Name: Robert A. Greco

Title: Manager, Air Quality

Company: We Energies

Sign Date: 6/30/2010

Name: Scott 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 10
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:

1 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.

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 % H2O Method 1 - 4 3 180 0

Stack Exit Carbon Monoxide Method 10 3 120 0

Stack Exit Formaldehyde Method 0011 3 120 0

Monday, February 07, 2011 Page 2 of 10
6/30/2010

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 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

Total organic compounds 

(TOC) as Propane

Stack Exit Method 25A 3 120 0

Stack Exit Hydrogen Fluoride Method 26A 3 180 0

Stack Exit Hydrogen Chloride Method 26A 3 180 0

Stack Exit Hydrogen Fluoride Method 26 3 180 0

Stack Exit Hydrogen Chloride Method 26 3 180 0

Filterable PM2.5 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

Monday, February 07, 2011 Page 3 of 10
6/30/2010

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.

All methods described in the EU MACT ICR were used.

Inorganic (Aqueous) 

Condensible Part.

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

stacks. Delete Method 

5/OTM28 tests.

Stack Exit

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

Stack Exit Beryllium Method 29 3 240 0

Stack Exit Cobalt Method 29 0

Stack Exit Nickel Method 29 3 240 0

Stack Exit Antimony Method 29 3 240 0

Stack Exit Arsenic Method 29 3 240 0

Stack Exit Selenium Method 29 3 240 0

Stack Exit Lead Method 29 3 240 0

Stack Exit Filterable Particulate Method 29 3 240 0

Stack Exit Chromium Method 29 3 240 0

Stack Exit Manganese Method 29 3 240 0

Stack Exit Cadmium Method 29 3 240 0

Stack Exit O2 Method 3A O2 3 240 0

Stack Exit O2 Method 3A O2 3 120 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 3 480 0

Stack Exit Co2 Method 3A CO2 3 480 0

Total 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

Organic Condensible 

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

Monday, February 07, 2011 Page 4 of 10
6/30/2010

Sampling / Stack Data Results Summary

Location Stack Exit - Method 26A

Average

Run Number M26A-1 M26A-2 M26A-3

Test Date 4/13/2010 4/13/2010 4/14/2010

Run Start Time 8:05:00 AM 12:08:00 

PM

7:50:00 AM

Run Finish Time 11:36:00 AM 3:28:00 PM 11:12:00 AM

Net Run Time, minutes 180 180 180

Dry Gas Meter Volume Sampled, dscf 139.405 142.390 147.205 143.000

Moisture Content of Stack Gas, % 16.49 16.76 16.78 16.677

Moisture Saturation at Stack Gas Temperature, % 15.74 15.69 15.59 15.673

Carbon Dioxide, % 13.6 13.6 13.3 13.500

Oxygen, % 5.4 5.4 5.7 5.500

Average Stack Gas Temperature, °F 130.75 130.58 130.36 130.563

Dry Volumetric Flow Rate, dry scfm 524,470.1 528,483.8 546,224.3 533,059.400

Actual Wet Volumetric Flue Gas Flow Rate, acfm 711,638.8 717,188.2 740,109.2 722,978.733

Percent Isokinetic of Sampling Rate, % 101.1 102.5 102.5 102.033

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 5 of 10
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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 0.48 0.39 0.54 0.470

Elb/hr 2.39E-01 1.91E-01 2.65E-01 0.232

lb/mmBtuO2 1.01E-04 8.00E-05 1.09E-04 0.000

mg/dscm 1.22E-01 9.67E-02 1.30E-01 0.116

mg/dscm@7%O2 1.09E-01 8.67E-02 1.19E-01 0.105

Compound: Hydrogen Fluoride

Average

RunNumber M26A-1 M26A-2 M26A-3

Mass_mg 0.24 0.35 0.28 0.290

Elb/hr 1.19E-01 1.72E-01 1.37E-01 0.143

lb/mmBtuO2 5.03E-05 7.18E-05 5.66E-05 0.000

mg/dscm 6.08E-02 8.68E-02 6.72E-02 0.072

mg/dscm@7%O2 5.45E-02 7.78E-02 6.15E-02 0.065

Monday, February 07, 2011 Page 6 of 10
6/30/2010

Process Run Data

Run Name Value UOM Comments

Target

Value

1 Subbituminous Coal Burned 384.28 1000 Tons/hr 0

2 Subbituminous Coal Burned 389.1 1000 Tons/hr 0

3 Subbituminous Coal Burned 384.24 1000 Tons/hr 0

1 Average Heat Input 7192.4 MMBtu/hr 0

2 Average Heat Input 7049.7 MMBtu/hr 0

3 Average Heat Input 7146.3 MMBtu/hr 0

1 Steam Output 4379.5 1000 lb steam/hr 0

2 Steam Output 4378.9 1000 lb steam/hr 0

3 Steam Output 4384.5 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 1E+06 0 DSCFM

1 Pressure Drop Across FGD (if applicable) 6.617 in H20 0

1 FGD Scrubber Liquor pH 0 pH 0

1 FGD Scrubber Liquor Flow Rate 248.63 gal/min 0

1 Sorbent Type and Sorbent Injection Rate (if 

applicable)

