### Name: Scott McQuiston

Title: Environmental Regulatory Compliance Company: Lansing Board of Water & Light Sign Date: Name: Thomas Schmelter Title: Project Manager Company: Bureau Veritas North America Inc. Sign Date: Permitted Facility Representative / Date Testing Company Representative / Date



## Lansing Board of Water and Light - Erickson Station

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.

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### Lansing Board of Water and Light - Erickson Station

Facility Information:
Erickson Station
3725 South Canal Road

Lansing MI 48917 Contact: Scott McQuiston Phone: 571.702.6362 Fax: Email: sdm@lbwl.com Testing Company:
Bureau Veritas North America Inc.
45525 Grand River Ave.

Novi MI 48374 Contact: Thomas Schmelter Phone: 248.344.3003 Fax: 248.344.2656 Email: Thomas.schmelter@us.bureauveritas.co

Air Permit Number: MI-ROP-B4001-2005 Permitted Source ID/Name: Boiler #1 EU001 Permitted Maximum Process Rate: N/A Max. Normal Operation Process Rate: 165 MW Target Process Test Rate 155MW - 165MW

Description of the source (including control equipment). Please see the attachments for source or process flow diagram: Lansing Board of Water and Light operates a single coal fired steam generator capable of producing 165 MW of electricity that provides electricity to 96,000 residential, commercial, and industrial customers and is connected to the power grid by three 138,000-volt lines. At the Erickson station silos feed coal pulverizers (coal mills) 2-inch pieces of coal, grind them to a fine powder, which is mixed with primary combustion air. The pulverized coal is air-blown into the furnace from fuel nozzles and is rapidly burnt forming a large flame at the center of the boiler. The thermal radiation of the flame heats the water that circulates through the boiler tubes near the boiler perimeter. The gas exiting the boiler is passed through an electrostatic precipitator to remove fine particulates known as fly ash and the gas is exhausted to atmosphere. Industry/SCC/NAIS 221112

Sampling Location Information:

Test Parameter Information: AFS #: 2604500013 FRS #: 110000787818

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 204 1632 1668 3 0 12 0 0

Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location % H2O Method 1 - 4 3 360 0 Stack Exit Regulation Description Compound Limit Unit Not Applicable EPA 114 ICR 0



### Friday, January 28, 2011 Page 2 of 16

### Lansing Board of Water and Light - Erickson Station

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. Fuel samples could not be collected as outlined in Table 2.1 for the belt feeder. The belt feeder could not be stopped during boiler operation. Fuel samples were collected from the feeder and processed as specified in Section 2.2 through 2.5 of the 114 request letter.
The procedures for preparation of mercury standards and sample analysis in Sections 13.4.1.1 through 13.4.1.3 of ASTM D6784-02 were followed instead of the procedures in Sections 7.5.33 and 11.1.3 of Method 29; and The QA/QC procedures in Section 13.4.2 of ASTM D6784-02 were performed instead of the procedures in Section 9.2.3 of Method 29.
Minor field test changes were required to complete the emissions testing as proposed. The changes addressed the physical obstruction in the north sampling port and the pre- and post-test leak checks. Discussions between Lansing Board of Water and Light, Bureau Veritas, and the DNRE resolved these issues onsite and the testing was completed

Flowrate Method 1 - 4 3 0 Stack Exit Filterable Particulate OTM - 27/28 3 360 0 collect a minimum volume of 3.4 cubic meters and have a minimum sample time of 4 hours per run. Stack Exit

Total Particulate OTM - 27/28 3 360 0 collect a minimum volume of 3.4 cubic meters and have a minimum sample time of 4 hours per run. Stack Exit

Filterable PM10 OTM - 27/28 3 360 0 collect a minimum volume of 3.4 cubic meters and have a minimum sample time of 4 hours per run. Stack Exit

Filterable PM2.5 - PM10 OTM - 27/28 3 360 0 collect a minimum volume of 3.4 cubic meters and have a minimum sample time of 4 hours per run. Stack Exit

