Name:

Title:

Company:

Sign Date:

Name:

Title:

Company:

Sign Date:

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.

Wednesday, February 16, 2011 Page 1 of 13
Facility Information:

AES Petersburg

6925 N. State Road 57

Petersburg IN 47567

Contact: Angelique Oliger

Phone: (317) 261-5852 ext ____

Fax:

Email: angelique.oliger@aes.com

Testing Company:

URS Corporation

1600 Perimeter Park Dr.

Morrisville NC 27560

Contact:Brad Justus

Phone: 919-461-1100

Fax: 919-461-1415

Email: Brad_Justus@URScorp.com

Air Permit Number:

994

Permitted Source ID/Name:

1 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:

2200 MMBtu/hr, Low NOx Burner, Neural Net Controls, Overfire Air, ESP, FGD.

Industry/SCC/NAIS 221112

Sampling Location Information:

Test Parameter Information:

AFS #: 1812500002 FRS #: 330015653241

SCC / Description 10100211 External Combustion Boilers - Electric Generation - Bituminous/Subbituminous 

Coal - Wet Bottom (Tangential) (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

Stack Exit 258 0 0 0 516 2064 4 3

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

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

Wednesday, February 16, 2011 Page 2 of 13
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

Stack Exit Total PCBs Method 23 3 480 0

Stack Exit Total TEQ Method 23 3 480 0

Total organic compounds 

(TOC) as Propane

Stack Exit Method 25A 3 120 0

Stack Exit Hydrogen Chloride Method 26 3 180 0

Stack Exit Hydrogen Fluoride Method 26 3 180 0

Stack Exit Hydrogen Chloride Method 26A 3 180 0

Stack Exit Hydrogen Fluoride Method 26A 3 180 0

Inorganic (Aqueous) 

Condensible Part.

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

stacks. Delete Method 

5/OTM28 tests.

Stack Exit

Filterable PM2.5 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

Wednesday, February 16, 2011 Page 3 of 13
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.

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

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

stacks. Delete Method 

5/OTM28 tests.

Stack Exit

Stack Exit Filterable Particulate Method 29 3 240 0

Stack Exit Antimony Method 29 3 240 0

Stack Exit Arsenic Method 29 3 240 0

Stack Exit Beryllium Method 29 3 240 0

Stack Exit Cadmium Method 29 3 240 0

Stack Exit Chromium Method 29 3 240 0

Stack Exit Lead Method 29 3 240 0

Stack Exit Magnesium Method 29 3 240 0

Stack Exit Manganese Method 29 3 240 0

Stack Exit Mercury Method 29 3 240 0

Stack Exit Nickel Method 29 3 240 0

Stack Exit Selenium Method 29 3 240 0

Stack Exit Co2 Method 3A CO2 3 240 0

Stack Exit Co2 Method 3A CO2 3 120 0

Stack Exit O2 Method 3A O2 3 240 0

Stack Exit O2 Method 3A O2 3 120 0

Stack Exit O2 Method 3A O2 3 480 0

Stack Exit Co2 Method 3A CO2 3 480 0

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

Total 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

Wednesday, February 16, 2011 Page 4 of 13
Sampling / Stack Data Results Summary

Location Stack Exit - Method 26A

Average

Run Number 1 1 2

Test Date 3/23/2010 1/1/2010 3/31/2010

Run Start Time 9:01:00 AM 9:01:00 

AM

12:15:00 PM

Run Finish Time 12:28:00 PM 12:28:00 

PM

3:40:00 PM

Net Run Time, minutes 180 180 180

Dry Gas Meter Volume Sampled, dscf 101.453 101.453 84.232 95.713

Moisture Content of Stack Gas, % 13.97 13.97 11.57 13.170

Moisture Saturation at Stack Gas Temperature, % 13.39 13.39 11.34 12.707

Carbon Dioxide, % 10.2 10.2 7.7 9.367

Oxygen, % 9 9 11.9 9.967

Average Stack Gas Temperature, °F 124.42 124.42 117.92 122.253

Dry Volumetric Flow Rate, dry scfm 719,232.7 719,232.7 624,364.6 687,610.000

Actual Wet Volumetric Flue Gas Flow Rate, acfm 947,342.7 947,342.7 805,535.3 900,073.567

