Name: Nicholas Laryea

Title: Environmental Manager

Company: Indiantown Cogeneration L.P.

Sign Date: 9/2/2010

Name: Steve Webb

Title: President

Company: Coastal Air Consulting

Sign Date: 9/2/2010

Permitted Facility Representative / Date Testing Company Representative / Date

50976 Indiantown Cogeneration

Final Test Report 

for

/ /

Based on information and belief formed 

after reasonable inquiry, I certify that the 

statements and information in this test 

report are true, accurate, and complete.

I have reviewed all testing details and 

results in this test report and hereby 

certify that the test report is authentic 

and accurate.

Saturday, January 29, 2011 Page 1 of 27
50976 Indiantown Cogeneration

9/2/2010

Facility Information:

Indiantown Cogeneration LP

13303 S W Silver Fox Lane

Indiantown FL 34956

Contact: Nicholas Laryea

Phone: 772-597-6500 x19

Fax: 772-597-6210

Email: nicholas.laryea@indiantowncogen.c

om

Testing Company:

Coastal Air Consulting, Inc.

1531 Wyngate Dr.

DeLand FL 32724

Contact: Steve Webb

Phone: 386-451-0619

Fax:

Email: CoastalAir123@aol.com

Air Permit Number:

50976

Permitted Source ID/Name:

01 Boiler #1

Permitted Maximum Process Rate: Max. Normal Operation Process Rate: Target Process Test Rate

Description of the source (including control equipment). Please see the attachments for source or

 process flow diagram:

Indiantown Cogeneration uses bituminous pulverzized coal. The coal is burned in low nox burners utilizing overfire 

air. A selective catalytic reducer uses ammonia to reduce Nox. The flue gas then passes through an air preheater, 

spray dry absorber to reduce Sox, and fabric baghouse.

Industry/SCC/NAIS 221112

Sampling Location Information:

Test Parameter Information:

AFS #: 1208500102 FRS #: 110002394793

SCC / Description 10100202 External Combustion Boilers - Electric Generation - Bituminous/Subbituminous 

Coal - Pulverized Coal: Dry Bottom (Bituminous Coal) 

The following state and federal regulations that apply to the proposed testing:

Location

Round

Duct

Diam.

Distance from 

upstream dist.

Distance from

downstream dist.

Number of

Traverse Ports

Equiv. 

Diam

Min.Travers 

Points

Rect. Duct 

Length /Width

Stack Exit 206 0 0 0 1792 3000 4 12

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Stack Exit % H2O Method 1 - 4 3 180 0

Stack Exit Carbon Monoxide Method 10 3 120 0

Stack Exit Formaldehyde Method 0011 3 120 0

Stack Exit 2,3,7,8-TCDD Method 23 3 480 0

Stack Exit 1,2,3,7,8-PeCDD Method 23 3 480 0

Stack Exit 1,2,3,4,7,8-HxCDD Method 23 3 480 0

Stack Exit 1,2,3,6,7,8-HxCDD Method 23 3 480 0

Saturday, January 29, 2011 Page 2 of 27
50976 Indiantown Cogeneration

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Stack Exit 1,2,3,7,8,9-HxCDD Method 23 3 480 0

Stack Exit 1,2,3,4,6,7,8-HpCDD Method 23 3 480 0

Stack Exit OCDD Method 23 3 480 0

Stack Exit 2,3,7,8-TCDF Method 23 3 480 0

Stack Exit 1,2,3,7,8-PeCDF Method 23 3 480 0

Stack Exit 2,3,4,7,8-PeCDF Method 23 3 480 0

Stack Exit 1,2,3,4,7,8-HxCDF Method 23 3 480 0

Stack Exit 1,2,3,6,7,8-HxCDF Method 23 3 480 0

Stack Exit 2,3,4,6,7,8-HxCDF Method 23 3 480 0

Stack Exit 1,2,3,7,8,9-HxCDF Method 23 3 480 0

Stack Exit 1,2,3,4,6,7,8-HpCDF Method 23 3 480 0

Stack Exit 1,2,3,4,7,8,9-HpCDF Method 23 3 480 0

Stack Exit OCDF Method 23 3 480 0

Stack Exit Other TCDD Method 23 0

Stack Exit Other PeCDD Method 23 0

Stack Exit Other HxCDD Method 23 0

Stack Exit Other HpCDD Method 23 0

Stack Exit Other TCDF Method 23 0

Stack Exit Other PeCDF Method 23 0

Stack Exit Other HxCDF Method 23 0

Stack Exit Other HpCDF Method 23 0

Stack Exit Total Dioxins Method 23 3 480 0

Stack Exit Total Furans Method 23 3 480 0

Stack Exit 3,3',4,4'-TCB (PCB77) Method 23 3 480 0

Stack Exit 3,4,4',5-TCB (PCB81) Method 23 3 480 0

Stack Exit 2,3,3',4,4'-PeCB (PCB105) Method 23 3 480 0

Stack Exit 2,3,4,4',5-PeCB (PCB114) Method 23 3 480 0

Stack Exit 2,3',4,4',5-PeCB (PCB118) Method 23 3 480 0

Stack Exit 2',3,4,4',5-PeCB (PCB123) Method 23 3 480 0

Stack Exit 3,3',4,4',5-PeCB (PCB126) Method 23 3 480 0

2,3,3',4,4',5/2,3,3',4,4',5'-

HxCB (PCBs156/157)

Stack Exit Method 23 3 480 0

Stack Exit 2,3',4,4',5,5'-HxCB (PCB167) Method 23 3 480 0

Stack Exit 3,3',4,4',5,5'-HxCB (PCB169) Method 23 3 480 0

2,3,3',4,4',5,5'-HpCB 

(PCB189)

Stack Exit Method 23 3 480 0

Stack Exit Total PCBs Method 23 3 480 0

Stack Exit Total TEQ Method 23 3 480 0

Total organic compounds 

(TOC) as Propane

Stack Exit Method 25A 3 120 0

Stack Exit Hydrogen Chloride Method 26 3 180 0

Stack Exit Hydrogen Fluoride Method 26 3 180 0

Hydrogen Chloride Method 26A 3 180 0 run date is 3/8 not 

4/10 - ERT entry error

Stack Exit

Hydrogen Fluoride Method 26A 3 180 0 run date is 3/8 not 

4/10 - ERT entry error

Stack Exit

Inorganic (Aqueous) 

Condensible Part.