Filterable PM2.5 OTM - 27/28 3 360 0 collect a minimum volume of 3.4 cubic meters and have a minimum sample time of 4 hours per run. Stack Exit

Arsenic Method 29 3 360 0 Stack Exit Beryllium Method 29 3 360 0 Stack Exit Cadmium Method 29 3 360 0 Stack Exit Chromium Method 29 3 360 0 Stack Exit Manganese Method 29 3 360 0 Stack Exit Nickel Method 29 3 360 0 Stack Exit Antimony Method 29 3 360 0 Stack Exit Cobalt Method 29 3 360 0 Stack Exit Filterable Particulate Method 29 3 360 0 Stack Exit Phosphorus (yellow or white) Method 29 3 360 0 Stack Exit Mercury Method 29 3 360 0 Stack Exit Selenium Method 29 3 360 0 Stack Exit Co2 Method 3A CO2 3 360 0 Stack Exit O2 Method 3A O2 3 360 0 Stack Exit



### Friday, January 28, 2011 Page 3 of 16

### Lansing Board of Water and Light - Erickson Station

in accordance with established requirements.
In the north port, the sampling probes could not be inserted into the interior of the stack due to a physical obstruction (debris). Several times, Bureau Veritas attempted to dislodge the obstruction using a 3-inch-diameter steel pipe; however, the obstruction could not be removed and the port could not be traversed with the sampling trains. Due to the 17-foot-diameter of the stack, sampling using two perpendicular sampling ports was not feasible. Bureau Veritas informed the DNRE representative and LBWL personnel onsite of this issue. DNRE authorized continuing the emissions testing and traversing one of the other three accessible sampling ports twice as a substitution for the north port. Based on the distances from the upstream and downstream disturbances, the flue gas at the sampling port elevation is most likely well mixed and not stratified; thus this sampling variation is not considered to have significantly affected the results of the emissions tests.



### Friday, January 28, 2011 Page 4 of 16

### Lansing Board of Water and Light - Erickson Station

Friday, January 28, 2011 Page 5 of 16

### Lansing Board of Water and Light - Erickson Station

Sampling / Stack Data Results Summary



### Location Stack Exit - Method 29 Average Run Number 1 2 3
Test Date 5/19/2010 5/20/2010 5/20/2010 Run Start Time 4:03:00 PM 8:20:00 AM 4:15:00 PM

Run Finish Time 10:54:00 PM 3:10:00 PM 11:12:00 PM Net Run Time, minutes 360 360 360 Dry Gas Meter Volume Sampled, dscf 247.735 252.730 256.566 252.344 Moisture Content of Stack Gas, % 10.59 10.63 9.65 10.290 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Carbon Dioxide, % 14.6 15.2 12.8 14.200 Oxygen, % 6 6.4 5.7 6.033 Average Stack Gas Temperature, °F 336.33 332.08 335.33 334.580 Dry Volumetric Flow Rate, dry scfm 429,801.2 434,378.5 441,765.7 435,315.133 Actual Wet Volumetric Flue Gas Flow Rate, acfm 724,520.2 727,924.9 735,279.0 729,241.367 Percent Isokinetic of Sampling Rate, % 98.6 99.5 99.3 99.133 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



### Location Stack Exit - Method 3A CO2 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



### Friday, January 28, 2011 Page 6 of 16

### Lansing Board of Water and Light - Erickson Station

Location Stack Exit - Method 3A O2 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



### Friday, January 28, 2011 Page 7 of 16

### Lansing Board of Water and Light - Erickson Station

Emissions Summary



### Location: Stack Exit - Method 29 Compound: Antimony Average RunNumber 1 2 3 Mass_mg 0.0011 0.004 0.0011 0.002 Elb/hr 2.52E-04 9.09E-04 2.51E-04 0.000 mg/dscm 1.57E-04 5.59E-04 1.51E-04 0.000 

### Compound: Arsenic Average RunNumber 1 2 3 Mass_mg 0.014 0.0095 0.0107 0.011 Elb/hr 3.21E-03 2.16E-03 2.44E-03 0.003 mg/dscm 2.00E-03 1.33E-03 1.47E-03 0.002 