Percent Isokinetic of Sampling Rate, % 104.0 104.0 99.4 102.467

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

Wednesday, February 16, 2011 Page 5 of 13
Location Stack Exit - Method 26A 3

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Net Run Time, minutes

Dry Gas Meter Volume Sampled, dscf

Moisture Content of Stack Gas, %

Moisture Saturation at Stack Gas Temperature, %

Carbon Dioxide, %

Oxygen, %

Average Stack Gas Temperature, °F

Dry Volumetric Flow Rate, dry scfm

Actual Wet Volumetric Flue Gas Flow Rate, acfm

Percent Isokinetic of Sampling Rate, %

F-Factor, dscfm/MMBtu @ %O2

Fw

Fc

Wednesday, February 16, 2011 Page 6 of 13
Emissions Summary

Process Run Data

Location: Stack Exit - Method 26A

Compound: Hydrogen Chloride

Average

RunNumber 1 1 2

Mass_mg 0.369 0.369 0.336 0.358

Elb/hr 3.46E-01 3.46E-01 3.29E-01 0.340

lb/mmBtuO2 1.38E-04 1.38E-04 2.00E-04 0.000

mg/dscm 1.28E-01 1.28E-01 1.41E-01 0.132

mg/dscm@7%O2 1.50E-01 1.50E-01 2.18E-01 0.173

Compound: Hydrogen Fluoride

Average

RunNumber 1 1 2

Mass_mg 0.299 0.299 0.339 0.312

Elb/hr 2.80E-01 2.80E-01 3.32E-01 0.297

lb/mmBtuO2 1.12E-04 1.12E-04 2.02E-04 0.000

mg/dscm 1.04E-01 1.04E-01 1.42E-01 0.117

mg/dscm@7%O2 1.21E-01 1.21E-01 2.19E-01 0.154

Location: Stack Exit - Method 26A 3

Compound: Hydrogen Chloride

Average

RunNumber 3 1 1

Mass_mg 0.301 0.369 0.369 0.346

Elb/hr 2.89E-01 3.46E-01 3.46E-01 0.327

lb/mmBtuO2 1.90E-04 1.38E-04 1.38E-04 0.000

mg/dscm 1.34E-01 1.28E-01 1.28E-01 0.130

mg/dscm@7%O2 2.07E-01 1.50E-01 1.50E-01 0.169

Compound: Hydrogen Fluoride

Average

RunNumber 3 1 1

Mass_mg 0.308 0.299 0.299 0.302

Elb/hr 2.96E-01 2.80E-01 2.80E-01 0.285

lb/mmBtuO2 1.94E-04 1.12E-04 1.12E-04 0.000

mg/dscm 1.37E-01 1.04E-01 1.04E-01 0.115

mg/dscm@7%O2 2.12E-01 1.21E-01 1.21E-01 0.151

Wednesday, February 16, 2011 Page 7 of 13
Process Run Data

Run Name Value UOM Comments

Target

Value

1 Bituminous Coal Burned 2351 Tons/hr 0

1 Average Heat Input 2219 MMBtu/hr 0

1 Steam Output 1560 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 Flue Gas Flow Rate 721260 dscfm 0

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

1 FGD Scrubber Liquor pH 5.7 pH 0

1 FGD Scrubber Liquor Flow Rate 0 gal/min 0

1 Sorbent Type and Sorbent Injection Rate (if 

applicable)

0 lb/hr 0

1 Flue Gas Oxygen Content 3.75 % 0

1 Flue Gas Carbon Dioxide Content 8.3 % 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 1 atm 0

1 Standard Temperature 68 Deg F 0

1 Unit Gross Electrical Output 231.72 MW 0

1 Unit Net Electric Generation 209.95 MWh 0

2 Bituminous Coal Burned 1755 Tons/hr 0

2 Average Heat Input 1657 MMBtu/hr 0

2 Steam Output 1152 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 626116 dscfm 0

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

2 FGD Scrubber Liquor pH 5.6 pH 0

2 FGD Scrubber Liquor Flow Rate 0 gal/min 0

Wednesday, February 16, 2011 Page 8 of 13
APCD Run Data

2 Sorbent Type and Sorbent Injection Rate (if 

applicable)

0 lb/hr 0

2 Flue Gas Oxygen Content 4.02 % 0

2 Flue Gas Carbon Dioxide Content 7.9 % 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 1 atm 0

2 Standard Temperature 68 Deg F 0

2 Unit Gross Electrical Output 177.04 MW 0

2 Unit Net Electric Generation 158.3 MWh 0

3 Bituminous Coal Burned 1541 Tons/hr 0

3 Average Heat Input 1455 MMBtu/hr 0

3 Steam Output 1014 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 578395 dscfm 0

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

3 FGD Scrubber Liquor pH 5.8 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 4.16 % 0

3 Flue Gas Carbon Dioxide Content 7.4 % 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 1 atm 0

3 Standard Temperature 68 Deg F 0

3 Unit Gross Electrical Output 159.89 MW 0

3 Unit Net Electric Generation 142.24 MWh 0

Run Name Value UOM Comments

Target

Value

1 LOW NOX BURNERS 0 0

Wednesday, February 16, 2011 Page 9 of 13
Process Lab Run Data

2 LOW NOX BURNERS 0 0

3 LOW NOX BURNERS 0 0

1 OVERFIRE AIR 0 0

2 OVERFIRE AIR 0 0

3 OVERFIRE AIR 0 0

1 ELECTROSTATIC PRECIPITATOR 0 kvolts 0

2 ELECTROSTATIC PRECIPITATOR 0 kvolts 0

3 ELECTROSTATIC PRECIPITATOR 0 kvolts 0

1 CAUSTIC SCRUBBER 0 0

2 CAUSTIC SCRUBBER 0 0

3 CAUSTIC SCRUBBER 0 0

Run Name Value UOM Comments

1 Fuel Higher Heating Value 10749 Btu/lb

1 Fuel Moisture 17 %

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 410 ppm

1 Fuel Fluorine Content 45 ppm

2 Fuel Higher Heating Value 11506 Btu/lb

2 Fuel Moisture 11 %

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 160 ppm

2 Fuel Fluorine Content 39 ppm

Wednesday, February 16, 2011 Page 10 of 13
3 Fuel Higher Heating Value 10684 Btu/lb

