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.

Tuesday, February 15, 2011 Page 1 of 13
9/30/2010

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:

3399 Cumberland Fossil Plant

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 0 0 0 1617 3095.4 4 16

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Stack 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

Tuesday, February 15, 2011 Page 2 of 13
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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.

Stack Sulfur Dioxide Method 6C 3 120 0

Stack Nitrogen oxides (NOx) Method 7E 3 120 0

Tuesday, February 15, 2011 Page 3 of 13
9/30/2010

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

Tuesday, February 15, 2011 Page 4 of 13
9/30/2010

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

Tuesday, February 15, 2011 Page 5 of 13
9/30/2010

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

Tuesday, February 15, 2011 Page 6 of 13
9/30/2010

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

Tuesday, February 15, 2011 Page 7 of 13
9/30/2010

Process Run Data

APCD Run Data

Process Lab Run Data

Run Name Value UOM Comments

Target

Value

1 Heat Input 11832 MMBtu/hr 0 M26a Run 1

1 Gross Electric Generation 1260 MW 0 M26a Run 1

2 Heat Input 11890 MMBtu/hr 0 M26a Run 2

2 Gross Electric Generation 1262 MW 0 M26a Run 2

3 Heat Input 11817 MMBtu/hr 0 M26a Run 3

3 Gross Electric Generation 1245 MW 0 M26a Run 3

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

Tuesday, February 15, 2011 Page 8 of 13
9/30/2010

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

Tuesday, February 15, 2011 Page 9 of 13
9/30/2010

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

Tuesday, February 15, 2011 Page 10 of 13
9/30/2010

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

Tuesday, February 15, 2011 Page 11 of 13
9/30/2010

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

Tuesday, February 15, 2011 Page 12 of 13
9/30/2010

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

Tuesday, February 15, 2011 Page 13 of 13