Process Information

1 Name of legal owner of facility:

Gulf Power Company

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

Gulf Power Company

3 Address of ___ legal owner or ____ operator:

One Energy Place

Pensacola, FL 32520 - 0100

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

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

Lansing Smith

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

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

643

5 Complete street address of facility (physical location):

4300 County Road 2300

Southport, FL 32409

6 Provide mailing address if different:

One Energy Place

Pensacola, FL 32520 - 0350

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

Sarah Markham, Engineer II

8 Contact(s) telephone number(s):

(205) 257-6780

and e-mail address(es):

sasander@southernco.com

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

____ Yes _X__ No ____ Don't know

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

__X_ coal __X__ oil (including pet coke) ___ natural gas

_X_ other (specify in question 14 below)

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

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

__X_ coal __X__ oil (including pet coke) ___ natural gas

_X_ other (specify in question 14 below)

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

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

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

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

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

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

 that recycle materials) (%_____)

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

____ petroleum coke (% _____)

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

_X__ distillate (% _96.8_)

_X__ other (specify on spec used oil_) (% _3.2_)

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

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

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

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

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

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

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

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

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

material? ____ Yes ____ No _X__ Neither

Explain: Until the regulations are finalized, we cannot determine with certainty whether we would use these other materials 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
15 Identification (or designation) of all coal- and oil-fired steam generating units (boilers) (as defined by Clean Air Act section 112(a)(8))

located at this facility. Boiler ID

6

coal rank or type of oil) Original design fuel (i.e., 

r

Design heat input, 

(MMBtu/hr)7, q

Present maximum heat 

input, (MMBtu/hr)8,p

MWe Gross capacity

summer o

MWe Net Capacity

summer 

n

efficiency (%, HHV) 

Original design gross 

m

Present operating gross 

efficiency (%, HHV) 

l

Design steam pressure 

(psig) 

k

Operating steam pressure 

(psig) 

j

Design steam temperature 

(

oF) I 

Operating steam 

temperature (

oF) 

h

Design steam reheat 

temperature (

oF)9, g

Operating steam reheat 

temperature (

oF)10, f

Fuel11, e

Hours/year operated12, d

Average annual capacity 

factor for the past 3 years 

c

Applicable NSPS b 

Estimated year of 

retirement13, 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.
16 For each boiler noted in Part I, question 15, provide the following information for each current emission control device installed

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

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

Boiler ID14 Type15 NOx control16 SO2 control17 PM control18 Other control19

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

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

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

etc.).

Name Telephone Address

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

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

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

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

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

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

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

Boiler ID22

Demonstration 

activity actual startup date

Demonstration 

activity projected 

start-up date

Demonstration 

activity end-date or 

projected end-date

Type of control (e.g., 

sorbent and type; 

chemical additive23)

Desired HAP emission 

reduction (%) or 

emission rate

Coal rank(s) in use

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

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

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

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

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

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

"inlet" and "outlet" are).

Boiler ID25 Actual start-up date Expected or projected 

start-up date

Type of control (e.g., 

sorbent and type; 

chemical additive)26

Guaranteed HAP 

emission reduction 

(%) or emission rate

Sorbent or additive 

feed rate on which 

guarantee is based

Coal rank(s) upon 

which guarantee is 

based

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

PM28 PM10

(29) PM2.5(30) SO2

HCl and/or 

HF

HCN

Metal 

HAP31 Hg CO

Other 

organics 

(specify)

Other 

pollutant 

(specify)

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- hr 

daily 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- hr 

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

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

Other organics 

(specify)

Other 

pollutant 

(specify)

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

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

Please elaborate.

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

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

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

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

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

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

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

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

PM36 PM10 PM2.5 SO2

HCl 

and/or 

HF

HCN

Metal 

HAP37 Hg CO

Other 

organics 

(specify)

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

Facility Name/Unit No.: N/A

Retrofit to existing boiler? 

Installation on a new boiler?

Total Capital Investment: $ -

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

Note: "N/A" means not applicable.