OTM - 27/28 3 240 0 Use only for dry 

stacks. Delete Method 

5/OTM28 tests.

Stack Exit

Filterable PM2.5 OTM - 27/28 3 240 0 Use only for dry 

stacks. Delete Method 

5/OTM28 tests.

Stack Exit

Saturday, January 29, 2011 Page 3 of 27
50976 Indiantown Cogeneration

9/2/2010

The following describes any modifications and/or deviations to the applicable test 

methods. If alternative methods were requested, see the attachments for documentation 

of request AND approval, including dates.

Organic Condensible 

Particulate

OTM - 27/28 3 240 0 Use only for dry 

stacks. Delete Method 

5/OTM28 tests.

Stack Exit

Total PM2.5 OTM - 27/28 3 240 0 Use only for dry 

stacks. Delete Method 

5/OTM28 tests.

Stack Exit

Total Particulate OTM - 27/28 3 240 0 Use only for dry 

stacks. Delete Method 

5/OTM28 tests.

Stack Exit

Filterable Particulate OTM - 27/28 3 240 0 Use only for dry 

stacks. Delete Method 

5/OTM28 tests.

Stack Exit

Stack Exit Arsenic Method 29 3 240 0

Stack Exit Manganese Method 29 3 240 0

Stack Exit Nickel Method 29 3 240 0

Stack Exit Selenium Method 29 3 240 0

Stack Exit Chromium Method 29 3 240 0

Stack Exit Cadmium Method 29 3 240 0

Stack Exit Lead Method 29 3 240 0

Stack Exit Beryllium Method 29 3 240 0

Stack Exit Antimony Method 29 3 240 0

Stack Exit Co2 Method 3A CO2 3 120 0

Stack Exit Co2 Method 3A CO2 3 240 0

Stack Exit O2 Method 3A O2 3 240 0

Stack Exit O2 Method 3A O2 3 480 0

Stack Exit Co2 Method 3A CO2 3 480 0

Stack Exit O2 Method 3A O2 3 120 0

Organic Condensible 

Particulate

Method 5/OTM-28 3 240 0 Use only for wet 

stacks. Delete 

OTM27/OTM28 test.

Stack Exit

Inorganic (Aqueous) 

Condensible Part.

Method 5/OTM-28 3 240 0 Use only for wet 

stacks. Delete 

OTM27/OTM28 test.

Stack Exit

Total Particulate Method 5/OTM-28 3 240 0 Use only for wet 

stacks. Delete 

OTM27/OTM28 test.

Stack Exit

Stack Exit Filterable Particulate Method 5 3 240 0

Filterable Particulate Method 5/OTM-28 3 240 0 Use only for wet 

stacks. Delete 

OTM27/OTM28 test.

Stack Exit

Stack Exit Sulfur Dioxide Method 6C 3 180 0

Stack Exit Nitrogen oxides (NOx) Method 7E 3 180 0

Saturday, January 29, 2011 Page 4 of 27
50976 Indiantown Cogeneration

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Sampling / Stack Data Results Summary

Location Stack Exit - Method 10

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Location Stack Exit - Method 25A

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Saturday, January 29, 2011 Page 5 of 27
50976 Indiantown Cogeneration

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Location Stack Exit - Method 26A

Average

Run Number 1 2 3

Test Date 6/6/2010 6/7/2010 6/7/2010

Run Start Time 3:03:00 PM 10:08:00 

AM

1:19:00 PM

Run Finish Time 5:48:00 PM 12:53:00 

PM

4:04:00 PM

Net Run Time, minutes 180 180 180

Dry Gas Meter Volume Sampled, dscf 149.334 148.848 153.819 150.667

Moisture Content of Stack Gas, % 14.33 14.68 13.97 14.327

Moisture Saturation at Stack Gas Temperature, % 60.62 59.10 59.10 59.607

Carbon Dioxide, % 13.1 12.9 12.8 12.933

Oxygen, % 6.1 6.4 6.2 6.233

Average Stack Gas Temperature, °F 187.92 186.75 186.75 187.140

Dry Volumetric Flow Rate, dry scfm 758,822.1 753,893.8 753,137.8 755,284.567

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,085,833.9 1,081,251.2 1,071,252.4 1,079,445.83

3

Percent Isokinetic of Sampling Rate, % 97.6 97.9 101.3 98.933

F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000

Fw 10640 10640 10640 10,640.000

Fc 1800 1800 1800 1,800.000

Saturday, January 29, 2011 Page 6 of 27
50976 Indiantown Cogeneration

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Location Stack Exit - Method 29

