/20085/5/20085/5/20085/5/20085/5/20085/5/2008 Sampling Time -Start Military 1305 1425 1555 1305 1425 1555 Sampling Time -Stop Military 1405 1525 1655 1405 1525 1655 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.75 0.75 0.75 0.75 0.75 0.75 Barometric Pressure Inches Mercury 29.80 29.80 29.80 29.80 29.80 29.80 Standard Orifice PressureH@ 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 9.5 9.0 7.0 7.0 6.0 5.5 Carbon Dioxide Concentration Mole Percent CO2 12.0 12.0 13.0 13.0 13.0 13.0 Volume of Gas Metered Actual Cubic Feet 41.780 46.140 44.040 34.274 40.514 39.624 Volume of Water Collected Milliliters 52 80 71 54 70 67 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.238 0.245 0.245 0.231 0.242 0.239 Weight of Solids Collected Milligrams 10.8 9.1 9.4 7.5 9.1 10.8 Area of Stack Square Feet 107.380 107.380 107.380 96.900 96.900 96.900 Avg. Sqr. Root Velocity Pressure Inches Water 0.8480 0.8796 0.8291 0.7927 0.8240 0.7989 Average Orifice Pressure (H) Inches Water 1.6 2.0 1.8 1.3 2.0 1.8 Average Stack Temperature Degrees F 302 303 303 312 315 312 Average Meter Temperature Degrees F 83 85 85 92 94 91 Flowrate 

### Calculations LOWER UPPERWeighted DUCT DUCTTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 39.766 43.804 41.721 32.201 37.956 37.316 41.764 35.824 77.588 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.30 30.28 30.36 30.36 30.32 30.30 30.31 30.33 30.31
Water vapor in Stack Gas Percent 5.8 7.9 7.4 7.3 8.0 7.8 7.0 7.7 7.0
Average Stack Gas Velocity Feet per second 56.5 59.0 55.5 53.3 55.6 53.9 57.0 54.3 57.0

Stack Gas Flow Rate Actual Cubic 364,239379,941 357,256310,082323,447313,089 367,145 315,539 682,684 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 251,901 262,301 246,736211,493 219,982213,599 253,646 215,025 468,671 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 237,295241,537228,438 196,020202,411 196,954 235,757 198,462 434,218 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 17,773 18,091 17,110 14,682 15,161 14,752 17,658 14,865 32,523 Per Minute Particulate Concentration Grains per Standard 0.004 0.003 0.003 0.004 0.004 0.004 0.004 0.004 0.004 Dry Cubic Foot Particulate Concentration Grains per Actual 0.003 0.002 0.002 0.002 0.002 0.003 0.002 0.002 0.002 Cubic Foot Particulate Emission Rate Pounds per Hour 8.5 6.6 6.8 6.0 6.4 7.5 7.3 6.7 14.0

Particulate Emission Rate Pounds per Million 0.011 0.008 0.007 0.008 0.007 0.008 0.009 0.008 0.009 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 794 844 932 800 885 890 857 858 857

Isokinetic Rate Percent 97.1 99.1 99.8 91.1 94.8 98.2 98.7 94.7 98.7

Post Test Meter Correction Check dimensionless 0.99 1.01 1.00 0.99 1.04 1.00 1.00 1.01 1.00

Percent Difference Allowed 5% Average 1.3 2.9 2.3 1.1 5.5 1.8 2.1 2.8

Combined Particulate Emission RatePounds per Million 0.0093 0.0076 0.0078 0.0082 Allowable Btu (O2 F Factor) 0.3 0.3 0.3 0.3



## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH -UNIT 1 SOOT BLOWING OPERATIONS

### ATTACHMENT 26 - Smith Report 26 Test Results

LOWERLOWERLOWER UPPER UPPER UPPER

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 5/6/20085/6/20085/6/20085/6/20085/6/20085/6/2008 Sampling Time -Start Military 0620 0745 0904 0620 0745 0904 Sampling Time -Stop Military 0720 0845 1004 0720 0845 1004 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.35 0.35 0.35 0.40 0.40 0.40 Barometric Pressure Inches Mercury 30.01 30.01 30.01 30.01 30.01 30.01 Standard Orifice PressureH@ 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 7.5 7.5 7.0 6.0 6.0 5.5 Carbon Dioxide Concentration Mole Percent CO2 13.0 13.0 13.5 13.0 13.5 13.0 Volume of Gas Metered Actual Cubic Feet 39.830 44.545 43.115 36.954 40.607 42.978 Volume of Water Collected Milliliters 58 76 74 78 86 82 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.238 0.242 0.239 0.232 0.245 0.245 Weight of Solids Collected Milligrams 4.1 4.1 1.5 6.4 5.6 6.3 Area of Stack Square Feet 107.380 107.380 107.380 96.900 96.900 96.900 Avg. Sqr. Root Velocity Pressure Inches Water 0.7979 0.8457 0.8493 0.8101 0.8071 0.8356 Average Orifice Pressure (H) Inches Water 1.6 1.8 1.8 1.6 2.0 2.1 Average Stack Temperature Degrees F 292 302 307 293 308 314 Average Meter Temperature Degrees F 68 75 81 70 79 86 Flowrate 