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

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

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

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

Lansing Smith

1b Plant 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.
2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

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

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

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

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 SUNNYSIDE TRAIN 0.86 14.42 12,489

3,949 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.2 17.07 12,123

3,847 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.27 12.08 13,025

3,948 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.36 13.7 12,657

3,922 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.27 11.77 13,056

4,012 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.24 12.85 12,838

3,975 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.33 12.87 12,898

4,034 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.29 13.67 12,667

3,715 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.34 11.99 13,044

4,077 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.3 12.73 12,880

4,049 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.26 12.35 12,920

4,122 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.29 11.06 13,212

4,126 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.24 10.99 13,161

4,175 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 1.34 11.6 13,149

4,119 1, 2 UT CARBON UPPER SUNNYSIDE TRAIN 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.
2 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information,

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

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 

method
3 For each individual coal and oil shipment received during the preceding 12 calendar months, provide the following information44

, as

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

Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium

09-303 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 0.9 UT 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 5.3 COLOMBIA 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 1.0 CO 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 1.0 IL 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 1.0 IL 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 0.9 CO 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 0.8 UT 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 1.2 UT 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 5.4 COLOMBIA 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 5.8 COLOMBIA 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 0.9 CO 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 1.0 IL 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 2.5 WV 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 3.4 WV 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 1.1 UT 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 0.9 UT 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 5.2 COLOMBIA 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 0.9 CO 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 0.9 UT 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 1.0 IL 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 1.2 UT 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 2.7 WV 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.

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

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

analysis requirement can be bypassed by the respondent.

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

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

____ permit requirements

____ contractual obligations

____ standard operational procedures

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

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

____ Fuel supplier (name and address)

_X__ Other (name and address)

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

Alabama Power Company, General Services Laboratory

744 Highway 87, GSC #8

Calera, AL 35040

6 Name and address of laboratory performing analyses:

Alabama Power Company, General Services Laboratory

744 Highway 87, GSC #8

Calera, AL 35040

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

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

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

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

these data.

Proximate and ultimate analysis, trace metals, and ash minerals are provided for coal shipments reported in Question 3.

Total 

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

09-303 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 1.94 0.02018 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 1.47 0.03578 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 1.27 0.01981 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 0.93 0.03108 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 2.46 0.02948 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 1.13 0.01657 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 1.58 0.04447 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 1.54 0.03871 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 1.2 0.01991 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 2.46 0.02948 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 1.1 0.06211 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 0.95 0.05926 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 1.07 0.02019 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 2.23 0.02931 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 1.71 0.05069 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 2.06 0.03026 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 0.99 0.03776 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 1.17 0.01657 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
8a What emission test report(s), parametric monitoring data, and other data or monitoring are available for the boilers noted in Part I,

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

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

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

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

Report 1 Unit 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
8b Please indicate the date(s) and types (e.g., stack, fuel, parametric, etc.) of the test(s) and the constituents (including criteria and hazardous

air pollutants) sampled for:

Report 1 Date: 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
8c Do 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 6/1/2005 Particulate Inlet Test

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

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

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

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

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

Yes __X_ No ____ If yes, please list the unit's complete control configuration at time of testing in a similar format to Part I, question 16.

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 - fired 1) 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 - fired 1) 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 - 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.

8g Do 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.
9 What 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. 

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

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

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

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

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

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

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

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

01/01/05 - 12/31/09 Unit 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.
12 For each boiler noted in Part I, question 15, provide the following information:

Test Report Date of test PM49 SO2 HCl/HF/HCN Metal HAP50 Hg51 CO

Other organics 

(specify)

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 10 N/A N/A N/A N/A N/A N/A

Unit 1 Report 11 5/10/2006 N/A See Attachment 11 N/A N/A N/A N/A N/A

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

Report 13 5/11/2006 See Attachment 13 N/A N/A N/A N/A N/A N/A

Unit 2 Report 14 5/22/2006 N/A See Attachment 14 N/A N/A N/A N/A N/A

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

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

Unit 1 Report 17 6/11/2007 N/A See Attachment 17 N/A N/A N/A N/A N/A

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

Report 19 6/12/2007 See Attachment 19 N/A N/A N/A N/A N/A N/A

Unit 2 Report 20 5/8/2007 N/A See Attachment 20 N/A N/A N/A N/A N/A

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

Report 22 5/8/2007 See Attachment 22 N/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 23 N/A

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

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

Report 26 5/6/2008 See Attachment 26 N/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 27 N/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 29 N/A N/A N/A N/A N/A N/A

Report 30 3/18/2008 See Attachment 30 N/A N/A N/A N/A N/A N/A

Unit 1 Report 31 8/18/2009 N/A See Attachment 31 N/A N/A N/A N/A N/A

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

Report 33 8/19/2009 See Attachment 33 N/A N/A N/A N/A N/A N/A

Unit 2 Report 34 5/19/2009 N/A See Attachment 34 N/A N/A N/A N/A N/A

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

Report 36 5/20/2009 See Attachment 36 N/A N/A N/A N/A N/A N/A

Note: "N/A" means not applicable.

