Name: Robert A. Greco

Title: Manager, Air Quality

Company: We Energies

Sign Date: 6/30/2010

Name: Scott W. Banach

Title: Director, Project Engineering

Company: Platt Environmental Services, Inc.

Sign Date: 6/30/2010

Permitted Facility Representative / Date Testing Company Representative / Date

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.

Monday, February 07, 2011 Page 1 of 9
6/30/2010

Facility Information:

Pleasant Prairie (ORIS Facility ID #6170)

8000 95th Street

Pleasant Prairie WI 53158

Contact: Robert A. Greco

Phone: (414) 221-5441

Fax: (414) 221-2022

Email: bob.greco@we-energies.com

Testing Company:

Platt Environmental Services, Inc.

1520 Kensington Road, Suite 204

Oak Brook IL 60523

Contact: Scott W. Banach

Phone: (630) 521-9400

Fax: (630) 521-9494

Email: sbanach@plattenv.com

Air Permit Number:

6170

Permitted Source ID/Name:

2 Pleasant Prairie

Permitted Maximum Process Rate:

N/A

Max. Normal Operation Process Rate:

N/A

Target Process Test Rate

N/A

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

 process flow diagram:

Pleasant Prairie Power Plant is a steam electric generating plant. The plant includes two identical side by side 

pulverized sub-bituminous coal fired steam electric generating units (B20 and B21). Each of two fossil fuel fired 

steam electric generating units consists of a boiler, turbine, and electric generator. Each is a natural circulation Riley 

Stoker Corporation type, integral superheater and reheater, single drum radiant heat boiler. The furnace is a Riley 

Turbo design constructed for balanced draft operation. The main fuel supply is pulverized coal with natural gas or 

fuel oil igniters used for coal flame stabilization during start-up and shutdown operations. Majority of emissions are 

controlled by selective catalytic reduction (SCR) system, electrostatic precipitator (ESP), and flue gas desulfurization 

(FGD) system.

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.

Industry/SCC/NAIS 221112

Sampling Location Information:

Test Parameter Information:

AFS #: 5505960002 FRS #: 20847

SCC / Description 10100222 External Combustion Boilers - Electric Generation - Bituminous/Subbituminous 

Coal - Pulverized Coal: Dry Bottom (Subbituminous 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 192 0 0 0 1158 2627.75 4 12

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Stack Exit Hydrogen Fluoride Method 26A 3 180 0

Stack Exit Hydrogen Chloride Method 26A 3 180 0

Monday, February 07, 2011 Page 2 of 9
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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.

All methods described in the EU MACT ICR were used.

Monday, February 07, 2011 Page 3 of 9
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Sampling / Stack Data Results Summary

Location Stack Exit - Method 26A

Average

Run Number M26A-1 M26A-2 M26A-3

Test Date 4/14/2010 4/15/2010 4/15/2010

Run Start Time 11:35:00 AM 7:25:00 

AM

10:55:00 AM

Run Finish Time 2:48:00 PM 10:38:00 

AM

2:13:00 PM

Net Run Time, minutes 180 180 180

Dry Gas Meter Volume Sampled, dscf 149.791 149.587 145.993 148.457

Moisture Content of Stack Gas, % 16.37 14.95 16.66 15.993

Moisture Saturation at Stack Gas Temperature, % 15.87 15.64 15.54 15.683

Carbon Dioxide, % 13.3 12.9 12.9 13.033

Oxygen, % 5.7 6.1 6.1 5.967

Average Stack Gas Temperature, °F 130.81 130.25 130.00 130.353

Dry Volumetric Flow Rate, dry scfm 556,175.1 565,555.9 553,185.5 558,305.500

Actual Wet Volumetric Flue Gas Flow Rate, acfm 761,100.1 764,839.8 753,017.4 759,652.433

Percent Isokinetic of Sampling Rate, % 102.5 100.6 100.4 101.167

F-Factor, dscfm/MMBtu @ %O2 9820 9820 9820 9,820.000

Fw 0 0 0 0.000

Fc 1840 1840 1840 1,840.000

Monday, February 07, 2011 Page 4 of 9
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Emissions Summary

Process Run Data

Location: Stack Exit - Method 26A

Compound: Hydrogen Chloride

Average

RunNumber M26A-1 M26A-2 M26A-3

Mass_mg 0.49 0.51 0.39 0.463

Elb/hr 2.41E-01 2.55E-01 1.95E-01 0.230

lb/mmBtuO2 9.74E-05 1.04E-04 8.17E-05 0.000

mg/dscm 1.16E-01 1.20E-01 9.44E-02 0.110

mg/dscm@7%O2 1.06E-01 1.13E-01 8.87E-02 0.103

Compound: Hydrogen Fluoride

Average

RunNumber M26A-1 M26A-2 M26A-3

Mass_mg 0.35 0.4 0.37 0.373

Elb/hr 1.72E-01 2.00E-01 1.85E-01 0.186

lb/mmBtuO2 6.96E-05 8.18E-05 7.75E-05 0.000

mg/dscm 8.25E-02 9.44E-02 8.95E-02 0.089

mg/dscm@7%O2 7.54E-02 8.87E-02 8.41E-02 0.083

Monday, February 07, 2011 Page 5 of 9
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Process Run Data