### Calculations LOWER UPPER Weighted DUCT DUCTTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 39.197 43.345 41.476 36.421 39.379 41.172 41.339 38.990 80.330 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.38 30.38 30.44 30.32 30.40 30.30 30.40 30.34 30.40
Water vapor in Stack Gas Percent 6.5 7.6 7.7 9.2 9.3 8.6 7.3 9.0 7.29
Average Stack Gas Velocity Feet per second 52.7 56.4 56.7 53.9 54.2 56.3 55.3 54.8 55.27

Stack Gas Flow Rate Actual Cubic 339,575 363,091 365,522313,356314,926327,391 356,063 318,558 674,620 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 239,302252,637252,713 220,550217,437224,164 248,217 220,717 468,934 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 223,720233,376233,134200,353 197,169204,951 230,077 200,824 430,901 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 16,757 17,480 17,462 15,006 14,768 15,351 17,233 15,042 32,274 Per Minute Particulate Concentration Grains per Standard 0.0016 0.0015 0.0006 0.0027 0.0022 0.0024 0.0012 0.0024 0.0012 Dry Cubic Foot Particulate Concentration Grains per Actual 0.0011 0.0009 0.0004 0.0017 0.0014 0.0015 0.0008 0.0015 0.0008 Cubic Foot Particulate Emission Rate Pounds per Hour 3.1 2.9 1.1 4.6 3.7 4.1 2.4 4.2 6.5

Particulate Emission Rate Pounds per Million 0.0035 0.0032 0.0012 0.0053 0.0043 0.0045 0.0026 0.0047 0.0026 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 880 918 951 876 862 926 916 888 916

Isokinetic Rate Percent 101.5 104.0 102.2 100.0 98.5 99.1 102.6 99.2

Post Test Meter Correction Check dimensionless 1.01 0.98 1.01 0.99 1.02 1.00 1.00 1.00

Percent Difference Allowed 5% Average 3.2 0.1 2.9 0.6 3.3 2.3 2.1 2.1

Combined Particulate Emission RatePounds per Million 0.0046 0.0038 0.0038 0.0041 Allowable Btu (O2 F Factor) 0.1 0.1 0.1 0.1 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH -UNIT 1 STEADY STATE OPERATIONS

# ATTACHMENT 27 - Smith Report 27 Test Results

Title of Run Description Date Start Time End Time Test LoadAvg. Econ Gas Outlet CO Avg. Econ Gas Outlet O2 Avg. Econ Gas Outlet CO2 Avg. Econ Gas Outlet Temp 

## Military Military MW ppm % dry % dry DEGF 1 Baseline; B Mill off 2/12/2008 2:25 PM 2:49 PM 167 6 4.825 13.27 655 2 Opt -1; B Mill off 2/13/2008 8:15 AM 8:39 AM 167 11 3.825 15.11 686 3 Opt -2 2/13/2008 11:26 AM 11:50 AM 199 15 4.035 15.01 691 4 Opt - 3 2/13/2008 1:54 PM 2:18 PM 198 26 3.49 15.59 686 5 Perf - 1 2/14/2008 8:41 AM 9:05 AM 202 8 3.76 15.23 690 6 Perf - 2 2/14/2008 2:25 PM 11:46 AM 203 27 3.615 15.12 695 7 Perf - 3 2/14/2008 2:31 PM 2:55 PM 203 32 3.565 15.04 698 8 Perf - 4 2/15/2008 8:16 AM 8:40 AM 204 15 3.715 15.14 702 9 Perf - 5 2/18/2008 5:11 AM 5:35 AM 78 16 7.01 12.1 465 SNCR Baseline Test Results Summary

Smith Unit 2

# ATTACHMENT 28 - Smith Report 28 Test Results

2008 SO2 Emissions Test

Smith Unit 2 2008 Run Time Time Unit RM-6C (SO2)FUEL FLOWULTIMA TE ANALYSIS MMBTU/HR NumberStarted Stopped Load lbs/mmBtu LBS BTU/LB

