Name: Jon Hays

Title: Environmental Specialist

Company: Duke Energy

Sign Date:

Name: Patrick Ford

Title: Technical Director, Air Measuremen

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 02, 2011 Page 1 of 15
Facility Information:

NC_Belews Creek Steam Station

3195 Pine Hall Road

Belews Creek NC 27009

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:

01983T22

Permitted Source ID/Name:

ES-1 No. 2 Fuel Oil/Coal-Fired Electric Utility Boiler

Permitted Maximum Process Rate:

12,000 Million Btu/hour

Max. Normal Operation Process Rate:

9,800 Million Btu/hour

Target Process Test Rate

9,800 Million Btu/hour

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 #: 3716900004 FRS #: 110000604141

SCC / Description 10100222 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 432 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 3 180 0

Wednesday, February 02, 2011 Page 2 of 15
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.

EPA Method 26A was modified to include the provisions cited in Method CTM-033 to allow simultaneous collection 

of HCl, HF and HCN. Modification included elimination of the 0.1 N H2SO4 impingers, addition of a third NaOH 

impinger and use of high normality NaOH absorbing solutions (6N in the 1st impinger and 2 N in the second and 

third) in order to maintain the pH of the solution high enough to prevent poor HCN analyte collection. The sample 

time was also reduced to 1-hour as allowed by EPA (see FAQ's section on the ICR website) again to ensure that the 

pH of the absorbing solution remained high.

Wednesday, February 02, 2011 Page 3 of 15
Sampling / Stack Data Results Summary

Location Stack Exit - Method 26A

Average

Run Number M26A-3 M26A-4 M26A-5

Test Date 3/4/2010 3/4/2010 3/4/2010

Run Start Time 9:00:00 AM 11:35:00 

AM

1:35:00 PM

Run Finish Time 10:26:00 AM 1:17:00 

PM

2:57:00 PM

Net Run Time, minutes 60 60 60

Dry Gas Meter Volume Sampled, dscf 39.315 38.355 37.968 38.546

Moisture Content of Stack Gas, % 13.49 12.78 14.31 13.527

Moisture Saturation at Stack Gas Temperature, % 12.46 12.35 12.35 12.387

Carbon Dioxide, % 13.47 13.53 13.53 13.510

Oxygen, % 6.08 6.05 6.08 6.070

Average Stack Gas Temperature, °F 121.33 121.00 121.00 121.110

Dry Volumetric Flow Rate, dry scfm 2,521,493.5 2,510,718.

5

2,476,701.7 2,502,971.23

3

Actual Wet Volumetric Flue Gas Flow Rate, acfm 3,310,743.5 3,290,589.

5

3,246,006.6 3,282,446.53

3

Percent Isokinetic of Sampling Rate, % 104.9 102.8 103.2 103.633

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 15
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 15
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 15
Emissions Summary

Process Run Data

Location: Stack Exit - Method 26A

Compound: Hydrogen Chloride

Average

RunNumber M26A-3 M26A-4 M26A-5

Mass_mg 0.41 1.051 0.939 0.800

Elb/hr 3.48E+00 9.10E+00 8.10E+00 6.893

lb/mmBtuO2 3.17E-04 8.32E-04 7.52E-04 0.001

mg/dscm 3.68E-01 9.68E-01 8.74E-01 0.737

mg/dscm@7%O2 3.45E-01 9.06E-01 8.20E-01 0.690

Compound: Hydrogen Fluoride

Average

RunNumber M26A-3 M26A-4 M26A-5

Mass_mg 1.18 0.64 1.25 1.023

Elb/hr 1.00E+01 5.54E+00 1.08E+01 8.780

lb/mmBtuO2 9.13E-04 5.06E-04 1.00E-03 0.001

mg/dscm 1.06E+00 5.89E-01 1.16E+00 0.936

mg/dscm@7%O2 9.94E-01 5.51E-01 1.09E+00 0.878

Location: Stack Exit - Method 6C

Compound: Sulfur Dioxide

Average

Run 3 4 5

Elb/hr 5.23E+02 5.37E+02 5.27E+02 529.000

lb/mmBtuO2 4.75E-02 4.90E-02 4.86E-02 0.048

ppm 2.07E+01 2.14E+01 2.12E+01 21.100

ppm@7%O2 1.94E+01 2.00E+01 1.99E+01 19.767

Location: Stack Exit - Method 7E

Compound: Nitrogen oxides (NOx)

