### 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.

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Facility Information: Pleasant Prairie (ORIS Facility ID #6170) 8000 95th Street

Pleasant Prairie WI53158 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 IL60523 Contact:Scott W. Banach Phone:(630) 521-9400 Fax: (630) 521-9494 Email:sbanach@plattenv.com

Air Permit Number: 6170 Permitted Source ID/Name: Pleasant Prairie 1 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/NAIS221112

Sampling Location Information:

Test Parameter Information: AFS #:5505960002 FRS #:20847

SCC / Description10100222 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 1158 2627.75 4 0 12 0 0

Target Parameter Test Method Number of

Test RunsTest Run

DurationSample

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 

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### 6/30/2010 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 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 organic compounds

(TOC) as Propane 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 Stack Exit 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



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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.

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

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 Stack Exit 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

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



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Sampling / Stack Data Results Summary 

### LocationStack Exit - Method 26A Average Run Number M26A-1 M26A-2 M26A-3 Test Date 4/13/20104/13/2010 4/14/2010 Run Start Time 8:05:00 AM 12:08:00 PM7:50:00 AM

Run Finish Time 11:36:00 AM3:28:00 PM11:12:00 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 524,470.1 528,483.8 546,224.3533,059.400 Actual Wet Volumetric Flue Gas Flow Rate, acfm 711,638.8 717,188.2 740,109.2722,978.733 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



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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



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Process Run Data



### Run Name Value UOM Comments Target Value 1 Subbituminous Coal Burned 384.281000 Tons/hr 0 

### 2Subbituminous Coal Burned 389.11000 Tons/hr 0 3 Subbituminous Coal Burned 384.241000 Tons/hr 0 1 Average Heat Input 7192.4MMBtu/hr 0 

### 2Average Heat Input 7049.7MMBtu/hr 0 3 Average Heat Input 7146.3MMBtu/hr 0 1 Steam Output 4379.51000 lb steam/hr 0 

### 2Steam Output 4378.91000 lb steam/hr 0 3 Steam Output 4384.51000 lb steam/hr 0 1 Synfuel Firing Rate 0 1000 Tons/hr 0 

### 2Synfuel 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 

### 2Petroleum Coke Firing Rate 0 1000 Tons/hr 0 3Petroleum Coke Firing Rate 0 1000 Tons/hr 0 1 Coal Gas Firing Rate 0 Ft^3/min 0 

### 2Coal 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 

### 2Fuel Oil Firing Rate 0 gal/hr 0 3Fuel Oil Firing Rate 0 gal/hr 0 1 Flue Gas Flow Rate 1E+06 DSCFM 0 

### 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


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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 2FGD 0.019 lb/mmBtu 0.1 

### 3FGD 0.02 lb/mmBtu 0.1 1 SCR (SELECTIVE CATALYTIC REDUCTION) 0.071 lb/mmBtu 0.1 

### 2SCR (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 

### 2ELECTROSTATIC PRECIPITATOR 0.004 lb/mmBtu 0.03 3ELECTROSTATIC PRECIPITATOR 0.003 lb/mmBtu 0.03

Run Name ValueUOM Comments 1 Fuel Higher Heating Value 11806Btu/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 2Fuel Higher Heating Value 11961Btu/lb 2Fuel Moisture 19.67 % 

### 2Fuel Mercury Content 0.094 ppm 2Fuel Cadmium Content 0.11 ppm 2Ultimate/Proximate Analysis 0 2Fuel Nickel Content 13 ppm 

### 2Fuel Arsenic Content 1.6 ppm 2Fuel Chromium Content 5 ppm 2Fuel Beryllium Content 0.26 ppm



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2Fuel Lead Content 3.1 ppm 

### 2Fuel Manganese Content 22 ppm 2Fuel Chlorine Content 43 ppm 2Fuel Fluorine Content 87 ppm 3Fuel Higher Heating Value 11984Btu/lb 

### 3Fuel Moisture 17.29 % 3Fuel Mercury Content 0.09 ppm 3Fuel Cadmium Content 0.11 ppm 

### 3Ultimate/Proximate Analysis 0 3Fuel Nickel Content 15 ppm 3Fuel Arsenic Content 1.4 ppm 3Fuel Chromium Content 6 ppm 

### 3Fuel Beryllium Content 0.27 ppm 3Fuel Lead Content 3.2 ppm 3Fuel Manganese Content 27 ppm 

### 3Fuel Chlorine Content 45 ppm 3Fuel Fluorine Content 87 ppm

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Sampling / Stack Data Results Detail 

### LocationStack 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 AM12:08:00 PM7:50:00 AM Run Finish Time 11:36:00 AM3:28:00 PM11:12:00 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 565410.972312152

0627341.035952717

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 524,470.1 528,483.8 546,224.3533,059.400 Actual Wet Volumetric Flue Gas Flow Rate, acfm 711,638.8 717,188.2 740,109.2722,978.733 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 98209,820.000 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 18401,840.000



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