1 3/17/08 14:503/17/08 15:50 199 1.500 

## 197900 11552 2017.2 2 3/17/08 16:103/17/08 17:10 200 1.400 

## 181300 11034 2000.5 3 3/18/08 8:11 3/18/08 9:11 200 1.400 

## 187300 11497 2153.4 Avg 1.433ATTACHMENT 29 - Smith Report 29 Test Results

Title of Run RUN 1 UPPER RUN 2

UPPER RUN 3

UPPER RUN 1

LOWER RUN 2

LOWER RUN 3

LOWER Date Month/Day/Year 3/17/20083/17/20083/17/20083/17/20083/17/20083/17/2008 Sampling Time -Start Military 1230 1436 1610 1230 1436 1610 Sampling Time -Stop Military 1330 1536 1710 1330 1536 1710 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 2.30 2.30 2.30 1.40 1.40 1.40 Barometric Pressure Inches Mercury 30.28 30.28 30.28 30.28 30.28 30.28 Standard Orifice PressureH@ 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 9.50 8.50 7.00 9.00 10.00 9.50 Carbon Dioxide Concentration Mole Percent CO2 12.5 11.5 12.50 11.0 10.00 10.50 Volume of Gas Metered Actual Cubic Feet 42.843 42.028 41.915 48.160 40.900 39.900 Volume of Water Collected Milliliters 65 59 74 74 64 54 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.244 0.237 0.237 0.236 0.236 0.246 Weight of Solids Collected Milligrams 31 24.9 32.9 17.2 27.1 21.6 Area of Stack Square Feet 122.910 122.910 122.910 122.840 122.840 122.840 Avg. Sqr. Root Velocity Pressure Inches Water 0.8178 0.8153 0.8117 0.9942 0.8342 0.8090 Average Orifice Pressure (H) Inches Water 2.1 1.9 1.8 2.2 1.5 1.4 Average Stack Temperature Degrees F 327 330 332 321 323 325 Average Meter Temperature Degrees F 76 75 75 78 78 79 Flowrate 

### Calculations Weighted Upper SideLower SideTOTAL or

RUN 1 UPPER RUN 2

UPPER RUN 3

UPPER RUN 1

LOWER RUN 2

LOWER RUN 3

LOWERAVERAGEAVERAGECOMBINE D AVERAGE
Volume of Gas Sampled Standard Dry 40.355 39.589 39.464 47.147 39.982 38.948 41.639 39.465 81.104 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.38 30.18 30.28 30.12 30.00 30.06 30.24 30.03 30.24

Water vapor in Stack Gas Percent 7.0 6.6 8.1 6.9 7.0 6.1 7.1 6.6 7.1

Average Stack Gas Velocity Feet per second 55.0 55.0 54.9 66.9 56.3 54.5 57.9 55.4 57.9

Stack Gas Flow Rate Actual Cubic 405,282 405,686 405,051 492,772 414,891 401,874 427,198 408,382835,580 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 276,598 275,798 274,764 338,387 284,165 274,396 291,387 279,280570,667 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 257,105 257,719 252,480 315,107 264,254 257,586 270,603 260,920531,523 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 19,257 19,303 18,911 23,602 19,793 19,293 20,268 19,543 39,811 Per Minute Particulate Concentration Grains per Standard 0.012 0.010 0.013 0.006 0.010 0.009 0.010 0.009 0.010 Dry Cubic Foot Particulate Concentration Grains per Actual 0.008 0.006 0.008 0.004 0.007 0.005 0.006 0.006 0.006 Cubic Foot Particulate Emission Rate Pounds per Hour 26.1 21.4 27.8 15.2 23.6 18.9 22.6 21.2 43.9

Particulate Emission Rate Pounds per Million 0.030 0.023 0.027 0.014 0.028 0.022 0.023 0.025 0.023 ALLOWABLE Btu (O2 F Factor) 0.300 Heat Input (O2 F Factor) Million Btu per Hour 860 938 1,030 1,101 846 862 982 854 982

Isokinetic Rate Percent 99.0 102.7 104.5 100.8 102.0 93.8 101.8 97.9 101.8

Post Test Meter Correction Checkdimensionless 0.95 0.93 0.91 0.97 0.96 0.96 0.94 0.96 0.94

Percent Difference Allowed 5% Average 1.3 -1.2 -2.5 -0.9 -2.1 -2.3 -0.8 -2.2 -1.5 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT 2 SOOT BLOWINGATTACHMENT 30 - Smith Report 30 Test Results