Average

Run 3 4 5

Elb/hr 4.66E+02 4.87E+02 5.03E+02 485.333

lb/mmBtuO2 4.23E-02 4.44E-02 4.64E-02 0.044

ppm 2.57E+01 2.70E+01 2.82E+01 26.967

ppm@7%O2 2.41E+01 2.53E+01 2.64E+01 25.267

Wednesday, February 02, 2011 Page 7 of 15
Process Run Data

Run Name Value UOM Comments

Target

Value

1 Heat Input Million Btus/million BTU using O2 0 0

2 Heat Input Million Btus/million BTU using O2 0 0

3 Heat Input Million Btus/million BTU using O2 0 0

1 Average Heat Input 0 MMBtu/hr 0

2 Average Heat Input 0 MMBtu/hr 0

3 Average Heat Input 0 MMBtu/hr 0

1 Steam Output 0 1000 lb steam/hr 0

2 Steam Output 0 1000 lb steam/hr 0

3 Steam Output 0 1000 lb steam/hr 0

1 Synfuel Firing Rate 0 1000 Tons/hr 0

2 Synfuel 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

2 Petroleum Coke Firing Rate 0 1000 Tons/hr 0

3 Petroleum Coke Firing Rate 0 1000 Tons/hr 0

1 Coal Gas Firing Rate 0 Ft^3/min 0

2 Coal 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

2 Fuel Oil Firing Rate 0 gal/hr 0

3 Fuel Oil Firing Rate 0 gal/hr 0

1 Flue Gas Flow Rate 0 0

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

1 FGD Scrubber Liquor pH 0 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 0 % 0

1 Flue Gas Carbon Dioxide Content 0 % 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

Wednesday, February 02, 2011 Page 8 of 15
APCD Run Data

Process Lab Run Data

1 Unit Gross Electrical Output 0 Mwe 0

1 Unit Net Electric Generation 0 MWh 0

4 Heat Input Million Btus/million BTU using O2 0 0

4 Average Heat Input 0 MMBtu/hr 0

4 Steam Output 0 1000 lb steam/hr 0

4 Synfuel Firing Rate 0 1000 Tons/hr 0

4 Petroleum Coke Firing Rate 0 1000 Tons/hr 0

4 Coal Gas Firing Rate 0 Ft^3/min 0

4 Fuel Oil Firing Rate 0 gal/hr 0

4 Flue Gas Flow Rate 0 0

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

4 FGD Scrubber Liquor pH 0 pH 0

4 FGD Scrubber Liquor Flow Rate 0 gal/min 0

4 Sorbent Type and Sorbent Injection Rate (if 

applicable)

0 lb/hr 0

4 Flue Gas Oxygen Content 0 % 0

4 Flue Gas Carbon Dioxide Content 0 % 0

4 Flue Gas Moisture Content 0 % 0

4 Flue Gas Sampling Point Temperature 0 Deg F 0

4 Flue Gas Pressure 0 atm 0

4 Standard Pressure 0 atm 0

4 Standard Temperature 0 Deg F 0

4 Unit Gross Electrical Output 0 Mwe 0

4 Unit Net Electric Generation 0 MWh 0

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 %

Wednesday, February 02, 2011 Page 9 of 15
1 Ultimate/Proximate Analysis 0

1 Fuel Chlorine Content 0 ppm

1 Fuel Fluorine Content 0 ppm

Wednesday, February 02, 2011 Page 10 of 15
Sampling / Stack Data Results Detail

Location Stack Exit - Method 26A

Average

Run Number M26A-3 M26A-4 M26A-5

Test Date 3/4/2010 3/4/2010 3/4/2010

Run Start Time 9:00:00 AM 11:35:00 AM 1:35:00 PM

Run Finish Time 10:26:00 AM 1:17:00 PM 2:57:00 PM

Net Traversing Points 12 12 12

Net Run Time, minutes 60 60 60

Nozzle Diameter, inches 0.215 0.215 0.215 0.215

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 28.7 28.7 28.7 28.700

Average Orifice Meter Differential, inches H2O 1.44 1.43 1.42 1.430

Dry Gas Meter Volume Sampled, cubic feet 40.720 39.764 39.619 40.034

Average Dry Gas Meter Temperature, °F 79.67 80.17 83.67 81.170

Dry Gas Meter Volume Sampled, dscf 39.315 38.355 37.968 38.546

Total Moisture Liquid collected, g 130.2 119.4 134.6 128.067

Volume of Water Vapor, standard cubic feet 6.13 5.62 6.34 6.030

Moisture Content of Stack Gas, % 13.49 12.78 14.31 13.527

Moisture Saturation at Stack Gas Temperature, % 12.46 12.35 12.35 12.387

Dry Mole Fraction 0.8754 0.8765 0.8765 0.876

Carbon Dioxide, % 13.47 13.53 13.53 13.510

Oxygen, % 6.08 6.05 6.08 6.070

Carbon Monoxide & Nitrogen, % 80.45 80.42 80.39 80.420

Fuel Factor 1.10 1.10 1.10

Dry Molecular Weight, lb/lb-Mole 30.40 30.41 30.41 30.407

Wet Molecular weight, lb/lb-Mole 29.04 28.95 29.23 29.073

Flue Gas Static Pressure, inches of H2O -0.6 -0.6 -0.61 -0.603

Absolute Flue Gas Pressure, inches of Mercury 28.66 28.66 28.66 28.660

Average Stack Gas Temperature, °F 121.33 121.00 121.00 121.110

Average Velocity Head, inches of H2O 0.8157847183

20918

0.803804547

177154

0.789811455

97504

0.803

Average Stack Gas Velocity, feet/second 54.21 53.88 53.15 53.747

Stack Cross-Sectional Area, square feet 1,017.876 1,017.876 1,017.876 1,017.876

Dry Volumetric Flow Rate, dry scfm 2,521,493.5 2,510,718.5 2,476,701.7 2,502,971.2

33

Actual Wet Volumetric Flue Gas Flow Rate, acfm 3,310,743.5 3,290,589.5 3,246,006.6 3,282,446.5

33

Percent Isokinetic of Sampling Rate, % 104.9 102.8 103.2 103.633

Percent Excess Air, % 40.1 39.9 40.2 40.067

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

Round Duct Diameter, inches 432 432 432

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 11 of 15
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 12 of 15
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 13 of 15
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 14 of 15
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 15 of 15