Run Name Value UOM Comments

Target

Value

1 Subbituminous Coal Burned 384.6 1000 Tons/hr 0

2 Subbituminous Coal Burned 385.13 1000 Tons/hr 0

3 Subbituminous Coal Burned 371.73 1000 Tons/hr 0

1 Average Heat Input 6842.7 MMBtu/hr 0

2 Average Heat Input 6778.8 MMBtu/hr 0

3 Average Heat Input 6856.8 MMBtu/hr 0

1 Steam Output 4308.0 1000 lb steam/hr 0

2 Steam Output 4267.5 1000 lb steam/hr 0

3 Steam Output 4280.7 1000 lb steam/hr 0

1 Synfuel Firing Rate 0 1000 Tons/hr 0

2 Synfuel Firing Rate 0 1000 Tons/hr 0

3 Synfuel Firing Rate 0 1000 Tons/hr 0

1 Petroleum Coke Firing Rate 0 1000 Tons/hr 0

2 Petroleum Coke Firing Rate 0 1000 Tons/hr 0

3 Petroleum Coke Firing Rate 0 1000 Tons/hr 0

1 Coal Gas Firing Rate 0 Ft^3/min 0

2 Coal Gas Firing Rate 0 Ft^3/min 0

3 Coal Gas Firing Rate 0 Ft^3/min 0

1 Fuel Oil Firing Rate 0 gal/hr 0

2 Fuel Oil Firing Rate 0 gal/hr 0

3 Fuel Oil Firing Rate 0 gal/hr 0

1 Flue Gas Flow Rate 2E+06 0 DSCFM

1 Pressure Drop Across FGD (if applicable) 6.35 in H20 0

1 FGD Scrubber Liquor pH 0 pH 0

1 FGD Scrubber Liquor Flow Rate 278.62 gal/min 0

1 Sorbent Type and Sorbent Injection Rate (if 

applicable)

19190 lb/hr 0

1 Flue Gas Oxygen Content 1.869 % 0

1 Flue Gas Carbon Dioxide Content 11.988 % 0

1 Flue Gas Moisture Content % 0

1 Flue Gas Sampling Point Temperature 134.98 Deg F 0

1 Flue Gas Pressure 0.016 atm 0

1 Standard Pressure 1 atm 0

1 Standard Temperature 63.33 Deg F 0

Monday, February 07, 2011 Page 6 of 9
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APCD Run Data

Process Lab Run Data

1 Unit Gross Electrical Output 642.27 Mwe 0

1 Unit Net Electric Generation 591.66 MWh 0

Run Name Value UOM Comments

Target

Value

1 SCR (SELECTIVE CATALYTIC REDUCTION) 0.059 lb/mmBtu 0.1

2 SCR (SELECTIVE CATALYTIC REDUCTION) 0.063 lb/mmBtu 0.1

3 SCR (SELECTIVE CATALYTIC REDUCTION) 0.062 lb/mmBtu 0.1

1 ELECTROSTATIC PRECIPITATOR 0.007 lb/mmBtu 0.03

2 ELECTROSTATIC PRECIPITATOR 0.01 lb/mmBtu 0.03

3 ELECTROSTATIC PRECIPITATOR 0.007 lb/mmBtu 0.03

1 FGD 0.035 lb/mmBtu 0.1

2 FGD 0.035 lb/mmBtu 0.1

3 FGD 0.034 lb/mmBtu 0.1

Run Name Value UOM Comments

1 Fuel Higher Heating Value 12002 Btu/lb

1 Fuel Moisture 23.01 %

1 Fuel Mercury Content 0.11 ppm

1 Fuel Cadmium Content 0.084 ppm

1 Ultimate/Proximate Analysis 0

1 Fuel Nickel Content 12 ppm

1 Fuel Arsenic Content 0.94 ppm

1 Fuel Chromium Content 5 ppm

1 Fuel Beryllium Content 0.29 ppm

1 Fuel Lead Content 2.9 ppm

1 Fuel Manganese Content 16 ppm

1 Fuel Chlorine Content 36 ppm

1 Fuel Fluorine Content 90 ppm

2 Fuel Higher Heating Value 12025 Btu/lb

2 Fuel Moisture 22.56 %

2 Fuel Mercury Content 0.078 ppm

2 Fuel Cadmium Content 0.08 ppm

2 Ultimate/Proximate Analysis 0

2 Fuel Nickel Content 6.7 ppm

2 Fuel Arsenic Content 1 ppm

2 Fuel Chromium Content 4.6 ppm

2 Fuel Beryllium Content 0.25 ppm

Monday, February 07, 2011 Page 7 of 9
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2 Fuel Lead Content 3.2 ppm