Title of Run RUN 1 UPPER RUN 2

UPPER RUN 3

UPPER RUN 1

LOWER RUN 2

LOWER RUN 3

LOWER Date Month/Day/Year 3/18/20083/18/20083/18/20083/18/20083/18/20083/18/2008 Sampling Time -Start Military 0632 0810 0940 0632 0810 0940 Sampling Time -Stop Military 0732 0910 1040 0732 0910 1040 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 2.40 2.40 2.40 1.40 1.40 1.40 Barometric Pressure Inches Mercury 30.25 30.25 30.25 30.25 30.25 30.25 Standard Orifice PressureH@ 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 7.00 7.50 6.50 8.50 9.00 9.00 Carbon Dioxide Concentration Mole Percent CO2 13.0 12.5 12.0 10.00 11.00 11.00 Volume of Gas Metered Actual Cubic Feet 43.326 39.302 39.532 43.000 42.600 42.200 Volume of Water Collected Milliliters 61 75 64 80 58 64 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.246 0.237 0.235 0.246 0.245 0.246 Weight of Solids Collected Milligrams 24.2 44.5 31.7 42.7 51.0 27.9 Area of Stack Square Feet 122.910 122.910 122.910 122.840 122.840 122.840 Avg. Sqr. Root Velocity Pressure Inches Water 0.7868 0.7547 0.7748 0.8121 0.7878 0.8042 Average Orifice Pressure (H) Inches Water 2.0 1.7 1.7 1.7 1.7 1.7 Average Stack Temperature Degrees F 321 328 332 313 317 320 Average Meter Temperature Degrees F 70 72 74 73 74 76 Flowrate 

### Calculations Weighted UPPER LOWERTOTAL or

RUN 1 UPPER RUN 2

UPPER RUN 3

UPPER RUN 1

LOWER RUN 2

LOWER RUN 3

LOWERAVERAGEAVERAGECOMBINE D AVERAGE
Volume of Gas Sampled Standard Dry 41.189 37.181 37.271 42.455 41.930 41.386 38.547 41.924 80.471 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.36 30.30 30.18 29.94 30.12 30.12 30.28 30.06 30.28

Water vapor in Stack Gas Percent 6.5 8.7 7.5 8.1 6.1 6.8 7.6 7.0 7.6

Average Stack Gas Velocity Feet per second 52.6 51.0 52.5 54.7 52.8 54.1 52.0 53.8 52.0

Stack Gas Flow Rate Actual Cubic 388,111 376,090 386,956 402,811 389,148 398,567 383,719 396,842780,561 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 266,932 256,212 262,150 279,236 268,201 273,648 261,765 273,695535,460 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 249,537 233,995 242,546 256,487 251,806 255,081 242,026 254,458496,484 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 18,690 17,526 18,167 19,211 18,860 19,106 18,128 19,059 37,187 Per Minute Particulate Concentration Grains per Standard 0.009 0.018 0.013 0.015 0.019 0.010 0.014 0.015 0.014 Dry Cubic Foot Particulate Concentration Grains per Actual 0.006 0.011 0.008 0.010 0.012 0.007 0.008 0.010 0.008 Cubic Foot Particulate Emission Rate Pounds per Hour 19.4 37.0 27.2 34.1 40.4 22.7 27.9 32.4 60.2

Particulate Emission Rate Pounds per Million 0.019 0.040 0.027 0.036 0.046 0.025 0.029 0.036 0.029 

### Allowable Btu (O2 F Factor) 0.100 Heat Input (O2 F Factor) Million Btu per Hour 1,018 920 1,025 934 880 891 988 901 988

Isokinetic Rate Percent 102.4 106.2 104.5 102.7 104.1 100.6 104.4 102.5 104.4

Post Test Meter Correction Checkdimensionless 0.92 0.92 0.92 0.97 0.97 0.98 0.92 0.97 0.92

Percent Difference Allowed 5% Average -1.7 -1.5 -1.6 -1.5 -1.1 -0.2 -1.6 -0.9 -1.62 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT 2 STEADY STATE

# ATTACHMENT 31 - Smith Report 31 Test Results

2009 SO2 Emissions Test

Smith Unit 1 2009 Run Unit FUEL FLOWULTIMA TE ANALYSIS MMBTU/HR Number Load LBS BTU/LB

