### Name: Steve Strunk

Title: Specialist Air Permitting Compliance Company: Tennessee Valley Authority Sign Date: 9/30/2010 Name: Jim Diederich Title: System Engineer Performance Evalu Company: Tennessee Valley Authority Sign Date: 9/30/2010 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.

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Facility Information:

Cumberland Fossil Plant Unit 2 815 Cumberland City Road

Cumberland City TN 37050
Contact: Steve Strunk

Phone: 423-751-2808

Fax: 423-751-7011

Email: scstrunk@tva.gov Testing Company: TVA Performance Engineering

1101 Market Street

PSC 1B-C Chattanooga TN 37402
Contact: Jim Diederich

Phone: 423-876-6730

Fax: 423-876-6734
Email: jadiederich@tva.gov

Air Permit Number:
546465 Permitted Source ID/Name:
Cumberland Fossil Plant 3399
Permitted Maximum Process Rate: Max. Normal Operation Process Rate: Target Process Test Rate

Description of the source (including control equipment). Please see the attachments for source or process flow diagram: Cumberland Unit 2 is a pulverized coal-fired, supercritical, cell-fired once-through steam generator with a Maximum Continuous Rating of 10 Mlb/hr reheat steam flow. Steam pressure at the turbine first stage is 3500 psig. Final superheat and reheat temperatures are 1003°F. There are 88 burners installed in an opposed firing pattern four rows high on both the front and rear wall. 11 MPS 89 mills feed pulverized coal to the burners. The unit is equipped with low NOx burners and a selective catalyst reduction (SCR) system for NOx emissions control, an electrostatic precipitator for removal of particulate matter as well as a wet scrubber for control of SO2 emissions and additional particulate removal. Industry/SCC/NAIS 221112

Sampling Location Information:

Test Parameter Information: AFS #: 4716100011 FRS #: 110000493127

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 462 1617 3095.4 4 0 16 0 0

Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location Hydrogen Fluoride Method 26A 3 180 0 Stack Hydrogen Chloride Method 26A 3 180 0 Stack O2 Method 3A O2 3 120 0 Stack Co2 Method 3A CO2 3 120 0 Stack



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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.

MANUAL COAL COLLECTION IN SUPPORT OF HAPS TESTING AT CUF

Preliminary communication with plant operations and engineering indicated that manual sampling from the coal feeders prior to the pulverizers would be possible because it is regularly performed to collect “grab” samples. On June 8, prior to the beginning of HAPS sampling, in conversations with operations we determined that due to the positive pressure in the feed system that a gate would need to be closed between the pulverizer and the feeder while samples were being collected. This was not an issue until we discovered that oil guns automatically came on to maintain a flame when a pulverizer was isolated. It was calculated that the oil input would constitute 3% to 5% of the Btus for the test period. The input of the oil firing was considered to be too significant to collect samples from the feeders.

Another possible sample collection point considered was the pipe between the coal bunker and the belt feeder. However, there was no way to collect a sample that would comply with ASTM coal sampling standards.

The decision was made to collect the manual coal samples from the head pulleys of the belts feeding the bunkers. All samples were collected using methods that comply with ASTM standards. The bunker feed belts do not run continuously as the feeders, so the coal was collected during the bunker filling run during or prior to the stack test.

Sulfur Dioxide Method 6C 3 120 0 Stack Nitrogen oxides (NOx) Method 7E 3 120 0 Stack



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Sampling / Stack Data Results Summary



### Location Stack - Method 26A Average
Run Number 1 2 3

Test Date 6/25/2010 6/25/2010 6/27/2010

Run Start Time 11:01:00 AM 4:35:00 PM 3:20:00 PM

Run Finish Time 3:15:00 PM 8:40:00 PM 7:15:00 PM
Net Run Time, minutes 192 208 208 Dry Gas Meter Volume Sampled, dscf 84.036 94.935 95.990 91.654
Moisture Content of Stack Gas, % 17.75 17.99 17.53 17.757 Moisture Saturation at Stack Gas Temperature, % 15.83 16.29 15.91 16.010
Carbon Dioxide, % 13.282 13.304 13.23 13.272 Oxygen, % 5.53 5.456 5.94 5.642 Average Stack Gas Temperature, °F 130.75 131.69 130.56 131.000 Dry Volumetric Flow Rate, dry scfm 2,769,934.9 2,817,363.1 2,871,104.9 2,819,467.63 3
Actual Wet Volumetric Flue Gas Flow Rate, acfm 3,784,438.3 3,889,910.9 3,963,252.7 3,879,200.63 3 Percent Isokinetic of Sampling Rate, % 95.4 97.8 97.1 96.767
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 - 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



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Location Stack - 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 - 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



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Location Stack - 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



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Emissions Summary

Process Run Data 

### Location: Stack - Method 26A Compound: Hydrogen Chloride Average RunNumber 1 2 3 Mass_mg 0.882 1.01 1.23 1.041 lb/mmBtuO2 3.08E-04 3.10E-04 3.86E-04 0.000


