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 10
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Facility Information:

Coffeen

134 CIPS Lane

Coffeen IL 62017

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 IL 60067

Contact:Bill Ansell

Phone: 847-654-4545

Fax: 847-991-3385

Email: bansell@cleanair.com

Air Permit Number:

861

Permitted Source ID/Name:

01 Enter the Boiler ID of the tested boiler (left)

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/NAIS 221112

Sampling Location Information:

Test Parameter Information:

AFS #: 1713500038 FRS #: 110000500501

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

Unit 1 Stack 240 0 0 0 7.3 14.1 4 12

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Unit 1 Stack Hydrogen Fluoride Method 26A 3 60 0

Unit 1 Stack Hydrogen Chloride Method 26A 3 60 0

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Sampling / Stack Data Results Summary

Location Unit 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 PM 5:20:00 PM 7:07:00 PM

Run Finish Time 4:35:00 PM 6:15:00 PM 8:02:00 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 877,210.1 887,303.8 885,565.2 883,359.700

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,255,944.9 1,271,213.0 1,269,516.5 1,265,558.13

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 10
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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 10
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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 0 1000 lb steam/hr 0

2 Synfuel Firing Rate 0 0

2 Petroleum Coke Firing Rate 0 0

2 Coal Gas Firing Rate 0 0

2 Fuel Oil Firing Rate 0 0

2 Flue Gas Flow Rate 1E+06 dscfm 0

2 Pressure Drop Across FGD (if applicable) 0 in H20 0

2 FGD Scrubber Liquor pH 0 pH 0

2 FGD Scrubber Liquor Flow Rate 0 gal/min 0

2 Sorbent Type and Sorbent Injection Rate (if 

applicable)

0 lb/hr 0

2 Flue Gas Oxygen Content 0 % 0

2 Flue Gas Carbon Dioxide Content 10.9 % 0

2 Flue Gas Moisture Content 0 % 0

2 Flue Gas Sampling Point Temperature 0 Deg F 0

2 Flue 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

2 Unit 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 10
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3 Average Heat Input 0 MMBtu/hr 0

3 Steam Output 0 1000 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 0 1000 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

2 Flue Gas Flow 6E+07 SCFH 0

Tuesday, January 18, 2011 Page 8 of 10
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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

2 Load 355.3 MW 0

3 Load 355.2 MW 0

1 NOx 32.6 ppm 0

2 NOx 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 Value UOM Comments

1 Fuel Higher Heating Value 12013 Btu/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 95.4 ug/g dry coal

Tuesday, January 18, 2011 Page 9 of 10
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2 Fuel Higher Heating Value 12082 Btu/lb

2 Fuel Moisture 28.16 %

2 Fuel Mercury Content 0 ppm

2 Fuel Cadmium Content 0 ppm

2 Ultimate/Proximate Analysis 0

2 Fuel Nickel Content 0 ppm

2 Fuel Arsenic Content 0 ppm

2 Fuel Chromium Content 0 ppm

2 Fuel Beryllium Content 0 ppm

2 Fuel Lead Content 0 ppm

2 Fuel Manganese Content 0 ppm

2 Fuel Chlorine Content 0.025 % wt

2 Fuel Fluorine Content 93.5 ug/g dry coal

3 Fuel Higher Heating Value 12011 Btu/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 92.6 ug/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 10
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Sampling / Stack Data Results Detail

Location Unit 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 PM 5:20:00 PM 7:07:00 PM

Run Finish Time 4:35:00 PM 6:15:00 PM 8:02:00 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

9768

1.256227848

2588

1.247531175

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 877,210.1 887,303.8 885,565.2 883,359.700

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,255,944.9 1,271,213.0 1,269,516.5 1,265,558.1

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 9780 9,780.000

Round Duct Diameter, inches 240 240 240

Rectangular Duct Width, inches 0 0 0

Rectangular Duct Length, inches 0 0 0

Fw 10640 10640 10640 10,640.000

Fc 1800 1800 1800 1,800.000

Tuesday, January 18, 2011 Page 11 of 10