1 172 

## 142000 11651 1654.4 2 172 

## 144000 11638 1675.9 3 172 

## 144000 11619 1673.1 Avg 1.623

Time Time RM-6C (SO2) Started Stopped lbs/mmBtu

5/18/09 10:10 5/18/09 11:10 1.620 5/18/09 11:55 5/18/09 12:55 1.614 5/18/09 13:25 5/18/09 14:25 1.635ATTACHMENT 32 - Smith Report 32 Test Results

LOWER LOWER LOWER UPPER UPPER UPPER

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day /Year 5/18/20095/18/20095/18/20095/18/20095/18/20095/18/2009 Sampling Time -Start Military 1110 1255 1425 1110 1255 1425 Sampling Time -Stop Military 1220 1403 1534 1220 1403 1534 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.65 0.65 0.65 0.75 0.75 0.75 Barometric Pressure Inches Mercury 30.04 30.04 30.04 30.04 30.04 30.04 Standard Orifice PressureH@ Inches Water 2.211 2.211 2.211 2.040 2.040 2.040 Meter Correction Factor dimensionless 0.927 0.927 0.927 0.975 0.975 0.975 Oxygen Concentration Mole Percent O2 7.00 7.00 6.50 7.50 6.50 6.50 Carbon Dioxide Concentration Mole Percent CO2 11.5 11.0 11.5 12.0 12.0 12.0 Volume of Gas Metered Actual Cubic Feet 40.795 44.455 48.254 44.357 46.899 47.894 Volume of Water Collected Milliliters 65.3 71.5 86.0 74.3 91.7 88.0 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.238 0.248 0.249 0.240 0.250 0.250 Weight of Solids Collected Milligrams 8.8 7.3 8.9 16.9 12.6 9.0 Area of Stack Square Feet 107.380 107.380 107.380 96.900 96.900 96.900 Avg. Sqr. Root Velocity Pressure Inches Water 0.7640 0.7658 0.8157 0.8845 0.8799 0.8992 Average Orifice Pressure (H) Inches Water 1.6 1.9 2.2 2.0 2.3 2.4 Average Stack Temperature Degrees F 304 306 306 311 313 312 Average Meter Temperature Degrees F 73 74 76 76 77 79


### Calculations LOWER LOWER LOWER UPPER UPPER UPPER LOWER UPPER Total or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 37.760 41.083 44.480 43.028 45.368 46.190 41.107 44.862 85.969 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.12 30.04 30.10 30.22 30.18 30.18 30.09 30.19 30.14

Water vapor in Stack Gas Percent 7.5 7.6 8.3 7.5 8.7 8.2 7.8 8.1 8.0 0 0 0 Average Stack Gas Velocity Feet per second 51.2 51.4 54.8 59.4 59.3 60.5 52.5 59.7 56.1

Stack Gas FlowRate Actual Cubic 329,599 331,146353,046 345,144 344,949 352,032 337,930347,375 685,305 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic 228,909 229,553 244,564 237,813 236,941 241,994234,342238,916473,258 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic 211,678 212,172224,163 219,937 216,356 222,079216,004219,457435,462 Feet Per Minute Stack Gas FlowRate Pounds of Dry Air 15,855 15,892 16,790 16,473 16,205 16,634 16,179 16,437 32,616 Per Minute Particulate Concentration Grains per Standard 0.004 0.003 0.003 0.006 0.004 0.003 0.003 0.004 0.004 Dry Cubic Foot Particulate Concentration Grains per Actual 0.002 0.002 0.002 0.004 0.003 0.002 0.002 0.003 0.002 Cubic Foot Particulate Emission Rate Pounds per Hour 6.5 5.0 5.9 11.4 7.9 5.7 5.8 8.3 14.2

Particulate Emission Rate Pounds per Million 0.008 0.006 0.006 0.013 0.009 0.006 0.007 0.009 0.008 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 864 866 948 865 915 939 892 906 1,798

Isokinetic Rate Percent 103.3 103.3 105.0 100.6 99.3 98.5 103.9 99.5

Post Test Meter Correction Check dimensionless 0.92 0.92 0.91 0.99 1.00 1.00 0.92 1.00

Percent Difference Allowed 5% Average -0.9 -0.5 -1.7 1.4 2.3 2.5 -1.0 2.1

Combined Particulate Emission RatePounds per Million 0.0104 0.0072 0.0062 0.0079 Allowable Btu (O2 F Factor) 0.3 0.3 0.3 0.3 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH -UNIT 1 SOOT BLOWING OPERATIONSATTACHMENT 33 - Smith Report 33 Test Results

