Name: Michael L Menne

Title: VP Environmental Safety/Health Company: Ameren Services Sign Date: 9/3/2010 Name: Bill Ansell Title: Project Manager Company:Clean Air Engineering, Inc Sign Date: 9/3/2010 Permitted Facility Representative / Date Testing Company Representative / Date 

### Coffeen Unit O1 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.

Tuesday, January 18, 2011 Page 1 of 10Coffeen Unit O1 9/3/2010 Facility Information: Coffeen 134 CIPS Lane

Coffeen IL62017 Contact:Donald Schuh Phone:314-554-2658 Fax: 314-554-4182 Email:dschuh@ameren.com Testing Company: Clean Air Engineering 500 West Wood Street

Palatine IL60067 Contact:Bill Ansell Phone:847-654-4545 Fax: 847-991-3385 Email:bansell@cleanair.com

Air Permit Number: 861 Permitted Source ID/Name: Enter the Boiler ID of the tested boiler (left) 01 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: Coffeen Unit 01 consists of a steam-driven, electrical generator rated a 382 gross megawatts and a Combustion Engineering pulverized coal, tangentially-fired, reheat boiler. The unit contains Overfired aire, Selective Catalytic Reduction, Flue Gas conditioning, Electrostatic Precipitator and Flue Gas Desulfurization.

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. None Industry/SCC/NAIS221112

Sampling Location Information:

Test Parameter Information: AFS #:1713500038 FRS #:110000500501

SCC / Description10100202 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 Unit 1 Stack 240 7.3 14.1 4 0 12 0 0

Target Parameter Test Method Number of

Test RunsTest Run

DurationSample

Points Comments LocationHydrogen Fluoride Method 26A 3 60 0 Unit 1 StackHydrogen Chloride Method 26A 3 60 0 Unit 1 Stack

Tuesday, January 18, 2011 Page 2 of 10Coffeen Unit O1 9/3/2010

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Tuesday, January 18, 2011 Page 4 of 10Coffeen Unit O1 9/3/2010 Sampling / Stack Data Results Summary LocationUnit 1 Stack - Method 26A Average Run Number 1 2 3 Test Date 5/13/20105/13/2010 5/13/2010 Run Start Time 3:40:00 PM5:20:00 PM7:07:00 PM Run Finish Time 4:35:00 PM6:15:00 PM8:02:00 PM Net Run Time, minutes 60 60 60 Dry Gas Meter Volume Sampled, dscf 33.541 33.923 33.611 33.692 Moisture Content of Stack Gas, % 26.46 27.08 26.55 26.697 Moisture Saturation at Stack Gas Temperature, % 18.63 18.67 18.71 18.670 Carbon Dioxide, % 10.9 10.9 10.9 10.900 Oxygen, % 6.6 6.9 6.3 6.600 Average Stack Gas Temperature, °F 136.83 136.92 137.00 136.917 Dry Volumetric Flow Rate, dry scfm 877,210.1 887,303.8 885,565.2883,359.700 Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,255,944.91,271,213.0 1,269,516.51,265,558.13 3 Percent Isokinetic of Sampling Rate, % 101.7 101.7 100.9 101.433 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

Tuesday, January 18, 2011 Page 5 of 10Coffeen Unit O1 9/3/2010 Emissions Summary

Process Run Data Location: Unit 1 Stack - Method 26A Compound:Hydrogen Chloride Average RunNumber 1 2 3 Mass_mg 1.3976 2.0815 1.3782 1.619 lb/mmBtuO2 1.31E-03 1.98E-03 1.27E-03 0.002 Compound:Hydrogen Fluoride Average RunNumber 1 2 3 Mass_mg 0.6899 0.6878 0.7898 0.723 lb/mmBtuO2 6.48E-04 6.53E-04 7.25E-04 0.001

Tuesday, January 18, 2011 Page 6 of 10Coffeen Unit O1 9/3/2010 Process Run Data

Run Name Value UOM Comments Target Value 1 Flue Gas Flow Rate 1E+06 dscfm 0 1 FGD Scrubber Liquor Flow Rate 0 gal/min 0 1 Flue Gas Carbon Dioxide Content 10.9 % 0 1 Flue Gas Moisture Content 0 % 0 1 Flue Gas Sampling Point Temperature 0 Deg F 0 1 Flue Gas Pressure 0 atm 0 1 Standard Pressure 0 atm 0 1 Standard Temperature 0 Deg F 0 1 Unit Gross Electrical Output 354.6 MW 0 1 Unit Net Electric Generation 0 MWh 0 1 Coal Firing Rate 0 0 2 Average Heat Input 0 MMBtu/hr 0 2 Steam Output 01000 lb steam/hr 0 2 Synfuel Firing Rate 0 0 2Petroleum Coke Firing Rate 0 0 2 Coal Gas Firing Rate 0 0 2Fuel Oil Firing Rate 0 0 2Flue Gas Flow Rate 1E+06 dscfm 0 2 Pressure Drop Across FGD (if applicable) 0 in H20 0 2FGD Scrubber Liquor pH 0 pH 0 2FGD Scrubber Liquor Flow Rate 0 gal/min 0 2 Sorbent Type and Sorbent Injection Rate (if applicable) 0 lb/hr 0