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Net Run Time, minutes

Dry Gas Meter Volume Sampled, dscf

Moisture Content of Stack Gas, %

Moisture Saturation at Stack Gas Temperature, %

Carbon Dioxide, %

Oxygen, %

Average Stack Gas Temperature, °F

Dry Volumetric Flow Rate, dry scfm

Actual Wet Volumetric Flue Gas Flow Rate, acfm

Percent Isokinetic of Sampling Rate, %

F-Factor, dscfm/MMBtu @ %O2

Fw

Fc

Location Stack Exit - Method 6C

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Saturday, January 29, 2011 Page 7 of 27
50976 Indiantown Cogeneration

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Location Stack Exit - Method 7E

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Location Stack Exit - OTM - 27/28

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Net Run Time, minutes

Dry Gas Meter Volume Sampled, dscf

Moisture Content of Stack Gas, %

Moisture Saturation at Stack Gas Temperature, %

Carbon Dioxide, %

Oxygen, %

Average Stack Gas Temperature, °F

Dry Volumetric Flow Rate, dry scfm

Actual Wet Volumetric Flue Gas Flow Rate, acfm

Percent Isokinetic of Sampling Rate, %

F-Factor, dscfm/MMBtu @ %O2

Fw

Fc

Saturday, January 29, 2011 Page 8 of 27
50976 Indiantown Cogeneration

9/2/2010

Emissions Summary

Location: Stack Exit - Method 10

Compound: Carbon Monoxide

Average

Run 1 2 3

lb/mmBtuO2 3.50E-01 2.08E-01 9.48E-02 0.218

ppm 3.53E+02 2.09E+02 9.24E+01 218.133

ppm@7%O2 3.27E+02 1.95E+02 8.86E+01 203.533

Location: Stack Exit - Method 25A

Compound: Total organic compounds (TOC) as 

Average

Run 1 2 3

Elb/hr 0.00E+00 0.00E+00 0.000

gr/dscf 6.11E-04 6.29E-04 6.43E-04 0.001

lb/mmBtuO2 1.21E-03 1.25E-03 1.27E-03 0.001

mg/dscm 1.40E+00 1.44E+00 1.47E+00 1.437

ppm 7.62E-01 7.85E-01 8.02E-01 0.783

ppm@7%O2 7.21E-01 7.41E-01 7.54E-01 0.739

Location: Stack Exit - Method 26A

Compound: Hydrogen Chloride

Average

RunNumber 1 2 3

Mass_mg 0.176 0.175 0.175 0.175

Elb/hr 1.18E-01 1.17E-01 1.13E-01 0.116

lb/mmBtuO2 3.59E-05 3.65E-05 3.49E-05 0.000

mg/dscm 4.16E-02 4.15E-02 4.02E-02 0.041

mg/dscm@7%O2 3.91E-02 3.98E-02 3.80E-02 0.039

Compound: Hydrogen Fluoride

Average

RunNumber 1 2 3

Mass_mg 0.466 0.464 0.462 0.464

Elb/hr 3.13E-01 3.11E-01 2.99E-01 0.308

lb/mmBtuO2 9.50E-05 9.69E-05 9.21E-05 0.000

mg/dscm 1.10E-01 1.10E-01 1.06E-01 0.109

mg/dscm@7%O2 1.03E-01 1.05E-01 1.00E-01 0.103

Location: Stack Exit - Method 29

Compound: Antimony

Average

RunNumber 1 2 3

Mass_mg 0.000586 0.0031 0.000973 0.002

Elb/hr 2.99E-04 1.57E-03 4.89E-04 0.001

lb/mmBtuO2 9.35E-08 4.77E-07 1.53E-07 0.000

mg/dscm 1.07E-04 5.49E-04 1.74E-04 0.000

mg/dscm@7%O2 1.02E-04 5.19E-04 1.67E-04 0.000

Compound: Arsenic

Average

Saturday, January 29, 2011 Page 9 of 27
50976 Indiantown Cogeneration

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RunNumber 1 2 3

Mass_mg 0.000293 0.000897 0.0014 0.001

Elb/hr 1.50E-04 4.53E-04 7.04E-04 0.000

lb/mmBtuO2 4.68E-08 1.38E-07 2.20E-07 0.000

mg/dscm 5.35E-05 1.59E-04 2.50E-04 0.000

mg/dscm@7%O2 5.09E-05 1.50E-04 2.40E-04 0.000

Compound: Beryllium

Average

RunNumber 1 2 3

Mass_mg 0.000047 0.000053 0.00011 0.000

Elb/hr 2.40E-05 2.68E-05 5.53E-05 0.000

lb/mmBtuO2 7.50E-09 8.15E-09 1.73E-08 0.000

mg/dscm 8.59E-06 9.39E-06 1.96E-05 0.000

mg/dscm@7%O2 8.18E-06 8.88E-06 1.88E-05 0.000

Compound: Cadmium

Average

RunNumber 1 2 3

Mass_mg 0.001388 0.002529 0.001394 0.002

Elb/hr 7.08E-04 1.28E-03 7.01E-04 0.001

lb/mmBtuO2 2.22E-07 3.89E-07 2.19E-07 0.000

mg/dscm 2.54E-04 4.48E-04 2.49E-04 0.000

mg/dscm@7%O2 2.42E-04 4.24E-04 2.39E-04 0.000

Compound: Chromium

Average

RunNumber 1 2 3

Mass_mg 0.0074 0.00573 0.00518 0.006

