### 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: Boiler #1 01 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 1792 3000 4 0 12 0 0

Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location % 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 Stack Exit



### Saturday, January 29, 2011 Page 2 of 27

### 50976 Indiantown Cogeneration
9/2/2010 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 Stack Exit 2,3,3',4,4',5/2,3,3',4,4',5'-

HxCB (PCBs156/157) 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 Stack Exit 2,3,3',4,4',5,5'-HpCB

(PCB189) Method 23 3 480 0 Stack Exit

Total PCBs Method 23 3 480 0 Stack Exit Total TEQ Method 23 3 480 0 Stack Exit Total organic compounds

(TOC) as Propane Method 25A 3 120 0 Stack Exit
Hydrogen Chloride Method 26 3 180 0 Stack Exit Hydrogen Fluoride Method 26 3 180 0 Stack Exit 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

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 Stack Exit 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

Filterable Particulate Method 5 3 240 0 Stack Exit Filterable Particulate Method 5/OTM-28 3 240 0 Use only for wet stacks. Delete OTM27/OTM28 test. Stack Exit

Sulfur Dioxide Method 6C 3 180 0 Stack Exit Nitrogen oxides (NOx) Method 7E 3 180 0 Stack Exit



### Saturday, January 29, 2011 Page 4 of 27

### 50976 Indiantown Cogeneration
9/2/2010 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
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 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
9/2/2010
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
9/2/2010
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
9/2/2010
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
9/2/2010
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
9/2/2010 Process Run Data



### Run Name Value UOM Comments Target Value 3 Heat Input 2882.9 Million Btus/hr 6/7/10 0


### 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 lime 0



### 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 6/9/10 0
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
9/2/2010 4 Sorbent Type and Sorbent Injection Rate (if applicable) 0 lb/hr lime 0



### 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 6/5/10 0
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 lime 0

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 6/6/10 0


### 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
9/2/2010

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 lime 0

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