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

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

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

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

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

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

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

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

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

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

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

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

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

Boiler ID

Emissions test results (indicate format of emission data)47,48
ATTACHMENT 1 - Smith Report 1 Test Results

2005 SO2 Emissions Test (Based on RATA Results)

Run Number Date- Start Time Date- Stop Time

Average 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 5/24/2005 5/24/2005 5/24/2005 5/24/2005 5/24/2005 5/24/2005

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 3 Average RUN 1 RUN 2 RUN 3 Average

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 325,167 291,075 303,459 306,567 335,381 353,301 362,629 350,437

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 221,635 197,382 205,517 208,178 224,807 236,599 244,277 235,228

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 203,572 182,364 190,984 192,307 206,652 219,073 226,393 217,373

 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 Rate Pounds 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 5/25/2005 5/25/2005 5/25/2005 5/25/2005 5/25/2005 5/25/2005

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 3 Average RUN 1 RUN 2 RUN 3 Average

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 281,238 292,747 282,634 285,540 321,213 341,220 350,593 337,675

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 193,955 201,578 193,819 196,451 218,688 232,545 238,933 230,055

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 179,184 187,024 178,365 181,524 204,076 215,561 221,776 213,804

 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 Rate Pounds 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 5/31/2005 5/31/2005 5/31/2005 5/31/2005 5/31/2005 5/31/2005

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 Velocity Pressure 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 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 35.817 36.236 35.929 35.994 33.089 37.123 38.754 36.322

 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 Flow Rate Actual Cubic 393,770 393,725 397,261 394,919 364,076 363,511 360,197 362,595

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 250,190 260,364 261,493 257,349 250,036 257,801 256,053 254,630

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 229,389 238,663 239,527 235,860 230,373 238,731 236,784 235,296

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0076 0.0058 0.0049 0.0061 0.0068 0.0041 0.0045 0.0052

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0044 0.0035 0.0029 0.0036 0.0043 0.0027 0.0030 0.0033

 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 0.0099 0.0116

 Btu (O2 F Factor)

Combined Particulate Emission Rate Pounds per Million 0.0163 0.0113 0.0105 0.0127

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 6/1/2005 6/1/2005 6/1/2005 Average 6/1/2005 6/1/2005 6/1/2005 Average

Sampling Time -Start Military 0700 0845 1020 Compliance 0700 0845 1020 Compliance

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 122.910 122.910 122.910 122.840 122.840 122.840

Avg. Sqr. Root Velocity Pressure 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 Flow Rate Actual Cubic 382,613 377,473 385,259 381,782 370,341 366,230 377,913 371,495

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 262,712 258,451 255,855 259,006 255,006 256,165 259,505 256,892

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 242,870 237,531 236,295 238,899 234,533 235,381 240,048 236,654

 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 Rate Pounds 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 2 Average RUN 1 RUN 2 Average A+B

Date Month/Day/Year 6/1/2005 6/1/2005 6/1/2005 6/1/2005 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 Pressure Inches 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 2 Average RUN 1 RUN 2 Average 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 529,750 542,798 536,274 537,544 521,745 529,645 1,065,919

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 227,899 233,834 230,867 233,275 224,485 228,880 459,747

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 211,063 217,284 214,173 213,782 204,551 209,167 423,340

 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 2,810.2 2,798.9 3,207.6 2,641.2 2,924.4 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 1 Condition 1 Condition 2 Condition 2 Condition 3 Condition 3 Condition 1 Condition 2 Condition 3

Title of Run RUN 1 RUN 2 RUN 3 RUN 4 RUN 5 RUN 6 OUTLET A OUTLET A OUTLET 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 Pressure Inches 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 6 OUTLET A OUTLET A OUTLET 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 1 Condition 1 Condition 2 Condition 2 Condition 3 Condition 3 Condition 1 Condition 2 Condition 3