Elb/hr 3.78E-03 2.89E-03 2.61E-03 0.003

lb/mmBtuO2 1.18E-06 8.81E-07 8.14E-07 0.000

mg/dscm 1.35E-03 1.02E-03 9.25E-04 0.001

mg/dscm@7%O2 1.29E-03 9.64E-04 8.87E-04 0.001

Compound: Lead

Average

RunNumber 1 2 3

Mass_mg 0.0232 0.02053 0.02319 0.022

Elb/hr 1.18E-02 1.04E-02 1.17E-02 0.011

lb/mmBtuO2 3.70E-06 3.16E-06 3.64E-06 0.000

mg/dscm 4.24E-03 3.64E-03 4.14E-03 0.004

mg/dscm@7%O2 4.04E-03 3.44E-03 3.97E-03 0.004

Compound: Manganese

Average

RunNumber 1 2 3

Mass_mg 0.00352 0.0091 0.00355 0.005

Elb/hr 1.80E-03 4.59E-03 1.79E-03 0.003

lb/mmBtuO2 5.62E-07 1.40E-06 5.58E-07 0.000

mg/dscm 6.43E-04 1.61E-03 6.34E-04 0.001

mg/dscm@7%O2 6.12E-04 1.52E-03 6.08E-04 0.001

Compound: Nickel

Average

Saturday, January 29, 2011 Page 10 of 27
50976 Indiantown Cogeneration

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RunNumber 1 2 3

Mass_mg 0.00658 0.00521 0.00522 0.006

Elb/hr 3.36E-03 2.63E-03 2.63E-03 0.003

lb/mmBtuO2 1.05E-06 8.01E-07 8.20E-07 0.000

mg/dscm 1.20E-03 9.23E-04 9.32E-04 0.001

mg/dscm@7%O2 1.14E-03 8.73E-04 8.93E-04 0.001

Compound: Selenium

Average

RunNumber 1 2 3

Mass_mg 0.000222 0.001427 0.007762 0.003

Elb/hr 1.13E-04 7.20E-04 3.90E-03 0.002

lb/mmBtuO2 3.54E-08 2.19E-07 1.22E-06 0.000

mg/dscm 4.06E-05 2.53E-04 1.39E-03 0.001

mg/dscm@7%O2 3.87E-05 2.39E-04 1.33E-03 0.001

Location: Stack Exit - Method 6C

Compound: Sulfur Dioxide

Average

Run 1 2 3

Elb/hr 0.00E+00 0.00E+00 0.000

lb/mmBtuO2 1.46E-01 1.41E-01 1.53E-01 0.147

mg/dscm 1.72E+02 1.65E+02 1.74E+02 170.333

mg/dscm@7%O2 1.59E+02 1.54E+02 1.67E+02 160.000

ppm 6.45E+01 6.21E+01 6.54E+01 64.000

ppm@7%O2 5.98E+01 5.78E+01 6.27E+01 60.100

Location: Stack Exit - Method 7E

Compound: Nitrogen oxides (NOx)

Average

Run 1 2 3

Elb/hr 0.00E+00 0.00E+00 0.00E+00 0.000

lb/mmBtuO2 1.13E-01 1.25E-01 1.18E-01 0.119

mg/dscm 1.33E+02 1.46E+02 1.34E+02 137.667

mg/dscm@7%O2 1.23E+02 1.36E+02 1.29E+02 129.333

ppm 6.94E+01 7.62E+01 6.98E+01 71.800

ppm@7%O2 6.43E+01 7.09E+01 6.70E+01 67.400

Location: Stack Exit - OTM - 27/28

Compound: Filterable Particulate

Average

RunNumber 1 2 3

Mass_mg 0.0184 0.0128 0.0087 0.013

lb/mmBtuO2 4.38E-06 3.21E-06 2.07E-06 0.000

Compound: Filterable PM2.5

Average

RunNumber 1 2 3

Mass_mg 0.0061 0.0045 0.0014 0.004

lb/mmBtuO2 1.45E-06 1.13E-06 3.33E-07 0.000

Saturday, January 29, 2011 Page 11 of 27
50976 Indiantown Cogeneration

9/2/2010

Process Run Data

Compound: Inorganic (Aqueous) Condensible Pa

Average

RunNumber 1 2 3

Mass_mg 33.3 16.1 10 19.800

lb/mmBtuO2 7.93E-03 4.04E-03 2.38E-03 0.005

Compound: Organic Condensible Particulate

Average

RunNumber 1 2 3

Mass_mg 14.9 13.1 13.4 13.800

lb/mmBtuO2 3.55E-03 3.29E-03 3.19E-03 0.003

Compound: Total Particulate

Average

RunNumber 1 2 3

Mass_mg 48.2184 29.2128 23.4087 33.613

lb/mmBtuO2 1.15E-02 7.33E-03 5.57E-03 0.008

Compound: Total PM2.5

Average

RunNumber 1 2 3

Mass_mg 48.2061 29.2045 23.4014 33.604

lb/mmBtuO2 1.15E-02 7.33E-03 5.57E-03 0.008

Saturday, January 29, 2011 Page 12 of 27
50976 Indiantown Cogeneration

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Process Run Data

Run Name Value UOM Comments

Target

Value

3 Heat Input 2882.9 Million Btus/hr 0 6/7/10

3 Average Heat Input 2882.9 MMBtu/hr 0

3 Steam Output 2110.9 1000 lb steam/hr 0

3 Synfuel Firing Rate 0 0

3 Petroleum Coke Firing Rate 0 0

3 Coal Gas Firing Rate 0 0

3 Fuel Oil Firing Rate 0 0

3 Flue Gas Flow Rate 805797 dscfm 0

3 Pressure Drop Across FGD (if applicable) 1.4 in H20 0

3 FGD Scrubber Liquor pH 0 pH 0

3 FGD Scrubber Liquor Flow Rate 206.53 gal/min 0

3 Sorbent Type and Sorbent Injection Rate (if 

applicable)