SIDE ASIDE ASIDE A SIDE B SIDE B SIDE B

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day/Year 8/19/20098/19/20098/19/20098/19/20098/19/20098/19/2009 Sampling Time -Start Military 0818 0944 1110 0818 0944 1110 Sampling Time -Stop Military 0926 1051 1218 0926 1051 1218 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 0.85 0.75 0.80 0.50 0.50 0.50 Barometric Pressure Inches Mercury 30.05 30.05 30.05 30.05 30.05 30.05 Standard Orifice PressureH@ Inches Water 2.199 2.199 2.199 2.080 2.080 2.080 Meter Correction Factor dimensionless 0.985 0.985 0.985 1.051 1.051 1.051 Oxygen Concentration Mole Percent O2 7.5 7.0 7.5 7.5 7.5 7.0 Carbon Dioxide Concentration Mole Percent CO2 12.5 12.5 12.5 13.0 13.0 13.0 Volume of Gas Metered Actual Cubic Feet 49.168 49.549 49.035 32.660 38.300 39.330 Volume of Water Collected Milliliters 113.3 97.7 112.9 75.1 85.2 85.4 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.247 0.245 0.248 0.248 0.248 0.249 Weight of Solids Collected Milligrams 4.7 5.8 7.8 4.3 8.4 6.5 Area of Stack Square Feet 96.900 96.900 96.900 107.380 107.380 107.380 Avg. Sqr. Root Velocity Pressure Inches Water 0.8874 0.8845 0.8944 0.6777 0.8199 0.8286 Average Orifice Pressure (H) Inches Water 2.1 2.1 2.0 1.4 2.1 2.2 Average Stack Temperature Degrees F 301 310 312 318 322 323 Average Meter Temperature Degrees F 87 94 95 83 86 87 Flowrate 

## Calculations Weighted Side A Side BTOTAL or RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE

Volume of Gas Sampled Standard Dry 47.175 46.948 46.388 33.643 39.302 40.280 46.837 37.741 84.579 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.30 30.28 30.30 30.38 30.38 30.36 30.29 30.37 30.33

Water vapor in Stack Gas Percent 10.2 8.9 10.3 9.5 9.3 9.1 9.8 9.3 9.5

Average Stack Gas Velocity Feet per second 59.4 59.4 60.3 45.8 55.5 56.1 59.7 52.5 56.1

Stack Gas Flow Rate Actual Cubic 345,471 345,560350,804 295,002 357,693 361,477347,278 338,057685,336 Feet Per Minute Stack Gas Flow Rate Standard Wet Cubic 241,192238,509241,415 201,291 242,674 245,220240,372229,728470,100 Feet Per Minute Stack Gas Flow Rate Standard Dry Cubic 216,695217,230216,601 182,152 220,204 222,968216,842208,442425,284 Feet Per Minute Stack Gas Flow Rate Pounds of Dry Air 16,230 16,271 16,223 13,643 16,493 16,700 16,241 15,612 31,854 Per Minute Particulate Concentration Grains per Standard 0.002 0.002 0.003 0.002 0.003 0.002 0.002 0.003 0.002 Dry Cubic Foot Particulate Concentration Grains per Actual 0.001 0.001 0.002 0.001 0.002 0.002 0.001 0.002 0.001 Cubic Foot Particulate Emission Rate Pounds per Hour 2.8 3.5 4.8 3.1 6.2 4.7 3.7 4.7 8.4

Particulate Emission Rate Pounds per Million 0.003 0.004 0.006 0.004 0.007 0.005 0.004 0.006 0.005 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 852 886 852 716 866 910 864 831 848

Isokinetic Rate Percent 105.6 106.6 103.1 98.5 95.2 95.6 105.1 96.4

Combined Particulate Emission RatePounds per Million 0.0038 0.0056 0.0054 0.0049 Allowable Btu (O2 F Factor) 0.1 0.1 0.1 0.1 

## TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT 1 STEADY STATE OPERATIONS

# ATTACHMENT 34 - Smith Report 34 Test Results

2009 SO2 Emissions Test

Smith Unit 2 2009 Run Unit FUEL FLOW ULTIMA TE ANALYSISMMBTU/HR Number Load LBS BTU/LB

1 205 

## 164000 11642 1909.3 2 205 

## 168000 11549 1940.2 3 205 

## 164000 11505 1886.8 Avg 1.597

Time Time RM-6C (SO2) Started Stopped lbs/mmBtu

5/19 10:14 5/19 11:14 1.564 5/19 11:45 5/19 12:45 1.601 5/19 13:10 5/19 14:10 1.625ATTACHMENT 35 - Smith Report 35 Test Results