Title of Run RUN 1 RUN 2 RUN 3 RUN 4 RUN 5 RUN 6 OUTLET B OUTLET B OUTLET 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 Pressure Inches 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 1 Condition 1 Condition 2 Condition 2 Condition 3 Condition 3 Condition 1 Condition 2 Condition 3

RUN 1 RUN 2 RUN 3 RUN 4 RUN 5 RUN 6 OUTLET B OUTLET B OUTLET 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 6/2/2005 6/2/2005 6/2/2005 Average

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 Pressure Inches 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 1,413,490 1,469,426 1,462,150 1,448,355

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 635,031 661,934 657,233 651,399

 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 Time Date- 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 5/10/2006 5/10/2006 5/10/2006 5/10/2006 5/10/2006 5/10/2006

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 96.9000 96.9000 96.9000 107.3800 107.3800 107.3800

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 3 Average RUN 1 RUN 2 RUN 3

Volume of Gas Sampled Standard Dry 35.144 36.551 37.284 36.326 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 Flow Rate Actual Cubic 289,660 301,817 302,339 297,939 352,644 348,615 348,271

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 207,207 214,955 214,117 212,093 244,212 242,309 242,378

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 190,848 197,180 197,418 195,149 224,465 221,449 221,795

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0103 0.0056 0.0039 0.0066 0.0054 0.0040 0.0033

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0068 0.0037 0.0026 0.0043 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 Rate Pounds 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 5/11/2006 5/11/2006 5/11/2006 5/11/2006 5/11/2006 5/11/2006 5/11/2006

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 107.3800 107.3800 107.3800 107.3800

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 4 Average RUN 1 RUN 2 RUN 3 RUN 4 Average

Volume of Gas Sampled Standard Dry 37.489 36.600 36.782 36.360 36.581 40.243 40.234 41.126 40.710 40.690

 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 Flow Rate Actual Cubic 302,219 290,100 293,435 304,034 295,856 345,645 344,208 356,354 353,221 351,261

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 212,348 202,950 205,120 213,037 207,036 240,438 238,547 247,040 244,836 243,475

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 195,193 186,629 187,376 193,955 189,320 220,100 219,069 226,318 223,398 222,928

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0051 0.0061 0.0036 0.0050 0.0049 0.0048 0.0060 0.0023 0.0018 0.0034

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0033 0.0039 0.0023 0.0032 0.0031 0.0030 0.0038 0.0015 0.0011 0.0021

 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 Rate Pounds per Million 0.0122 0.0059 0.0066 0.0082

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 -Start Military 1233 1355 1519 1233 1355 1519

Sampling Time -Stop Military 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 Pressure Inches 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 Factordimensionless 0.967 0.967 0.967 0.938 0.938 0.938

Oxygen Concentration Mole 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 Metered Actual Cubic Feet 41.195 41.647 41.557 42.039 39.652 40.440

Volume of Water CollectedMilliliters 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 CollectedMilligrams 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 GasPercent 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 Flow Rate Actual Cubic 404,860 405,723 406,314 405,633 396,135 385,745 397,792 393,224

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 276,985 277,587 277,944 277,505 266,030 259,095 267,154 264,093

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 254,215 254,618 254,337 254,390 249,641 236,782 245,156 243,860

 Feet Per Minute

Particulate ConcentrationGrains per Standard 0.0086 0.0087 0.0059 0.0077 0.0053 0.0085 0.0057 0.0065

 Dry Cubic Foot

Particulate ConcentrationGrains per Actual 0.0054 0.0055 0.0037 0.0049 0.0034 0.0052 0.0035 0.0040

 Cubic Foot

Particulate Emission RatePounds per Hour 18.7 19.1 12.8 16.9 11.4 17.3 12.1 13.6

Particulate Emission RatePounds 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 EmPounds per Million ission Rate 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 5/22/2006 5/22/2006 5/22/2006 5/22/2006 5/22/2006 5/22/2006

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 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 39.292 39.855 38.829 39.325 38.461 36.932 36.803 37.399

 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 Flow Rate Actual Cubic 401,805 412,511 403,787 406,035 389,331 395,507 392,972 392,603

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 276,795 283,890 278,018 279,568 265,371 268,508 265,618 266,499