0 lb/hr 0 lime

3 Flue Gas Oxygen Content 0 % 0

3 Flue Gas Carbon Dioxide Content 11.2 % 0

3 Flue Gas Moisture Content 0 % 0

3 Flue Gas Sampling Point Temperature 0 Deg F 0

3 Flue Gas Pressure 0 in. Hg 29.89

3 Standard Pressure 0 in. Hg 0

3 Standard Temperature 191.6 Deg F 0

3 Unit Gross Electrical Output 0 MW 0

3 Unit Net Electric Generation 7188 MWh 0

4 Heat Input 2537.6 Million Btus/hr 0 6/9/10

4 Average Heat Input 2537.6 MMBtu/hr 0

4 Steam Output 1779.7 1000 lb steam/hr 0

4 Synfuel Firing Rate 0 0

4 Petroleum Coke Firing Rate 0 0

4 Coal Gas Firing Rate 0 0

4 Fuel Oil Firing Rate 0 0

4 Flue Gas Flow Rate 738754 dscfm 0

4 Pressure Drop Across FGD (if applicable) 1.2 in H20 0

4 FGD Scrubber Liquor pH 0 pH 0

4 FGD Scrubber Liquor Flow Rate 191.72 gal/min 0

Saturday, January 29, 2011 Page 13 of 27
50976 Indiantown Cogeneration

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4 Sorbent Type and Sorbent Injection Rate (if 

applicable)

0 lb/hr 0 lime

4 Flue Gas Oxygen Content 0 % 0

4 Flue Gas Carbon Dioxide Content 10.3 % 0

4 Flue Gas Moisture Content 0 % 0

4 Flue Gas Sampling Point Temperature 192.6 Deg F 0

4 Flue Gas Pressure 0 in. Hg 29.89

4 Standard Pressure 0 in. Hg 0

4 Standard Temperature 0 Deg F 0

4 Unit Gross Electrical Output 0 MW 0

4 Unit Net Electric Generation 5956.8 MWh 0

1 Heat Input 2350.6 Million Btus/hr 0 6/5/10

1 Average Heat Input 2350.6 MMBtu/hr 0

1 Steam Output 1738 1000 lb steam/hr 0

1 Synfuel Firing Rate 0

1 Petroleum Coke Firing Rate 0

1 Coal Gas Firing Rate 0

1 Fuel Oil Firing Rate 0

1 Flue Gas Flow Rate 730435 dscfm 0

1 Pressure Drop Across FGD (if applicable) 1.2 in H20 0

1 FGD Scrubber Liquor pH pH 0

1 FGD Scrubber Liquor Flow Rate 186.48 gal/min 0

1 Sorbent Type and Sorbent Injection Rate (if 

applicable)

lb/hr 0 lime

1 Flue Gas Oxygen Content % 0

1 Flue Gas Carbon Dioxide Content 10 % 0

1 Flue Gas Moisture Content % 0

1 Flue Gas Sampling Point Temperature 192.6 Deg F 0

1 Flue Gas Pressure in. Hg 29.89

1 Standard Pressure in. Hg 0

1 Standard Temperature Deg F 0

1 Unit Gross Electrical Output MW 0

1 Unit Net Electric Generation 5649.6 MWh 0

2 Heat Input 2161.1 Million Btus/hr 0 6/6/10

2 Average Heat Input 2161.1 MMBtu/hr 0

2 Steam Output 1560.2 1000 lb steam/hr 0

2 Synfuel Firing Rate 0 0

Saturday, January 29, 2011 Page 14 of 27
50976 Indiantown Cogeneration

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APCD Run Data

Process Lab Run Data

2 Petroleum Coke Firing Rate 0 0

2 Coal Gas Firing Rate 0 0

2 Fuel Oil Firing Rate 0 0

2 Flue Gas Flow Rate 709372 dscfm 0

2 Pressure Drop Across FGD (if applicable) 1.1 in H20 0

2 FGD Scrubber Liquor pH 0 pH 0

2 FGD Scrubber Liquor Flow Rate 172.37 gal/min 0

2 Sorbent Type and Sorbent Injection Rate (if 

applicable)

