Name: Jon Hays

Title: Environmantal Specialist

Company: Duke Energy

Sign Date: 9/2/2010

Name: Pat Ford

Title: Project Manager

Company: AECOM

Sign Date: 8/26/2010

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.

Wednesday, February 02, 2011 Page 1 of 13
9/2/2010

Facility Information:

IN_Gibson Generating Station Unit 4

1097 N 950 W

Owensville IN 47665

Contact: Jon Hays

Phone: 317-838-4445

Fax: 317-8382490

Email: jon.hays@duke.energy.com

Testing Company:

AECOM

2 Technology Park Drive

Westford MA 01886

Contact: Patrick Ford

Phone: 978-589-3427

Fax: 978-589-3100

Email: pat.ford@aecom.com

Air Permit Number:

051-23526-00013

Permitted Source ID/Name:

Unit 4 Coal-Fired Electric Utility Boilers

Permitted Maximum Process Rate:

5897

Max. Normal Operation Process Rate:

5897

Target Process Test Rate

5897

Description of the source (including control equipment). Please see the attachments for source or

 process flow diagram:

This description should describe the process and associated controls to differentiate this facility from, or document 

similarity with others of same SCC.

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.

Industry/SCC/NAIS 221112

Sampling Location Information:

Test Parameter Information:

AFS #: 1805100013 FRS #: 330015651387

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

Stack Exit 317 0 0 0 8 2 4 12

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Stack Exit % H2O Method 1 - 4 3 60 0

Stack Exit Hydrogen Fluoride Method 26A 3 60 0

Stack Exit Hydrogen Chloride Method 26A 3 60 0

Stack Exit O2 Method 3A O2 3 60 0

Stack Exit Co2 Method 3A CO2 3 60 0

Stack Exit Sulfur Dioxide Method 6C 3 60 0

Stack Exit Nitrogen oxides (NOx) Method 7E 3 60 0

Wednesday, February 02, 2011 Page 2 of 13
9/2/2010

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.

Wednesday, February 02, 2011 Page 3 of 13
9/2/2010

Sampling / Stack Data Results Summary

Location Stack Exit - Method 26A

Average

Run Number 1 2 3

Test Date 6/16/2010 6/16/2010 6/16/2010

Run Start Time 2:30:00 PM 4:39:00 

PM

6:27:00 PM

Run Finish Time 4:13:00 PM 6:05:00 

PM

7:43:00 PM

Net Run Time, minutes 60 60 60

Dry Gas Meter Volume Sampled, dscf 45.432 45.224 46.347 45.668

Moisture Content of Stack Gas, % 16.43 16.38 16.34 16.383

Moisture Saturation at Stack Gas Temperature, % 15.86 15.86 16.07 15.930

Carbon Dioxide, % 13.33 13.33 13.33 13.330

Oxygen, % 6.15 6.11 6.13 6.130

Average Stack Gas Temperature, °F 131.08 131.08 131.58 131.247

Dry Volumetric Flow Rate, dry scfm 1,364,844.7 1,366,540.

2

1,375,013.0 1,368,799.30

0

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,853,065.2 1,855,367.

2

1,873,125.0 1,860,519.13

3

Percent Isokinetic of Sampling Rate, % 101.0 100.4 102.2 101.200

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

Location Stack Exit - Method 3A CO2

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Wednesday, February 02, 2011 Page 4 of 13
9/2/2010

Location Stack Exit - Method 3A O2

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Location Stack Exit - Method 6C

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Wednesday, February 02, 2011 Page 5 of 13
9/2/2010

Location Stack Exit - Method 7E

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Wednesday, February 02, 2011 Page 6 of 13
9/2/2010

Emissions Summary

Process Run Data

Location: Stack Exit - Method 26A

Compound: Hydrogen Chloride

Average

RunNumber 1 2 3

Mass_mg 0.4 0.38 0.39 0.390

Elb/hr 1.59E+00 1.52E+00 1.53E+00 1.547

lb/mmBtuO2 2.69E-04 2.56E-04 2.57E-04 0.000

ppm 2.05E-01 1.96E-01 1.96E-01 0.199

ppm@7%O2 1.93E-01 1.84E-01 1.84E-01 0.187

Compound: Hydrogen Fluoride

Average

RunNumber 1 2 3

Mass_mg 0.24 0.23 0.24 0.237

Elb/hr 9.54E-01 9.19E-01 9.42E-01 0.938

lb/mmBtuO2 1.61E-04 1.55E-04 1.58E-04 0.000

ppm 2.24E-01 2.16E-01 2.20E-01 0.220

ppm@7%O2 2.11E-01 2.03E-01 2.07E-01 0.207

Location: Stack Exit - Method 6C

Compound: Sulfur Dioxide

Average

Run 1 2 3

Elb/hr 6.91E+02 7.78E+02 1.53E+03 999.667

lb/mmBtuO2 1.16E-01 1.29E-01 2.55E-01 0.167

ppm 5.04E+01 5.63E+01 1.11E+02 72.567

ppm@7%O2 4.75E+01 5.29E+01 1.04E+02 68.133

Location: Stack Exit - Method 7E

Compound: Nitrogen oxides (NOx)