### Compound: Beryllium Average RunNumber 1 2 3 Mass_mg 0.0005 0.0006 0.00062 0.001 Elb/hr 1.15E-04 1.36E-04 1.41E-04 0.000 mg/dscm 7.13E-05 8.39E-05 8.54E-05 0.000 

### Compound: Cadmium Average RunNumber 1 2 3 Mass_mg 0.00067 0.00076 0.0007 0.001 Elb/hr 1.54E-04 1.73E-04 1.59E-04 0.000 mg/dscm 9.55E-05 1.06E-04 9.64E-05 0.000 

### Compound: Chromium Average RunNumber 1 2 3 Mass_mg 0.0176 0.0178 0.0178 0.018 Elb/hr 4.04E-03 4.05E-03 4.05E-03 0.004 mg/dscm 2.51E-03 2.49E-03 2.45E-03 0.002 

### Compound: Cobalt Average RunNumber 1 2 3 Mass_mg 0.0034 0.003 0.0037 0.003 Elb/hr 7.80E-04 6.82E-04 8.43E-04 0.001 mg/dscm 4.85E-04 4.19E-04 5.09E-04 0.000 

### Compound: Filterable Particulate Average RunNumber 1 2 3 Mass_mg 85.5 81.1 91.3 85.967 Elb/hr 1.96E+01 1.84E+01 2.08E+01 19.600 mg/dscm 1.22E+01 1.13E+01 1.26E+01 12.033



### Friday, January 28, 2011 Page 8 of 16

### Lansing Board of Water and Light - Erickson Station

Compound: Manganese Average RunNumber 1 2 3 Mass_mg 0.034 0.027 0.03 0.030 Elb/hr 7.80E-03 6.14E-03 6.83E-03 0.007 mg/dscm 4.85E-03 3.77E-03 4.13E-03 0.004 

### Compound: Mercury Average RunNumber 1 2 3 Mass_mg 0.0178 0.0224 0.0201 0.020 Elb/hr 4.08E-03 5.09E-03 4.58E-03 0.005 mg/dscm 2.54E-03 3.13E-03 2.77E-03 0.003 

### Compound: Nickel Average RunNumber 1 2 3 Mass_mg 0.0515 0.027 0.0239 0.034 Elb/hr 1.18E-02 6.14E-03 5.44E-03 0.008 mg/dscm 7.34E-03 3.77E-03 3.29E-03 0.005 

### Compound: Phosphorus (yellow or white) Average RunNumber 1 2 3 Mass_mg 1.5061 0.9994 1.164 1.223 Elb/hr 3.46E-01 2.27E-01 2.65E-01 0.279 mg/dscm 2.15E-01 1.40E-01 1.60E-01 0.172 

### Compound: Selenium Average RunNumber 1 2 3 Mass_mg 0.0146 0.0142 0.0229 0.017 Elb/hr 3.35E-03 3.23E-03 5.22E-03 0.004 mg/dscm 2.08E-03 1.98E-03 3.15E-03 0.002



### Location: Stack Exit - OTM - 27/28 

### Compound: Filterable Particulate Average RunNumber 1 2 3 Mass_mg 0.5 26 30 18.833 

### Compound: Filterable PM10 Average RunNumber 1 2 3 Mass_mg 17 2.7 0.5 6.733 

### Compound: Filterable PM2.5 Average RunNumber 1 2 3 Mass_mg 27 4.4 5.2 12.200 

### Compound: Filterable PM2.5 - PM10 Average


### Friday, January 28, 2011 Page 9 of 16

### Lansing Board of Water and Light - Erickson Station

Process Run Data RunNumber 1 2 3 Mass_mg 1.8 4.4 7.9 4.700 

### Compound: Inorganic (Aqueous) Condensable P Average RunNumber 1 2 3 Mass_mg 19 4.7 30 17.900 

### Compound: Organic Condensable Particulate Average RunNumber 1 2 3 Mass_mg 6.6 16 30 17.533 

### Compound: Total Particulate Average RunNumber 1 2 3 Mass_mg 46.3 37.5 43.6 42.467



### Friday, January 28, 2011 Page 10 of 16

### Lansing Board of Water and Light - Erickson Station

Process Run Data

APCD Run Data

Process Lab Run Data 

### Run Name Value UOM Comments Target Value 1 Coal Burned 90 100 Tons/hr 100


### 2 Coal Burned 92 100 Tons/hr There is an error in the software thatwill not prepopulate the missing values from Run1. Please see Run1 for more information. 100