0 lb/hr 0 lime

2 Flue Gas Oxygen Content 0 % 0

2 Flue Gas Carbon Dioxide Content 9.3 % 0

2 Flue Gas Moisture Content 0 % 0

2 Flue Gas Sampling Point Temperature 192.3 Deg F 0

2 Flue Gas Pressure 0 in. Hg 29.89

2 Standard Pressure 0 in. Hg 0

2 Standard Temperature 0 Deg F 0

2 Unit Gross Electrical Output 0 MW 0

2 Unit Net Electric Generation 5028 MWh 0

Run Name Value UOM Comments

Target

Value

1 LOW NOX BURNERS 1 N/A 1

1 OVERFIRE AIR 1 N/A 1

1 SCR (SELECTIVE CATALYTIC REDUCTION) 1 1

1 SPRAY DRYER 1 1

1 BAGHOUSE 1 1

Run Name Value UOM Comments

1 Fuel Higher Heating Value 12526 Btu/lb

2 Fuel Higher Heating Value 12604 Btu/lb

3 Fuel Higher Heating Value 12669 Btu/lb

1 Fuel Moisture 2.07 %

2 Fuel Moisture 2.1 %

3 Fuel Moisture 2.1 %

1 Fuel Mercury Content 0.063 ppm

2 Fuel Mercury Content 0.037 ppm

Saturday, January 29, 2011 Page 15 of 27
50976 Indiantown Cogeneration

9/2/2010

3 Fuel Mercury Content 0.114 ppm

1 Fuel Cadmium Content 0.063 ppm

2 Fuel Cadmium Content 0.081 ppm

3 Fuel Cadmium Content 0.049 ppm

1 Ultimate/Proximate Analysis 0

2 Ultimate/Proximate Analysis 0

3 Ultimate/Proximate Analysis 0

1 Fuel Nickel Content 16.55 ppm

2 Fuel Nickel Content 16.87 ppm

3 Fuel Nickel Content 17.05 ppm

1 Fuel Arsenic Content 2.435 ppm

2 Fuel Arsenic Content 2.834 ppm

3 Fuel Arsenic Content 2.694 ppm

1 Fuel Chromium Content 19.5 ppm

2 Fuel Chromium Content 20.01 ppm

3 Fuel Chromium Content 19.84 ppm

1 Fuel Beryllium Content 2.197 ppm

2 Fuel Beryllium Content 2.229 ppm

3 Fuel Beryllium Content 2.236 ppm

1 Fuel Lead Content 8.68 ppm

2 Fuel Lead Content 8.744 ppm

3 Fuel Lead Content 8.828 ppm

1 Fuel Manganese Content 7.71 ppm

2 Fuel Manganese Content 7.635 ppm

3 Fuel Manganese Content 7.67 ppm

1 Fuel Chlorine Content 1316 ppm

2 Fuel Chlorine Content 1523 ppm

3 Fuel Chlorine Content 1516 ppm

1 Fuel Fluorine Content ppm

2 Fuel Fluorine Content ppm

3 Fuel Fluorine Content ppm

4 Fuel Higher Heating Value 12690 Btu/lb

4 Fuel Moisture 2.19 %

4 Fuel Mercury Content 0.049 ppm

4 Fuel Cadmium Content 0.085 ppm

4 Ultimate/Proximate Analysis 0

4 Fuel Nickel Content 17.07 ppm

4 Fuel Arsenic Content 2.89 ppm

4 Fuel Chromium Content 19.71 ppm

4 Fuel Beryllium Content 2.201 ppm

4 Fuel Lead Content 8.685 ppm

4 Fuel Manganese Content 7.22 ppm

4 Fuel Chlorine Content 1590 ppm

Saturday, January 29, 2011 Page 16 of 27
50976 Indiantown Cogeneration

9/2/2010

4 Fuel Fluorine Content 0 ppm

5 Fuel Higher Heating Value 12757 Btu/lb

5 Fuel Moisture 2.08 %

5 Fuel Mercury Content 0.06 ppm

5 Fuel Cadmium Content 0.081 ppm

5 Ultimate/Proximate Analysis 0

5 Fuel Nickel Content 16.7 ppm

5 Fuel Arsenic Content 2.726 ppm

5 Fuel Chromium Content 19.06 ppm

5 Fuel Beryllium Content 2.169 ppm

5 Fuel Lead Content 8.297 ppm

5 Fuel Manganese Content 7 ppm

5 Fuel Chlorine Content 1502 ppm

5 Fuel Fluorine Content 10 ppm

6 Fuel Higher Heating Value 12671 Btu/lb

6 Fuel Moisture 2.18 %

6 Fuel Mercury Content 0.086 ppm

6 Fuel Cadmium Content 0.075 ppm

6 Ultimate/Proximate Analysis 0

6 Fuel Nickel Content 16.61 ppm

6 Fuel Arsenic Content 2.497 ppm

6 Fuel Chromium Content 19.02 ppm

6 Fuel Beryllium Content 2.158 ppm

6 Fuel Lead Content 8.656 ppm

6 Fuel Manganese Content 7.289 ppm

6 Fuel Chlorine Content 1378 ppm

6 Fuel Fluorine Content 0 ppm

7 Fuel Higher Heating Value 12612 Btu/lb

7 Fuel Moisture 2.13 %

7 Fuel Mercury Content 0.09 ppm

7 Fuel Cadmium Content 0.134 ppm

7 Ultimate/Proximate Analysis 0

7 Fuel Nickel Content 16.86 ppm

7 Fuel Arsenic Content 2.357 ppm

7 Fuel Chromium Content 19.32 ppm

7 Fuel Beryllium Content 2.203 ppm

7 Fuel Lead Content 8.73 ppm

7 Fuel Manganese Content 8.31 ppm

7 Fuel Chlorine Content 1707 ppm

7 Fuel Fluorine Content 0 ppm

8 Fuel Higher Heating Value 12546 Btu/lb

8 Fuel Moisture 2.2 %

8 Fuel Mercury Content 0.055 ppm

Saturday, January 29, 2011 Page 17 of 27