3 Fuel Moisture 15 %

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 160 ppm

3 Fuel Fluorine Content 43 ppm

Wednesday, February 16, 2011 Page 11 of 13
Sampling / Stack Data Results Detail

Location Stack Exit - Method 26A

Average

Run Number 1 1 2

Test Date 3/23/2010 1/1/2010 3/31/2010

Run Start Time 9:01:00 AM 9:01:00 AM 12:15:00 PM

Run Finish Time 12:28:00 PM 12:28:00 PM 3:40:00 PM

Net Traversing Points 13 13 13

Net Run Time, minutes 180 180 180

Nozzle Diameter, inches 0.224 0.224 0.224 0.224

Pitot Tube Coefficient 0.84 0.84 0.84 0.840

Dry Gas Meter Calibration Factor 1.017 1.017 0.9946 1.010

Barometric Pressure, inches of Mercury 29.18 29.18 28.78 29.047

Average Orifice Meter Differential, inches H2O 1.12 1.12 0.82 1.020

Dry Gas Meter Volume Sampled, cubic feet 106.104 106.104 93.572 101.927

Average Dry Gas Meter Temperature, °F 89.25 89.25 102.33 93.610

Dry Gas Meter Volume Sampled, dscf 101.453 101.453 84.232 95.713

Total Moisture Liquid collected, g 349.8 349.8 234.2 311.267

Volume of Water Vapor, standard cubic feet 16.47 16.47 11.02 14.653

Moisture Content of Stack Gas, % 13.97 13.97 11.57 13.170

Moisture Saturation at Stack Gas Temperature, % 13.39 13.39 11.34 12.707

Dry Mole Fraction 0.8661 0.8661 0.8866 0.873

Carbon Dioxide, % 10.2 10.2 7.7 9.367

Oxygen, % 9 9 11.9 9.967

Carbon Monoxide & Nitrogen, % 80.8 80.8 80.4 80.667

Fuel Factor 1.17 1.17 1.17

Dry Molecular Weight, lb/lb-Mole 29.99 29.99 29.71 29.897

Wet Molecular weight, lb/lb-Mole 28.49 28.49 28.42 28.467

Flue Gas Static Pressure, inches of H2O -2 -2 -2 -2.000

Absolute Flue Gas Pressure, inches of Mercury 29.03 29.03 28.63 28.897

Average Stack Gas Temperature, °F 124.42 124.42 117.92 122.253

Average Velocity Head, inches of H2O 0.5189320006

59823

0.518932000

659823

0.373326858

909137

0.470

Average Stack Gas Velocity, feet/second 43.49 43.49 36.98 41.320

Stack Cross-Sectional Area, square feet 363.050 363.050 363.050 363.050

Dry Volumetric Flow Rate, dry scfm 719,232.7 719,232.7 624,364.6 687,610.000

Actual Wet Volumetric Flue Gas Flow Rate, acfm 947,342.7 947,342.7 805,535.3 900,073.567

Percent Isokinetic of Sampling Rate, % 104.0 104.0 99.4 102.467

Percent Excess Air, % 73.0 73.0 127.6 91.200

F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000

Round Duct Diameter, inches 258 258 258

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

Wednesday, February 16, 2011 Page 12 of 13
Location Stack Exit - Method 26A 3

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Net Traversing Points

Net Run Time, minutes

Nozzle Diameter, inches

Pitot Tube Coefficient

Dry Gas Meter Calibration Factor

Barometric Pressure, inches of Mercury

Average Orifice Meter Differential, inches H2O

Dry Gas Meter Volume Sampled, cubic feet

Average Dry Gas Meter Temperature, °F

Dry Gas Meter Volume Sampled, dscf

Total Moisture Liquid collected, g

Volume of Water Vapor, standard cubic feet

Moisture Content of Stack Gas, %

Moisture Saturation at Stack Gas Temperature, %

Dry Mole Fraction

Carbon Dioxide, %

Oxygen, %

Carbon Monoxide & Nitrogen, %

Fuel Factor

Dry Molecular Weight, lb/lb-Mole

Wet Molecular weight, lb/lb-Mole

Flue Gas Static Pressure, inches of H2O

Absolute Flue Gas Pressure, inches of Mercury

Average Stack Gas Temperature, °F

Average Velocity Head, inches of H2O

Average Stack Gas Velocity, feet/second

Stack Cross-Sectional Area, square feet

Dry Volumetric Flow Rate, dry scfm

Actual Wet Volumetric Flue Gas Flow Rate, acfm

Percent Isokinetic of Sampling Rate, %

Percent Excess Air, %

F-Factor, dscfm/MMBtu @ %O2

Round Duct Diameter, inches

Rectangular Duct Width, inches

Rectangular Duct Length, inches

Fw

Fc

Wednesday, February 16, 2011 Page 13 of 13