2Flue Gas Oxygen Content 0 % 0 2Flue Gas Carbon Dioxide Content 10.9 % 0 2Flue Gas Moisture Content 0 % 0 2Flue Gas Sampling Point Temperature 0 Deg F 0 2Flue Gas Pressure 0 atm 0 2 Standard Pressure 0 atm 0 2 Standard Temperature 0 Deg F 0 2 Unit Gross Electrical Output 355.3 MW 0 2Unit Net Electric Generation 0 MWh 0 2 Coal Firing Rate 0 0 2 Bituminous Coal Burned 0 Tons/hr 0 Tuesday, January 18, 2011 Page 7 of 10Coffeen Unit O1 9/3/2010 3 Average Heat Input 0 MMBtu/hr 0 3 Steam Output 01000 lb steam/hr 0 3 Synfuel Firing Rate 0 0 3 Petroleum Coke Firing Rate 0 0 3 Coal Gas Firing Rate 0 0 3 Fuel Oil Firing Rate 0 0 3 Flue Gas Flow Rate 1E+06 dscfm 0 3 Pressure Drop Across FGD (if applicable) 0 in H20 0 3 FGD Scrubber Liquor pH 0 pH 0 3 FGD Scrubber Liquor Flow Rate 0 gal/min 0 3 Sorbent Type and Sorbent Injection Rate (if applicable) 0 lb/hr 0

3 Flue Gas Oxygen Content 0 % 0 3 Flue Gas Carbon Dioxide Content 10.9 % 0 3 Flue Gas Moisture Content 0 % 0 3 Flue Gas Sampling Point Temperature 0 Deg F 0 3 Flue Gas Pressure 0 atm 0 3 Standard Pressure 0 atm 0 3 Standard Temperature 0 Deg F 0 3 Unit Gross Electrical Output 355.2 MW 0 3 Unit Net Electric Generation 0 MWh 0 3 Coal Firing Rate 0 0 3 Bituminous Coal Burned 0 Tons/hr 0 1 Average Heat Input 0 MMBtu/hr 0 1 Steam Output 01000 lb steam/hr 0 1 Synfuel Firing Rate 0 0 1 Petroleum Coke Firing Rate 0 0 1 Coal Gas Firing Rate 0 0 1 Fuel Oil Firing Rate 0 0 1 Pressure Drop Across FGD (if applicable) 0 in H20 0 1 FGD Scrubber Liquor pH 0 pH 0 1 Sorbent Type and Sorbent Injection Rate (if applicable) 0 lb/hr 0

1 Flue Gas Oxygen Content 0 % 0 1 Bituminous Coal Burned 0 Tons/hr 0 1 Flue Gas Flow 6E+07 SCFH 0 2Flue Gas Flow 6E+07 SCFH 0

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APCD Run Data

Process Lab Run Data 3 Flue Gas Flow 6E+07 SCFH 0 1 Load 354.6 MW 0 2Load 355.3 MW 0 3 Load 355.2 MW 0 1 NOx 32.6 ppm 0 2NOx 31.2 ppm 0 3 NOx 33.8 ppm 0 1 SO2 0 ppm 0 2 SO2 4.5 ppm 0 3 SO2 4.4 ppm 0 1 Opacity 0 0 2 Opacity 6.2 0 3 Opacity 6.7 0 1 opacity 0 0 2 opacity 0 0 3 opacity 0 0

Run Name Value UOM Comments Target Value 1 OVERFIRE AIR 0 0 1 LOW NOX BURNERS 0 0 1 ELECTROSTATIC PRECIPITATOR 0 0