Average

Run 1 2 3

Elb/hr 4.09E+02 5.32E+02 4.06E+02 449.000

lb/mmBtuO2 6.86E-02 8.85E-02 6.77E-02 0.075

ppm 4.15E+01 5.36E+01 4.10E+01 45.367

ppm@7%O2 3.91E+01 5.04E+01 3.86E+01 42.700

Wednesday, February 02, 2011 Page 7 of 13
9/2/2010

Process Run Data

APCD Run Data

Process Lab Run Data

Run Name Value UOM Comments

Target

Value

5 Heat Input 5358.1 Million Btu/Hr 6265 Run 3 Acid Gases

5 Unit Gross Electrical Output 662 MW 661 Run 3 Acid Gases

1 Heat Input 5410.5 Million Btu/Hr 6265 Run 1 Acid Gases

2 Heat Input 0 Million Btu/Hr 6265

3 Heat Input 0 Million Btu/Hr 6265

4 Heat Input 5295.8 Million Btu/Hr 6265 Run 2 Acid Gases

1 Unit Gross Electrical Output 662 MW 661 Run 1 Acid Gases

4 Unit Gross Electrical Output 662 MW 661 Run 2 Acid Gases

Run Name Value UOM Comments

Target

Value

1 List all emissions control devices in order of 

process flow. Choose from

0 0

1 drop down lists. If not on list add description and 

provide detailed

0 0

1 desription in section 5a. 0 0

Run Name Value UOM Comments

1 Fuel Higher Heating Value 0 Btu/lb

1 Fuel Moisture 0 %

1 Ultimate/Proximate Analysis 0

1 Fuel Chlorine Content 0 mg/kg

1 Fuel Fluorine Content 0 mg/kg

1 Metals Content 0 mg/kg

Wednesday, February 02, 2011 Page 8 of 13
9/2/2010

Sampling / Stack Data Results Detail

Location Stack Exit - Method 26A

Average

Run Number 1 2 3

Test Date 6/16/2010 6/16/2010 6/16/2010

Run Start Time 2:30:00 PM 4:39:00 PM 6:27:00 PM

Run Finish Time 4:13:00 PM 6:05:00 PM 7:43:00 PM

Net Traversing Points 12 12 12

Net Run Time, minutes 60 60 60

Nozzle Diameter, inches 0.235 0.235 0.235 0.235

Pitot Tube Coefficient 0.84 0.84 0.84 0.840

Dry Gas Meter Calibration Factor 1.025 1.025 1.025 1.025

Barometric Pressure, inches of Mercury 29.3 29.3 29.3 29.300

Average Orifice Meter Differential, inches H2O 2.09 2.10 2.14 2.110

Dry Gas Meter Volume Sampled, cubic feet 47.399 47.698 48.732 47.943

Average Dry Gas Meter Temperature, °F 95.83 101.92 100.25 99.333

Dry Gas Meter Volume Sampled, dscf 45.432 45.224 46.347 45.668

Total Moisture Liquid collected, g 189.8 188.3 192.2 190.100

Volume of Water Vapor, standard cubic feet 8.93 8.86 9.05 8.947

Moisture Content of Stack Gas, % 16.43 16.38 16.34 16.383

Moisture Saturation at Stack Gas Temperature, % 15.86 15.86 16.07 15.930

Dry Mole Fraction 0.8414 0.8414 0.8393 0.841

Carbon Dioxide, % 13.33 13.33 13.33 13.330

Oxygen, % 6.15 6.11 6.13 6.130

Carbon Monoxide & Nitrogen, % 80.52 80.56 80.54 80.540

Fuel Factor 1.11 1.11 1.11

Dry Molecular Weight, lb/lb-Mole 30.38 30.38 30.38 30.380

Wet Molecular weight, lb/lb-Mole 28.52 28.51 28.44 28.490

Flue Gas Static Pressure, inches of H2O 0.27 0.21 0.26 0.247

Absolute Flue Gas Pressure, inches of Mercury 29.32 29.32 29.32 29.320

Average Stack Gas Temperature, °F 131.08 131.08 131.58 131.247

Average Velocity Head, inches of H2O 0.8710335710

84044

0.873079741

952828

0.886758729

560565

0.877

Average Stack Gas Velocity, feet/second 56.35 56.42 56.96 56.577

Stack Cross-Sectional Area, square feet 548.082 548.082 548.082 548.082

Dry Volumetric Flow Rate, dry scfm 1,364,844.7 1,366,540.2 1,375,013.0 1,368,799.3

00

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,853,065.2 1,855,367.2 1,873,125.0 1,860,519.1

33

Percent Isokinetic of Sampling Rate, % 101.0 100.4 102.2 101.200

Percent Excess Air, % 40.7 40.3 40.5 40.500

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

Round Duct Diameter, inches 317 317 317

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 02, 2011 Page 9 of 13
9/2/2010

Location Stack Exit - Method 3A CO2

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Wednesday, February 02, 2011 Page 10 of 13
9/2/2010

Location Stack Exit - Method 3A O2

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Wednesday, February 02, 2011 Page 11 of 13
9/2/2010

Location Stack Exit - Method 6C

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Wednesday, February 02, 2011 Page 12 of 13
9/2/2010

Location Stack Exit - Method 7E

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Wednesday, February 02, 2011 Page 13 of 13