2 Fuel Manganese Content 19 ppm

2 Fuel Chlorine Content 35 ppm

2 Fuel Fluorine Content 87 ppm

3 Fuel Higher Heating Value 12073 Btu/lb

3 Fuel Moisture 20.46 %

3 Fuel Mercury Content 0.076 ppm

3 Fuel Cadmium Content 0.11 ppm

3 Ultimate/Proximate Analysis 0

3 Fuel Nickel Content 4.4 ppm

3 Fuel Arsenic Content 1.1 ppm

3 Fuel Chromium Content 5.2 ppm

3 Fuel Beryllium Content 0.25 ppm

3 Fuel Lead Content 2.7 ppm

3 Fuel Manganese Content 23 ppm

3 Fuel Chlorine Content 37 ppm

3 Fuel Fluorine Content 84 ppm

Monday, February 07, 2011 Page 8 of 9
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Sampling / Stack Data Results Detail

Location Stack Exit - Method 26A

Average

Run Number M26A-1 M26A-2 M26A-3

Test Date 4/14/2010 4/15/2010 4/15/2010

Run Start Time 11:35:00 AM 7:25:00 AM 10:55:00 AM

Run Finish Time 2:48:00 PM 10:38:00 AM 2:13:00 PM

Net Traversing Points 40 40 40

Net Run Time, minutes 180 180 180

Nozzle Diameter, inches 0.232 0.232 0.232 0.232

Pitot Tube Coefficient 0.84 0.84 0.84 0.840

Dry Gas Meter Calibration Factor 0.997 0.997 0.997 0.997

Barometric Pressure, inches of Mercury 29.15 29.15 29.15 29.150

Average Orifice Meter Differential, inches H2O 2.02 2.05 2.00 2.023

Dry Gas Meter Volume Sampled, cubic feet 160.368 161.211 157.980 159.853

Average Dry Gas Meter Temperature, °F 91.88 95.58 97.78 95.080

Dry Gas Meter Volume Sampled, dscf 149.791 149.587 145.993 148.457

Total Moisture Liquid collected, g 623.1 558.5 619.9 600.500

Volume of Water Vapor, standard cubic feet 29.33 26.29 29.18 28.267

Moisture Content of Stack Gas, % 16.37 14.95 16.66 15.993

Moisture Saturation at Stack Gas Temperature, % 15.87 15.64 15.54 15.683

Dry Mole Fraction 0.8413 0.8505 0.8446 0.845

Carbon Dioxide, % 13.3 12.9 12.9 13.033

Oxygen, % 5.7 6.1 6.1 5.967

Carbon Monoxide & Nitrogen, % 81 81 81 81.000

Fuel Factor 1.14 1.15 1.15

Dry Molecular Weight, lb/lb-Mole 30.36 30.31 30.31 30.327

Wet Molecular weight, lb/lb-Mole 28.49 28.47 28.60 28.520

Flue Gas Static Pressure, inches of H2O -1 -1 -1 -1.000

Absolute Flue Gas Pressure, inches of Mercury 29.08 29.08 29.08 29.080

Average Stack Gas Temperature, °F 130.81 130.25 130.00 130.353

Average Velocity Head, inches of H2O 1.0823190486

4535

1.093183376

36461

1.065082818

39623

1.080

Average Stack Gas Velocity, feet/second 63.09 63.40 62.42 62.970

Stack Cross-Sectional Area, square feet 201.062 201.062 201.062 201.062

Dry Volumetric Flow Rate, dry scfm 556,175.1 565,555.9 553,185.5 558,305.500

Actual Wet Volumetric Flue Gas Flow Rate, acfm 761,100.1 764,839.8 753,017.4 759,652.433

Percent Isokinetic of Sampling Rate, % 102.5 100.6 100.4 101.167

Percent Excess Air, % 36.3 39.9 39.9 38.700

F-Factor, dscfm/MMBtu @ %O2 9820 9820 9820 9,820.000

Round Duct Diameter, inches 192 192 192

Rectangular Duct Width, inches 0 0 0

Rectangular Duct Length, inches 0 0 0

Fw 0 0 0 0.000

Fc 1840 1840 1840 1,840.000

Monday, February 07, 2011 Page 9 of 9