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 253,976 259,663 254,282 255,974 245,538 244,796 243,221 244,518

 Feet Per Minute

Particulate Concentration Grains per Standard 0.0076 0.0048 0.0092 0.0072 0.0072 0.0059 0.0078 0.0070

 Dry Cubic Foot

Particulate Concentration Grains per Actual 0.0048 0.0030 0.0058 0.0045 0.0045 0.0036 0.0048 0.0043

 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 Rate Pounds 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 6/11/2007 6/11/2007 6/11/2007 6/11/2007 6/11/2007 6/11/2007

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 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 39.416 39.338 42.941 40.565 42.934 39.122 38.696 40.251

 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 374,806 376,019 376,093 375,639 322,693 323,829 321,262 322,594

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 256,210 256,498 256,328 256,345 220,295 220,426 218,090 219,604

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 230,352 237,198 231,464 233,004 198,138 202,182 198,750 199,690

 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 Rate Pounds per Million 0.0079 0.0109 0.0085 0.0091

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 6/12/2007 6/12/2007 6/12/2007 6/12/2007 6/12/2007 6/12/2007

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 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 40.070 40.261 39.122 39.817 35.707 39.028 40.498 38.411

 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 378,064 371,313 367,337 372,238 306,823 300,915 305,086 304,275

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 260,673 255,296 249,852 255,273 210,502 208,554 207,647 208,901

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 235,749 231,972 226,177 231,299 189,742 190,411 188,379 189,511

 Feet Per Minute

Stack Gas Flow Rate Pounds of Dry Air 17,658 17,375 16,941 17,324 14,212 14,262 14,110 14,194

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 Rate Pounds per Million 0.0092 0.0101 0.0074 0.0089

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 5/8/2007 5/8/2007 5/8/2007 5/8/2007 5/8/2007 5/8/2007

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 3 Average RUN 1 RUN 2 RUN 3 Average

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 367,756 370,672 372,656 370,361 381,317 374,475 356,554 370,782

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 252,909 253,246 253,206 253,120 262,723 255,001 240,487 252,737

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 234,941 235,143 230,235 233,440 239,874 232,713 217,841 230,143

 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 Rate Pounds 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 5/8/2007 5/8/2007 5/8/2007 5/8/2007 5/8/2007 5/8/2007

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 3 Average RUN 1 RUN 2 RUN 3 Average

Volume of Gas Sampled Standard Dry 33.435 34.088 34.717 34.080 33.411 33.136 32.412 32.986

 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 Flow Rate Actual Cubic 371,961 364,991 367,546 368,166 374,150 363,992 354,752 364,298

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 252,157 246,813 247,952 248,974 252,719 244,870 237,670 245,086

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 228,075 226,772 225,343 226,730 227,987 221,863 216,023 221,958

 Feet Per Minute

Stack Gas Flow Rate 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 Factor dimensionless 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 FLOW ULTIMATE ANALYSIS MMBTU/HR

Number Started Stopped Load lbs/mmBtu LBS BTU/LB

1 5/5/08 13:05 5/5/08 14:05 171 0.807 150000 11047 1578.1

2 5/5/08 14:25 5/5/08 15:25 172 0.805 157300 11352 1623.3

3 5/5/08 15:55 5/5/08 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 Time End Time Test Load

Avg. 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

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 5/5/2008 5/5/2008 5/5/2008 5/5/2008 5/5/2008 5/5/2008

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 UPPER Weighted

DUCT DUCT TOTAL or

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

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 364,239 379,941 357,256 310,082 323,447 313,089 367,145 315,539 682,684

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 251,901 262,301 246,736 211,493 219,982 213,599 253,646 215,025 468,671

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 237,295 241,537 228,438 196,020 202,411 196,954 235,757 198,462 434,218

 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 Rate Pounds 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

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 5/6/2008 5/6/2008 5/6/2008 5/6/2008 5/6/2008 5/6/2008

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 DUCT TOTAL or

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

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 339,575 363,091 365,522 313,356 314,926 327,391 356,063 318,558 674,620

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 239,302 252,637 252,713 220,550 217,437 224,164 248,217 220,717 468,934

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 223,720 233,376 233,134 200,353 197,169 204,951 230,077 200,824 430,901

 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 Rate Pounds 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 Load

Avg. 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 FLOW ULTIMATE ANALYSIS MMBTU/HR