19700 lb/hr 0

1 Flue Gas Oxygen Content 1.731 % 0

1 Flue Gas Carbon Dioxide Content 11.936 % 0

1 Flue Gas Moisture Content 0 % 0

1 Flue Gas Sampling Point Temperature 133.54 Deg F 0

1 Flue Gas Pressure 0.0159 atm 0

1 Standard Pressure 1 atm 0

1 Standard Temperature 63.33 Deg F 0

Monday, February 07, 2011 Page 7 of 10
6/30/2010

APCD Run Data

Process Lab Run Data

1 Unit Gross Electrical Output 643.18 Mwe 0

1 Unit Net Electric Generation 589.6 MWh 0

Run Name Value UOM Comments

Target

Value

1 FGD 0.2 lb/mmBtu 0.1

2 FGD 0.019 lb/mmBtu 0.1

3 FGD 0.02 lb/mmBtu 0.1

1 SCR (SELECTIVE CATALYTIC REDUCTION) 0.071 lb/mmBtu 0.1

2 SCR (SELECTIVE CATALYTIC REDUCTION) 0.07 lb/mmBtu 0.1

3 SCR (SELECTIVE CATALYTIC REDUCTION) 0.069 lb/mmBtu 0.1

1 ELECTROSTATIC PRECIPITATOR 0.004 lb/mmBtu 0.03

2 ELECTROSTATIC PRECIPITATOR 0.004 lb/mmBtu 0.03

3 ELECTROSTATIC PRECIPITATOR 0.003 lb/mmBtu 0.03

Run Name Value UOM Comments

1 Fuel Higher Heating Value 11806 Btu/lb

1 Fuel Moisture 17.33 %

1 Fuel Mercury Content 0.17 ppm

1 Fuel Cadmium Content 0.13 ppm

1 Ultimate/Proximate Analysis 0

1 Fuel Nickel Content 7.4 ppm

1 Fuel Arsenic Content 1.4 ppm

1 Fuel Chromium Content 5.6 ppm

1 Fuel Beryllium Content 0.24 ppm

1 Fuel Lead Content 3 ppm

1 Fuel Manganese Content 26 ppm

1 Fuel Chlorine Content 55 ppm

1 Fuel Fluorine Content 93 ppm

2 Fuel Higher Heating Value 11961 Btu/lb

2 Fuel Moisture 19.67 %

2 Fuel Mercury Content 0.094 ppm

2 Fuel Cadmium Content 0.11 ppm

2 Ultimate/Proximate Analysis 0

2 Fuel Nickel Content 13 ppm

2 Fuel Arsenic Content 1.6 ppm

2 Fuel Chromium Content 5 ppm

2 Fuel Beryllium Content 0.26 ppm

Monday, February 07, 2011 Page 8 of 10
6/30/2010

2 Fuel Lead Content 3.1 ppm

2 Fuel Manganese Content 22 ppm

2 Fuel Chlorine Content 43 ppm

2 Fuel Fluorine Content 87 ppm

3 Fuel Higher Heating Value 11984 Btu/lb

3 Fuel Moisture 17.29 %

3 Fuel Mercury Content 0.09 ppm

3 Fuel Cadmium Content 0.11 ppm

3 Ultimate/Proximate Analysis 0

3 Fuel Nickel Content 15 ppm

3 Fuel Arsenic Content 1.4 ppm

3 Fuel Chromium Content 6 ppm

3 Fuel Beryllium Content 0.27 ppm

3 Fuel Lead Content 3.2 ppm

3 Fuel Manganese Content 27 ppm

3 Fuel Chlorine Content 45 ppm

3 Fuel Fluorine Content 87 ppm

Monday, February 07, 2011 Page 9 of 10
6/30/2010

Sampling / Stack Data Results Detail

Location Stack Exit - Method 26A

Average

Run Number M26A-1 M26A-2 M26A-3

Test Date 4/13/2010 4/13/2010 4/14/2010

Run Start Time 8:05:00 AM 12:08:00 PM 7:50:00 AM

Run Finish Time 11:36:00 AM 3:28:00 PM 11:12:00 AM

Net Traversing Points 80 80 80

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 29.35 29.32 29.32 29.330

Average Orifice Meter Differential, inches H2O 1.78 1.81 1.88 1.823

Dry Gas Meter Volume Sampled, cubic feet 146.686 150.520 155.788 150.998

Average Dry Gas Meter Temperature, °F 85.78 87.79 88.51 87.360

Dry Gas Meter Volume Sampled, dscf 139.405 142.390 147.205 143.000

Total Moisture Liquid collected, g 584.8 608.8 630.6 608.067

Volume of Water Vapor, standard cubic feet 27.53 28.66 29.68 28.623

Moisture Content of Stack Gas, % 16.49 16.76 16.78 16.677

Moisture Saturation at Stack Gas Temperature, % 15.74 15.69 15.59 15.673

Dry Mole Fraction 0.8426 0.8431 0.8441 0.843

Carbon Dioxide, % 13.6 13.6 13.3 13.500

Oxygen, % 5.4 5.4 5.7 5.500

Carbon Monoxide & Nitrogen, % 81 81 81 81.000

Fuel Factor 1.14 1.14 1.14

Dry Molecular Weight, lb/lb-Mole 30.39 30.39 30.36 30.380

Wet Molecular weight, lb/lb-Mole 28.57 28.64 28.65 28.620

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

Absolute Flue Gas Pressure, inches of Mercury 29.28 29.25 29.25 29.260

Average Stack Gas Temperature, °F 130.75 130.58 130.36 130.563

Average Velocity Head, inches of H2O 0.9556199063

56541

0.972312152

062734

1.035952717

30808

0.988

Average Stack Gas Velocity, feet/second 58.99 59.45 61.35 59.930

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

Dry Volumetric Flow Rate, dry scfm 524,470.1 528,483.8 546,224.3 533,059.400

Actual Wet Volumetric Flue Gas Flow Rate, acfm 711,638.8 717,188.2 740,109.2 722,978.733

Percent Isokinetic of Sampling Rate, % 101.1 102.5 102.5 102.033

Percent Excess Air, % 33.8 33.8 36.3 34.633

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 10 of 10