Run Name ValueUOM Comments 1 Fuel Higher Heating Value 12013Btu/lb 1 Fuel Moisture 28.98 % 1 Fuel Mercury Content 0 ppm 1 Fuel Cadmium Content 0 ppm 1 Ultimate/Proximate Analysis 0 1 Fuel Nickel Content 0 ppm 1 Fuel Arsenic Content 0 ppm 1 Fuel Chromium Content 0 ppm 1 Fuel Beryllium Content 0 ppm 1 Fuel Lead Content 0 ppm 1 Fuel Manganese Content 0 ppm 1 Fuel Chlorine Content 0.026 % wt 1 Fuel Fluorine Content 95.4ug/g dry coal Tuesday, January 18, 2011 Page 9 of 10Coffeen Unit O1 9/3/2010 2Fuel Higher Heating Value 12082Btu/lb 2Fuel Moisture 28.16 % 2Fuel Mercury Content 0 ppm 2Fuel Cadmium Content 0 ppm 2 Ultimate/Proximate Analysis 0 2Fuel Nickel Content 0 ppm 2Fuel Arsenic Content 0 ppm 2Fuel Chromium Content 0 ppm 2Fuel Beryllium Content 0 ppm 2Fuel Lead Content 0 ppm 2Fuel Manganese Content 0 ppm 2Fuel Chlorine Content 0.025 % wt 2Fuel Fluorine Content 93.5ug/g dry coal 3 Fuel Higher Heating Value 12011Btu/lb 3 Fuel Moisture 29.01 % 3 Fuel Mercury Content 0 ppm 3 Fuel Cadmium Content 0 ppm 3 Ultimate/Proximate Analysis 0 3 Fuel Nickel Content 0 ppm 3 Fuel Arsenic Content 0 ppm 3 Fuel Chromium Content 0 ppm 3 Fuel Beryllium Content 0 ppm 3 Fuel Lead Content 0 ppm 3 Fuel Manganese Content 0 ppm 3 Fuel Chlorine Content 0.027 % wt 3 Fuel Fluorine Content 92.6ug/g dry coal 1 Ash 7.41 % wt 2 Ash 7.01 % wt 3 Ash 7.25 % wt 1 Sulfur 0.69 % wt 2 Sulfur 0.65 % wt 3 Sulfur 0.7 % wt

Tuesday, January 18, 2011 Page 10 of 10Coffeen Unit O1 9/3/2010 Sampling / Stack Data Results Detail LocationUnit 1 Stack - Method 26A Average Run Number 1 2 3 Test Date 5/13/2010 5/13/2010 5/13/2010 Run Start Time 3:40:00 PM5:20:00 PM7:07:00 PM Run Finish Time 4:35:00 PM6:15:00 PM8:02:00 PM Net Traversing Points 24 24 24 Net Run Time, minutes 60 60 60 Nozzle Diameter, inches 0.19 0.19 0.19 0.190 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 1.0066 1.0066 1.0066 1.007 Barometric Pressure, inches of Mercury 29.1 29.1 29.1 29.100 Average Orifice Meter Differential, inches H2O 1.04 1.06 1.06 1.053 Dry Gas Meter Volume Sampled, cubic feet 34.885 35.485 35.185 35.185 Average Dry Gas Meter Temperature, °F 79.04 82.17 82.58 81.263 Dry Gas Meter Volume Sampled, dscf 33.541 33.923 33.611 33.692 Total Moisture Liquid collected, g 256.5 267.6 258.1 260.733 Volume of Water Vapor, standard cubic feet 12.07 12.60 12.15 12.273 Moisture Content of Stack Gas, % 26.46 27.08 26.55 26.697 Moisture Saturation at Stack Gas Temperature, % 18.63 18.67 18.71 18.670 Dry Mole Fraction 0.8137 0.8133 0.8129 0.813 Carbon Dioxide, % 10.9 10.9 10.9 10.900 Oxygen, % 6.6 6.9 6.3 6.600 Carbon Monoxide & Nitrogen, % 82.5 82.2 82.8 82.500 Fuel Factor 1.31 1.28 1.34 Dry Molecular Weight, lb/lb-Mole 30.01 30.02 30.00 30.010 Wet Molecular weight, lb/lb-Mole 29.18 29.29 29.17 29.213 Flue Gas Static Pressure, inches of H2O -0.9 -0.9 -0.9 -0.900 Absolute Flue Gas Pressure, inches of Mercury 29.03 29.03 29.03 29.030 Average Stack Gas Temperature, °F 136.83 136.92 137.00 136.917 Average Velocity Head, inches of H2O 1.2218845771 97681.256227848

25881.247531175

28947 1.242 Average Stack Gas Velocity, feet/second 66.63 67.44 67.35 67.140 Stack Cross-Sectional Area, square feet 314.159 314.159 314.159 314.159 Dry Volumetric Flow Rate, dry scfm 877,210.1 887,303.8 885,565.2883,359.700 Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,255,944.91,271,213.0 1,269,516.51,265,558.1 33 Percent Isokinetic of Sampling Rate, % 101.7 101.7 100.9 101.433 Percent Excess Air, % 43.5 46.6 40.5 43.533 F-Factor, dscfm/MMBtu @ %O2 9780 9780 97809,780.000 Round Duct Diameter, inches 240 240 240 Rectangular Duct Width, inches 0 0 0 Rectangular Duct Length, inches 0 0 0 Fw 10640 10640 1064010,640.000 Fc 1800 1800 18001,800.000

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