### Compound: Hydrogen Fluoride Average RunNumber 1 2 3 Mass_mg 0.37 0.48 0.44 0.430 lb/mmBtuO2 1.29E-04 1.48E-04 1.38E-04 0.000



### Location: Stack - Method 6C Compound: Sulfur Dioxide Average
Run 1 2 3 lb/mmBtuO2 2.07E-01 1.91E-01 2.28E-01 0.209
ppm 9.38E+01 8.67E+01 1.01E+02 93.833 ppm@7%O2 8.48E+01 7.80E+01 9.36E+01 85.467



### Location: Stack - Method 7E Compound: Nitrogen oxides (NOx) Average
Run 1 2 3 lb/mmBtuO2 5.39E-02 5.38E-02 5.88E-02 0.056
ppm 3.39E+01 3.40E+01 3.62E+01 34.700 ppm@7%O2 3.07E+01 3.06E+01 3.35E+01 31.600



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Process Run Data

APCD Run Data

Process Lab Run Data 

### Run Name Value UOM Comments Target Value
1 Heat Input 11832 MMBtu/hr M26a Run 1 0



### 1 Gross Electric Generation 1260 MW M26a Run 1 0

2 Heat Input 11890 MMBtu/hr M26a Run 2 0

2 Gross Electric Generation 1262 MW M26a Run 2 0



### 3 Heat Input 11817 MMBtu/hr M26a Run 3 0

3 Gross Electric Generation 1245 MW M26a Run 3 0



### Run Name Value UOM Comments Target Value
1 ELECTROSTATIC PRECIPITATOR 0 0



### 1 LOW NOX BURNERS 0 0

1 WET SCRUBBER 0 0

1 SCR (SELECTIVE CATALYTIC REDUCTION) 0 0



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Sampling / Stack Data Results Detail



### Location Stack - Method 26A Average Run Number 1 2 3
Test Date 6/25/2010 6/25/2010 6/27/2010 Run Start Time 11:01:00 AM 4:35:00 PM 3:20:00 PM Run Finish Time 3:15:00 PM 8:40:00 PM 7:15:00 PM Net Traversing Points 16 17 17 Net Run Time, minutes 192 208 208 Nozzle Diameter, inches 0.188 0.188 0.188 0.188 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 1.009 1.009 1.009 1.009 Barometric Pressure, inches of Mercury 29.181 29.075 28.899 29.052 Average Orifice Meter Differential, inches H2O 0.79 0.83 0.86 0.827 Dry Gas Meter Volume Sampled, cubic feet 91.996 104.843 106.226 101.022 Average Dry Gas Meter Temperature, °F 109.94 112.94 110.69 111.190 Dry Gas Meter Volume Sampled, dscf 84.036 94.935 95.990 91.654 Total Moisture Liquid collected, g 385.1 442.4 433.3 420.267 Volume of Water Vapor, standard cubic feet 18.13 20.82 20.40 19.783 Moisture Content of Stack Gas, % 17.75 17.99 17.53 17.757 Moisture Saturation at Stack Gas Temperature, % 15.83 16.29 15.91 16.010 Dry Mole Fraction 0.8417 0.8371 0.8409 0.840 Carbon Dioxide, % 13.282 13.304 13.23 13.272 Oxygen, % 5.53 5.456 5.94 5.642 Carbon Monoxide & Nitrogen, % 81.188 81.24 80.83 81.086 Fuel Factor 1.16 1.16 1.13 Dry Molecular Weight, lb/lb-Mole 30.35 30.35 30.35 30.350 Wet Molecular weight, lb/lb-Mole 28.74 28.64 28.68 28.687 Flue Gas Static Pressure, inches of H2O -0.9 -0.9 -1 -0.933 Absolute Flue Gas Pressure, inches of Mercury 29.11 29.01 28.83 28.983 Average Stack Gas Temperature, °F 130.75 131.69 130.56 131.000 Average Velocity Head, inches of H2O 0.8060180734 54594 0.844421625

819848 0.874200033

610572 0.842

Average Stack Gas Velocity, feet/second 54.18 55.69 56.74 55.537 Stack Cross-Sectional Area, square feet 1,164.156 1,164.156 1,164.156 1,164.156 Dry Volumetric Flow Rate, dry scfm 2,769,934.9 2,817,363.1 2,871,104.9 2,819,467.6 33 Actual Wet Volumetric Flue Gas Flow Rate, acfm 3,784,438.3 3,889,910.9 3,963,252.7 3,879,200.6 33 Percent Isokinetic of Sampling Rate, % 95.4 97.8 97.1 96.767 Percent Excess Air, % 34.8 34.1 38.6 35.833 F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000 Round Duct Diameter, inches 462 462 462 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



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Location Stack - 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



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Location Stack - 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



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Location Stack - 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



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Location Stack - 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



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