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.

Friday, January 28, 2011 Page 1 of 16
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:

EU001 Boiler #1

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 0 0 0 1632 1668 3 12

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Stack Exit % H2O Method 1 - 4 3 360 0

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 

Stack Exit Flowrate Method 1 - 4 3 0

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

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

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 that 

will 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

Friday, January 28, 2011 Page 11 of 16
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