50976 Indiantown Cogeneration

9/2/2010

8 Fuel Cadmium Content 0.1 ppm

8 Ultimate/Proximate Analysis 0

8 Fuel Nickel Content 17.56 ppm

8 Fuel Arsenic Content 4.381 ppm

8 Fuel Chromium Content 26.46 ppm

8 Fuel Beryllium Content 2.24 ppm

8 Fuel Lead Content 8.817 ppm

8 Fuel Manganese Content 7.067 ppm

8 Fuel Chlorine Content 1468 ppm

8 Fuel Fluorine Content 0 ppm

9 Fuel Higher Heating Value 12661 Btu/lb

9 Fuel Moisture 2.1 %

9 Fuel Mercury Content 0.049 ppm

9 Fuel Cadmium Content 0.083 ppm

9 Ultimate/Proximate Analysis 0

9 Fuel Nickel Content 16.64 ppm

9 Fuel Arsenic Content 2.544 ppm

9 Fuel Chromium Content 19.35 ppm

9 Fuel Beryllium Content 2.207 ppm

9 Fuel Lead Content 8.564 ppm

9 Fuel Manganese Content 7.381 ppm

9 Fuel Chlorine Content 1447 ppm

9 Fuel Fluorine Content 10 ppm

10 Fuel Higher Heating Value 12548 Btu/lb

10 Fuel Moisture 2.22 %

10 Fuel Mercury Content 0 ppm

10 Fuel Cadmium Content 0 ppm

10 Ultimate/Proximate Analysis 0

10 Fuel Nickel Content 0 ppm

10 Fuel Arsenic Content 0 ppm

10 Fuel Chromium Content 0 ppm

10 Fuel Beryllium Content 0 ppm

10 Fuel Lead Content 0 ppm

10 Fuel Manganese Content 0 ppm

10 Fuel Chlorine Content 1598 ppm

10 Fuel Fluorine Content 26 ppm

11 Fuel Higher Heating Value 12656 Btu/lb

11 Fuel Moisture 2.3 %

11 Fuel Mercury Content 0 ppm

11 Fuel Cadmium Content 0 ppm

11 Ultimate/Proximate Analysis 0

11 Fuel Nickel Content 0 ppm

11 Fuel Arsenic Content 0 ppm

Saturday, January 29, 2011 Page 18 of 27
50976 Indiantown Cogeneration

9/2/2010

11 Fuel Chromium Content 0 ppm

11 Fuel Beryllium Content 0 ppm

11 Fuel Lead Content 0 ppm

11 Fuel Manganese Content 0 ppm

11 Fuel Chlorine Content 1729 ppm

11 Fuel Fluorine Content 0 ppm

12 Fuel Higher Heating Value 12473 Btu/lb

12 Fuel Moisture 2.49 %

12 Fuel Mercury Content 0 ppm

12 Fuel Cadmium Content 0 ppm

12 Ultimate/Proximate Analysis 0

12 Fuel Nickel Content 0 ppm

12 Fuel Arsenic Content 0 ppm

12 Fuel Chromium Content 0 ppm

12 Fuel Beryllium Content 0 ppm

12 Fuel Lead Content 0 ppm

12 Fuel Manganese Content 0 ppm

12 Fuel Chlorine Content 1485 ppm

12 Fuel Fluorine Content 0 ppm

13 Fuel Higher Heating Value 12725 Btu/lb

13 Fuel Moisture 2.32 %

13 Fuel Mercury Content 0 ppm

13 Fuel Cadmium Content 0 ppm

13 Ultimate/Proximate Analysis 0

13 Fuel Nickel Content 0 ppm

13 Fuel Arsenic Content 0 ppm

13 Fuel Chromium Content 0 ppm

13 Fuel Beryllium Content 0 ppm

13 Fuel Lead Content 0 ppm

13 Fuel Manganese Content 0 ppm

13 Fuel Chlorine Content 1528 ppm

13 Fuel Fluorine Content 0 ppm

14 Fuel Higher Heating Value 12693 Btu/lb

14 Fuel Moisture 2.25 %

14 Fuel Mercury Content 0 ppm

14 Fuel Cadmium Content 0 ppm

14 Ultimate/Proximate Analysis 0

14 Fuel Nickel Content 0 ppm

14 Fuel Arsenic Content 0 ppm

14 Fuel Chromium Content 0 ppm

14 Fuel Beryllium Content 0 ppm

14 Fuel Lead Content 0 ppm

14 Fuel Manganese Content 0 ppm

Saturday, January 29, 2011 Page 19 of 27
50976 Indiantown Cogeneration

9/2/2010

14 Fuel Chlorine Content 1552 ppm

14 Fuel Fluorine Content 0 ppm

15 Fuel Higher Heating Value 12693 Btu/lb

15 Fuel Moisture 2.24 %

15 Fuel Mercury Content 0 ppm

15 Fuel Cadmium Content 0 ppm

15 Ultimate/Proximate Analysis 0

15 Fuel Nickel Content 0 ppm

15 Fuel Arsenic Content 0 ppm

15 Fuel Chromium Content 0 ppm

15 Fuel Beryllium Content 0 ppm

15 Fuel Lead Content 0 ppm

15 Fuel Manganese Content 0 ppm

15 Fuel Chlorine Content 1477 ppm

15 Fuel Fluorine Content 0 ppm

Saturday, January 29, 2011 Page 20 of 27
50976 Indiantown Cogeneration

9/2/2010

Sampling / Stack Data Results Detail

Location Stack Exit - Method 10

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Saturday, January 29, 2011 Page 21 of 27
50976 Indiantown Cogeneration

9/2/2010

Location Stack Exit - Method 25A

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Saturday, January 29, 2011 Page 22 of 27
50976 Indiantown Cogeneration

