### 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: No. 2 Fuel Oil/Coal-Fired Electric Utility Boiler ES-1 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 8 2 4 0 12 0 0

Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location % 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 Stack Exit



### 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 0 Million Btus/million BTU using O2 0


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