3 Coal Burned 92 100 Tons/hr 100
1 Average Heat Input 2276.5 MMBtu/hr 1668
2 Average Heat Input 2304.8 MMBtu/hr 1668


### 3 Average Heat Input 2294.7 MMBtu/hr 1668
1 Steam Output 1110.3 1000 lb steam/hr 1100
2 Steam Output 1114 1000 lb steam/hr 1100


### 3 Steam Output 1113.5 1000 lb steam/hr 1100
1 Flue Gas Flow Rate 448890 scfm 470000
2 Flue Gas Flow Rate 449040 scfm 470000


### 3 Flue Gas Flow Rate 447520 scfm 470000
1 Flue Gas Sampling Point Temperature 330 Deg F 330
2 Flue Gas Sampling Point Temperature 330 Deg F 330


### 3 Flue Gas Sampling Point Temperature 330 Deg F 330
1 Unit Gross Electrical Output 166.07 Mwe 165
2 Unit Gross Electrical Output 166.87 Mwe 165


### 3 Unit Gross Electrical Output 167.52 Mwe 165
1 Unit Net Electric Generation 152.78 MWh 152
2 Unit Net Electric Generation 153.52 MWh 152


### 3 Unit Net Electric Generation 154.12 MWh 152

Run Name Value UOM Comments Target Value 1 ELECTROSTATIC PRECIPITATOR 0 0

Run Name Value UOM Comments 

### 1 Fuel Higher Heating Value 8638 Btu/lb
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### Lansing Board of Water and Light - Erickson Station

1 8638 Btu/lb 2 Fuel Higher Heating Value 8870 Btu/lb 

### 3 Fuel Higher Heating Value 8905 Btu/lb 1 Fuel Moisture 27.33 % 2 Fuel Moisture 26.87 % 

### 3 Fuel Moisture 26.65 % 1 Fuel Mercury Content 0.09 ppm 2 Fuel Mercury Content 0.05 ppm 3 Fuel Mercury Content 0.06 ppm 

### 1 Fuel Cadmium Content 0.09 ppm 2 Fuel Cadmium Content 0.14 ppm 3 Fuel Cadmium Content 0.11 ppm 1 Ultimate/Proximate Analysis 0 

### 2 Ultimate/Proximate Analysis 0 3 Ultimate/Proximate Analysis 0 1 Fuel Nickel Content 4.68 ppm 

### 2 Fuel Nickel Content 5.94 ppm 3 Fuel Nickel Content 4.85 ppm 1 Fuel Arsenic Content 1.15 ppm 2 Fuel Arsenic Content 1.35 ppm 

### 3 Fuel Arsenic Content 1.16 ppm 1 Fuel Chromium Content 5.17 ppm 2 Fuel Chromium Content 5.68 ppm 

### 3 Fuel Chromium Content 4.66 ppm 1 Fuel Beryllium Content 0.28 ppm 2 Fuel Beryllium Content 0.37 ppm 3 Fuel Beryllium Content 0.28 ppm 

### 1 Fuel Lead Content 1.42 ppm 2 Fuel Lead Content 1.79 ppm 3 Fuel Lead Content 2.02 ppm 

### 1 Fuel Manganese Content 10.92 ppm 2 Fuel Manganese Content 11.6 ppm 3 Fuel Manganese Content 10.53 ppm 1 Fuel Chlorine Content 58 ppm 