9/2/2010

Location Stack Exit - Method 26A

Average

Run Number 1 2 3

Test Date 6/6/2010 6/7/2010 6/7/2010

Run Start Time 3:03:00 PM 10:08:00 AM 1:19:00 PM

Run Finish Time 5:48:00 PM 12:53:00 PM 4:04:00 PM

Net Traversing Points 12 12 12

Net Run Time, minutes 180 180 180

Nozzle Diameter, inches 0.218 0.218 0.218 0.218

Pitot Tube Coefficient 0.84 0.84 0.84 0.840

Dry Gas Meter Calibration Factor 1.028 1.028 1.028 1.028

Barometric Pressure, inches of Mercury 29.99 29.99 29.99 29.990

Average Orifice Meter Differential, inches H2O 2.62 2.55 2.60 2.590

Dry Gas Meter Volume Sampled, cubic feet 157.061 155.407 160.156 157.541

Average Dry Gas Meter Temperature, °F 115.88 111.58 110.08 112.513

Dry Gas Meter Volume Sampled, dscf 149.334 148.848 153.819 150.667

Total Moisture Liquid collected, g 530.7 544.2 530.6 535.167

Volume of Water Vapor, standard cubic feet 24.98 25.62 24.98 25.193

Moisture Content of Stack Gas, % 14.33 14.68 13.97 14.327

Moisture Saturation at Stack Gas Temperature, % 60.62 59.10 59.10 59.607

Dry Mole Fraction 0.8567 0.8532 0.8603 0.857

Carbon Dioxide, % 13.1 12.9 12.8 12.933

Oxygen, % 6.1 6.4 6.2 6.233

Carbon Monoxide & Nitrogen, % 80.8 80.7 81 80.833

Fuel Factor 1.13 1.12 1.15

Dry Molecular Weight, lb/lb-Mole 30.34 30.32 30.30 30.320

Wet Molecular weight, lb/lb-Mole 28.57 28.51 28.58 28.553

Flue Gas Static Pressure, inches of H2O -0.5 -0.5 -0.5 -0.500

Absolute Flue Gas Pressure, inches of Mercury 29.95 29.95 29.95 29.950

Average Stack Gas Temperature, °F 187.92 186.75 186.75 187.140

Average Velocity Head, inches of H2O 1.5657028573

3907

1.552033677

98597

1.527264869

8903

1.548

Average Stack Gas Velocity, feet/second 78.19 77.86 77.14 77.730

Stack Cross-Sectional Area, square feet 231.452 231.452 231.452 231.452

Dry Volumetric Flow Rate, dry scfm 758,822.1 753,893.8 753,137.8 755,284.567

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,085,833.9 1,081,251.2 1,071,252.4 1,079,445.8

33

Percent Isokinetic of Sampling Rate, % 97.6 97.9 101.3 98.933

Percent Excess Air, % 40.0 42.9 40.8 41.233

F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000

Round Duct Diameter, inches 206 206 206

Rectangular Duct Width, inches 0 0 0

Rectangular Duct Length, inches 0 0 0

Fw 10640 10640 10640 10,640.000

Fc 1800 1800 1800 1,800.000

Saturday, January 29, 2011 Page 23 of 27
50976 Indiantown Cogeneration

9/2/2010

Location Stack Exit - Method 29

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Net Traversing Points

Net Run Time, minutes

Nozzle Diameter, inches

Pitot Tube Coefficient

Dry Gas Meter Calibration Factor

Barometric Pressure, inches of Mercury

Average Orifice Meter Differential, inches H2O

Dry Gas Meter Volume Sampled, cubic feet

Average Dry Gas Meter Temperature, °F

Dry Gas Meter Volume Sampled, dscf

Total Moisture Liquid collected, g

Volume of Water Vapor, standard cubic feet

Moisture Content of Stack Gas, %

Moisture Saturation at Stack Gas Temperature, %

Dry Mole Fraction

Carbon Dioxide, %

Oxygen, %

Carbon Monoxide & Nitrogen, %

Fuel Factor

Dry Molecular Weight, lb/lb-Mole

Wet Molecular weight, lb/lb-Mole

Flue Gas Static Pressure, inches of H2O

Absolute Flue Gas Pressure, inches of Mercury

Average Stack Gas Temperature, °F

Average Velocity Head, inches of H2O

Average Stack Gas Velocity, feet/second

Stack Cross-Sectional Area, square feet

Dry Volumetric Flow Rate, dry scfm

Actual Wet Volumetric Flue Gas Flow Rate, acfm

Percent Isokinetic of Sampling Rate, %

Percent Excess Air, %

F-Factor, dscfm/MMBtu @ %O2

Round Duct Diameter, inches

Rectangular Duct Width, inches

Rectangular Duct Length, inches

Fw

Fc

Saturday, January 29, 2011 Page 24 of 27
50976 Indiantown Cogeneration

9/2/2010

Location Stack Exit - Method 6C

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Saturday, January 29, 2011 Page 25 of 27
50976 Indiantown Cogeneration

9/2/2010

Location Stack Exit - Method 7E

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Saturday, January 29, 2011 Page 26 of 27
50976 Indiantown Cogeneration

9/2/2010

Location Stack Exit - OTM - 27/28

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Net Traversing Points

Net Run Time, minutes

Nozzle Diameter, inches

Pitot Tube Coefficient

Dry Gas Meter Calibration Factor

Barometric Pressure, inches of Mercury

Average Orifice Meter Differential, inches H2O

Dry Gas Meter Volume Sampled, cubic feet

Average Dry Gas Meter Temperature, °F

Dry Gas Meter Volume Sampled, dscf

Total Moisture Liquid collected, g

Volume of Water Vapor, standard cubic feet

Moisture Content of Stack Gas, %

Moisture Saturation at Stack Gas Temperature, %

Dry Mole Fraction

Carbon Dioxide, %

Oxygen, %

Carbon Monoxide & Nitrogen, %

Fuel Factor

Dry Molecular Weight, lb/lb-Mole

Wet Molecular weight, lb/lb-Mole

Flue Gas Static Pressure, inches of H2O

Absolute Flue Gas Pressure, inches of Mercury

Average Stack Gas Temperature, °F

Average Velocity Head, inches of H2O

Average Stack Gas Velocity, feet/second

Stack Cross-Sectional Area, square feet

Dry Volumetric Flow Rate, dry scfm

Actual Wet Volumetric Flue Gas Flow Rate, acfm

Percent Isokinetic of Sampling Rate, %

Percent Excess Air, %

F-Factor, dscfm/MMBtu @ %O2

Round Duct Diameter, inches

Rectangular Duct Width, inches

Rectangular Duct Length, inches

Fw

Fc

Saturday, January 29, 2011 Page 27 of 27