LOWER LOWER LOWER UPPER UPPER UPPER

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day /Year 5/19/20095/19/20095/19/20095/19/20095/19/20095/19/2009 Sampling Time -Start Military 1115 1245 1410 1115 1245 1410 Sampling Time -Stop Military 1222 1351 1517 1222 1351 1517 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 2.50 2.50 2.50 2.75 2.75 2.75 Barometric Pressure Inches Mercury 30.09 30.09 30.09 30.09 30.09 30.09 Standard Orifice PressureH@ Inches Water 2.211 2.211 2.211 2.040 2.040 2.040 Meter Correction Factor dimensionless 0.927 0.927 0.927 0.975 0.975 0.975 Oxygen Concentration Mole Percent O2 6.00 6.50 6.00 6.00 6.00 5.00 Carbon Dioxide Concentration Mole Percent CO2 12.0 11.5 11.0 11.5 11.5 11.0 Volume of Gas Metered Actual Cubic Feet 46.153 49.495 49.927 37.806 41.346 44.001 Volume of Water Collected Milliliters 69.6 79.2 67.1 62.4 66.2 65.0 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.238 0.248 0.250 0.240 0.250 0.249 Weight of Solids Collected Milligrams 36.4 14.1 12.3 37.0 22.0 45.2 Area of Stack Square Feet 122.840 122.840 122.840 122.910 122.910 122.910 Avg. Sqr. Root Velocity Pressure Inches Water 0.8623 0.8482 0.8416 0.7846 0.7852 0.8441 Average Orifice Pressure (H) Inches Water 1.9 2.2 2.2 1.6 1.8 2.0 Average Stack Temperature Degrees F 328 331 333 339 342 344 Average Meter Temperature Degrees F 75 77 80 77 81 85 

### Calculations LOWER UPPERTOTAL OR RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 42.697 45.606 45.810 36.596 39.741 42.033 44.704 39.457 84.161 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.16 30.10 30.00 30.08 30.08 29.96 30.09 30.04 30.06

Water vapor in Stack Gas Percent 7.1 7.6 6.4 7.4 7.3 6.8 7.0 7.2 7.1

Average Stack Gas Velocity Feet per second 58.4 57.6 57.2 53.6 53.7 57.8 57.7 55.0 56.4

Stack Gas FlowRate Actual Cubic 430,149 424,652 421,480 395,043 395,933 426,413 425,427405,796 831,223 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic 291,508 286,788 284,071 264,114 263,741 283,549287,456270,468 557,924 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic 270,735 265,117 265,748 244,491 244,565 264,310267,200251,122 518,322 Feet Per Minute Stack Gas FlowRate Pounds of Dry Air 20,278 19,857 19,905 18,312 18,318 19,797 20,013 18,809 38,822 Per Minute Particulate Concentration Grains per Standard 0.013 0.005 0.004 0.016 0.009 0.017 0.007 0.014 0.010 Dry Cubic Foot Particulate Concentration Grains per Actual 0.008 0.003 0.003 0.010 0.005 0.010 0.005 0.008 0.006 Cubic Foot Particulate Emission Rate Pounds per Hour 30.5 10.8 9.4 32.6 17.9 37.5 16.9 29.3 46.2

Particulate Emission Rate Pounds per Million 0.026 0.010 0.008 0.031 0.017 0.030 0.014 0.026 0.020 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 1,184 1,121 1,162 1,069 1,070 1,234 1,156 1,124 2,280

Isokinetic Rate Percent 104.5 105.0 103.5 97.6 97.6 96.3 104.3 97.2

Post Test Meter Correction Check dimensionless 0.90 0.89 0.90 1.03 1.02 1.01 0.90 1.02

Percent Difference Allowed 5% Average -2.8 -3.4 -3.0 5.0 4.1 3.9 -3.0 4.3

Combined Particulate Emission RatePounds per Million 0.0281 0.0132 0.0193 0.0202 Allowable Btu (O2 F Factor) 0.3 0.3 0.3 0.3 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT NO. 2 SOOT BLOWING CONDITIONATTACHMENT 36 - Smith Report 36 Test Results