### 2 Fuel Chlorine Content 54 ppm 3 Fuel Chlorine Content 80 ppm 1 Fuel Fluorine Content 35 ppm 

### 2 Fuel Fluorine Content 41 ppm 3 Fuel Fluorine Content 45 ppm 1 Fuel Cobalt Content 2.83 ppm 2 Fuel Cobalt Content 3.54 ppm 

### 3 Fuel Cobalt Content 2.75 ppm 1 Fuel Selenium Content 5.01 ppm 2 Fuel Selenium Content 0.46 ppm



### Friday, January 28, 2011 Page 12 of 16

### Lansing Board of Water and Light - Erickson Station

3 Fuel Selenium Content 0.96 ppm



### Friday, January 28, 2011 Page 13 of 16

### Lansing Board of Water and Light - Erickson Station

Sampling / Stack Data Results Detail



### Location Stack Exit - Method 29 Average Run Number 1 2 3 Test Date 5/19/2010 5/20/2010 5/20/2010 Run Start Time 4:03:00 PM 8:20:00 AM 4:15:00 PM Run Finish Time 10:54:00 PM 3:10:00 PM 11:12:00 PM Net Traversing Points 12 12 12 Net Run Time, minutes 360 360 360 Nozzle Diameter, inches 0.26 0.26 0.26 0.260 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 1.015 1.015 1.015 1.015 Barometric Pressure, inches of Mercury 30.03 30.06 30.06 30.050 Average Orifice Meter Differential, inches H2O 1.61 1.63 1.63 1.623 Dry Gas Meter Volume Sampled, cubic feet 250.501 252.055 255.126 252.561 Average Dry Gas Meter Temperature, °F 86.04 79.13 77.54 80.903 Dry Gas Meter Volume Sampled, dscf 247.735 252.730 256.566 252.344 Total Moisture Liquid collected, g 623.2 638.8 582.2 614.733 Volume of Water Vapor, standard cubic feet 29.33 30.07 27.40 28.933 Moisture Content of Stack Gas, % 10.59 10.63 9.65 10.290 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Dry Mole Fraction 0.8941 0.8937 0.9035 0.897 Carbon Dioxide, % 14.6 15.2 12.8 14.200 Oxygen, % 6 6.4 5.7 6.033 Carbon Monoxide & Nitrogen, % 79.4 78.4 81.5 79.767 Fuel Factor 1.02 0.95 1.19 Dry Molecular Weight, lb/lb-Mole 30.58 30.69 30.28 30.517 Wet Molecular weight, lb/lb-Mole 29.25 29.34 29.09 29.227 Flue Gas Static Pressure, inches of H2O -1.2 -1.2 -1.2 -1.200 Absolute Flue Gas Pressure, inches of Mercury 29.94 29.97 29.97 29.960 Average Stack Gas Temperature, °F 336.33 332.08 335.33 334.580 Average Velocity Head, inches of H2O 0.6035522481 50484 0.614908277

133791 0.619542313

473383 0.613
Average Stack Gas Velocity, feet/second 53.20 53.45 53.99 53.547 Stack Cross-Sectional Area, square feet 226.980 226.980 226.980 226.980 Dry Volumetric Flow Rate, dry scfm 429,801.2 434,378.5 441,765.7 435,315.133 Actual Wet Volumetric Flue Gas Flow Rate, acfm 724,520.2 727,924.9 735,279.0 729,241.367 Percent Isokinetic of Sampling Rate, % 98.6 99.5 99.3 99.133 Percent Excess Air, % 40.1 44.8 36.0 40.300 F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000 Round Duct Diameter, inches 204 204 204 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



### Friday, January 28, 2011 Page 14 of 16

### Lansing Board of Water and Light - Erickson Station

Location Stack Exit - Method 3A CO2 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



### Friday, January 28, 2011 Page 15 of 16

### Lansing Board of Water and Light - Erickson Station

Location Stack Exit - Method 3A O2 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



### Friday, January 28, 2011 Page 16 of 16

### Lansing Board of Water and Light - Erickson Station

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



### Friday, January 28, 2011 Page 17 of 16