Number Started Stopped Load lbs/mmBtu LBS BTU/LB

1 3/17/08 14:50 3/17/08 15:50 199 1.500 197900 11552 2017.2

2 3/17/08 16:10 3/17/08 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 1.433
ATTACHMENT 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 3/17/2008 3/17/2008 3/17/2008 3/17/2008 3/17/2008 3/17/2008

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 Side Lower Side TOTAL or

RUN 1 

UPPER

RUN 2 

UPPER

RUN 3 

UPPER

RUN 1 

LOWER

RUN 2 

LOWER

RUN 3 

LOWER AVERAGE AVERAGE

COMBINE

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 405,282 405,686 405,051 492,772 414,891 401,874 427,198 408,382 835,580

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 276,598 275,798 274,764 338,387 284,165 274,396 291,387 279,280 570,667

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 257,105 257,719 252,480 315,107 264,254 257,586 270,603 260,920 531,523

 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 Check dimensionless 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 BLOWING
ATTACHMENT 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 3/18/2008 3/18/2008 3/18/2008 3/18/2008 3/18/2008 3/18/2008

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 LOWER TOTAL or

RUN 1 

UPPER

RUN 2 

UPPER

RUN 3 

UPPER

RUN 1 

LOWER

RUN 2 

LOWER

RUN 3 

LOWER AVERAGE AVERAGE

COMBINE

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 388,111 376,090 386,956 402,811 389,148 398,567 383,719 396,842 780,561

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 266,932 256,212 262,150 279,236 268,201 273,648 261,765 273,695 535,460

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 249,537 233,995 242,546 256,487 251,806 255,081 242,026 254,458 496,484

 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 Check dimensionless 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 FLOW ULTIMATE 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 1.635
ATTACHMENT 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 5/18/2009 5/18/2009 5/18/2009 5/18/2009 5/18/2009 5/18/2009

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 3 AVERAGE AVERAGE AVERAGE

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 Flow Rate Actual Cubic 329,599 331,146 353,046 345,144 344,949 352,032 337,930 347,375 685,305

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 228,909 229,553 244,564 237,813 236,941 241,994 234,342 238,916 473,258

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 211,678 212,172 224,163 219,937 216,356 222,079 216,004 219,457 435,462

 Feet Per Minute

Stack Gas Flow Rate 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 Rate Pounds 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 OPERATIONS
ATTACHMENT 33 - Smith Report 33 Test Results

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

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

Date Month/Day/Year 8/19/2009 8/19/2009 8/19/2009 8/19/2009 8/19/2009 8/19/2009

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 B TOTAL or

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

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 345,471 345,560 350,804 295,002 357,693 361,477 347,278 338,057 685,336

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 241,192 238,509 241,415 201,291 242,674 245,220 240,372 229,728 470,100

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 216,695 217,230 216,601 182,152 220,204 222,968 216,842 208,442 425,284

 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 Rate Pounds 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 ULTIMATE ANALYSIS MMBTU/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 1.625
ATTACHMENT 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 5/19/2009 5/19/2009 5/19/2009 5/19/2009 5/19/2009 5/19/2009

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 UPPER TOTAL OR

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

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 Flow Rate Actual Cubic 430,149 424,652 421,480 395,043 395,933 426,413 425,427 405,796 831,223

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 291,508 286,788 284,071 264,114 263,741 283,549 287,456 270,468 557,924

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 270,735 265,117 265,748 244,491 244,565 264,310 267,200 251,122 518,322

 Feet Per Minute

Stack Gas Flow Rate 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 Rate Pounds 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 CONDITION
ATTACHMENT 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 5/20/2009 5/20/2009 5/20/2009 5/20/2009 5/20/2009 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 UPPER TOTAL OR

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

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 Flow Rate Actual Cubic 398,390 394,474 397,175 426,530 420,550 421,136 396,680 422,739 819,418

 Feet Per Minute

Stack Gas Flow Rate Standard Wet Cubic 270,574 266,708 267,445 285,802 280,557 279,964 268,242 282,107 550,350

 Feet Per Minute

Stack Gas Flow Rate Standard Dry Cubic 251,033 246,215 247,136 264,258 258,397 257,781 248,128 260,145 508,273

 Feet Per Minute

Stack Gas Flow Rate 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 Rate Pounds 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