LOWER LOWER LOWER UPPER UPPER UPPER

Title of Run RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3 Date Month/Day /Year 5/20/20095/20/20095/20/20095/20/20095/20/2009 5/20/2009 Sampling Time -Start Military 0805 0932 1055 0805 0932 1055 Sampling Time -Stop Military 0912 1039 1202 0912 1039 1202 Number of Ports dimensionless 5 5 5 5 5 5 Number of Points per Port dimensionless 6 6 6 6 6 6 Oxygen F Factor SDCF/MMBtu 9,780 9,780 9,780 9,780 9,780 9,780 Stack Static Pressure Inches Water 1.75 1.75 1.75 2.10 2.10 2.10 Barometric Pressure Inches Mercury 29.98 29.98 29.98 29.98 29.98 29.98 Standard Orifice PressureH@ Inches Water 2.211 2.211 2.211 2.040 2.040 2.040 Meter Correction Factor dimensionless 0.927 0.927 0.927 0.975 0.975 0.975 Oxygen Concentration Mole Percent O2 6.50 7.00 7.00 6.50 7.50 6.00 Carbon Dioxide Concentration Mole Percent CO2 11.5 11.0 11.0 12.0 12.0 12.0 Volume of Gas Metered Actual Cubic Feet 41.962 42.854 46.043 44.807 44.287 43.824 Volume of Water Collected Milliliters 64.1 69.6 73.8 75.0 77.3 76.5 Sampling Time Minutes 60 60 60 60 60 60 Nozzle Diameter Inches 0.238 0.240 0.248 0.250 0.250 0.249 Weight of Solids Collected Milligrams 11.2 54.5 12.1 15.9 17.0 16.1 Area of Stack Square Feet 122.840 122.840 122.840 122.910 122.910 122.910 Avg. Sqr. Root Velocity Pressure Inches Water 0.7985 0.7874 0.7913 0.8492 0.8354 0.8342 Average Orifice Pressure (H) Inches Water 1.6 1.7 1.9 2.1 2.0 2.0 Average Stack Temperature Degrees F 322 326 329 333 337 340 Average Meter Temperature Degrees F 73 76 77 77 81 83 

### Calculations LOWER UPPERTOTAL OR RUN 1 RUN 2 RUN 3 RUN 1 RUN 2 RUN 3AVERAGEAVERAGEAVERAGE
Volume of Gas Sampled Standard Dry 38.762 39.359 42.271 43.302 42.427 41.846 40.131 42.525 82.656 Cubic Feet Molecular Wt. of Stack Gas (dry) LB/LB-MOLE 30.10 30.04 30.04 30.18 30.22 30.16 30.06 30.19 30.12

Water vapor in Stack Gas Percent 7.2 7.7 7.6 7.5 7.9 7.9 7.5 7.8 7.6 0 0 0 Average Stack Gas Velocity Feet per second 54.1 53.5 53.9 57.8 57.0 57.1 53.8 57.3 55.6

Stack Gas FlowRate Actual Cubic 398,390 394,474397,175 426,530 420,550 421,136396,680422,739 819,418 Feet Per Minute Stack Gas FlowRate Standard Wet Cubic 270,574 266,708267,445 285,802 280,557 279,964268,242282,107 550,350 Feet Per Minute Stack Gas FlowRate Standard Dry Cubic 251,033 246,215 247,136 264,258 258,397 257,781 248,128260,145 508,273 Feet Per Minute Stack Gas FlowRate Pounds of Dry Air 18,802 18,441 18,510 19,793 19,354 19,308 18,585 19,485 38,070 Per Minute Particulate Concentration Grains per Standard 0.004 0.021 0.004 0.006 0.006 0.006 0.010 0.006 0.008 Dry Cubic Foot Particulate Concentration Grains per Actual 0.003 0.013 0.003 0.004 0.004 0.004 0.006 0.004 0.005 Cubic Foot Particulate Emission Rate Pounds per Hour 9.6 45.0 9.3 12.8 13.7 13.1 21.3 13.2 34.5

Particulate Emission Rate Pounds per Million 0.009 0.045 0.009 0.011 0.013 0.012 0.021 0.012 0.017 Btu (O2 F Factor) Heat Input (O2 F Factor) Million Btu per Hour 1,061 1,005 1,008 1,117 1,016 1,127 1,025 1,087 2,112

Isokinetic Rate Percent 102.3 104.2 104.4 98.5 98.7 98.3 103.6 98.5

Post Test Meter Correction Check dimensionless 0.91 0.90 0.90 1.00 1.00 1.00 0.90 1.00

Percent Difference Allowed 5% Average -2.1 -2.3 -2.7 2.5 2.7 3.0 -2.4 2.7

Combined Particulate Emission RatePounds per Million 0.0102 0.0291 0.0104 0.0166 Allowable Btu (O2 F Factor) 0.1 0.1 0.1 0.1 

### TABLE I. PARTICULATE EMISSIONS TEST RESULTS

GULF POWER COMPANY PLANT SMITH - UNIT NO. 2 STEADY STATE CONDITION