Name: Howard Vickers

Title: Environmental Supervisor

Company: Deseret Power Electric Cooperative

Sign Date: 6/10/2010

Name: Chet Gutwein

Title: Engineer

Company: Airtech Environmental Services Inc.

Sign Date: 6/10/2010

Permitted Facility Representative / Date Testing Company Representative / Date

3242 Deseret Power Electric Cooperative

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.

Thursday, February 03, 2011 Page 1 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

Facility Information:

Bonanza Power Plant

12500 East 25500 South

Vernal UT 84078-8525

Contact: Howard Vickers

Phone: (435) 781-5706

Fax: (435) 781-5816

Email: howard1v@deseretpower.com

Testing Company:

Airtech Environmental Services Inc.

5776 Lamar Street

Arvada CO 80002

Contact:Jeff Johnson

Phone: (303) 670-0530

Fax: (303) 670-4130

Email: jjohnson@airtechenv.com

Air Permit Number:

PSD-UO-0001-2001:00

Permitted Source ID/Name:

7790 Boiler 1-1

Permitted Maximum Process Rate:

N/A

Max. Normal Operation Process Rate:

N/A

Target Process Test Rate

N/A

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

 process flow diagram:

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 #: 4904700001 FRS #: 110015757670

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 339.25 0 0 0 3240 2484 4 12

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Stack Exit % H2O Method 1 - 4 3 180 0

Stack Exit Carbon Monoxide Method 10 3 120 0

Total organic compounds 

(TOC) as Propane

Stack Exit Method 25A 3 120 0

Stack Exit Co2 Method 3A CO2 3 120 0

Stack Exit O2 Method 3A O2 3 120 0

Thursday, February 03, 2011 Page 2 of 14
3242 Deseret Power Electric Cooperative

The following describes any modifications and/or deviations to the applicable test 6/10/2010

methods. If alternative methods were requested, see the attachments for documentation 

of request AND approval, including dates.

The following is a list of the test methods that are to be used for this test program and their respective promulgation 

dates:

EPA Methods 1 through 25A - August 1997

EPA Method 316 - March 1997

Thursday, February 03, 2011 Page 3 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

Sampling / Stack Data Results Summary

Location Stack Exit - Method 1 - 4

Average

Run Number 1 2 3

Test Date 4/20/2010 4/20/2010 4/20/2010

Run Start Time 10:24:00 AM 1:42:00 PM 4:57:00 PM

Run Finish Time 1:00:00 PM 4:06:00 PM 7:23:00 PM

Net Run Time, minutes 120 120 120

Dry Gas Meter Volume Sampled, dscf 76.204 76.790 77.324 76.773

Moisture Content of Stack Gas, % 16.16 16.19 16.58 16.310

Moisture Saturation at Stack Gas Temperature, % 16.08 16.28 16.64 16.333

Carbon Dioxide, % 14.1 14.36 14.37 14.277

Oxygen, % 5.01 4.7 4.69 4.800

Average Stack Gas Temperature, °F 125.04 125.50 126.29 125.610

Dry Volumetric Flow Rate, dry scfm 1,200,306.9 1,200,831.9 1,210,834.7 1,203,991.16

7

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,929,115.3 1,934,011.5 1,961,882.3 1,941,669.70

0

Percent Isokinetic of Sampling Rate, % 101.4 102.2 102.0 101.867

F-Factor, dscfm/MMBtu @ %O2 9888 10099 9829 9,938.667

Fw 10906 11147 10857 10,970.000

Fc 1880 1914 1867 1,887.000

Location Stack Exit - Method 10

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

Thursday, February 03, 2011 Page 4 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

Location Stack Exit - Method 25A

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 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

Thursday, February 03, 2011 Page 5 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

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

Thursday, February 03, 2011 Page 6 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

Emissions Summary

Process Run Data

Location: Stack Exit - Method 1 - 4

Compound: % H2O

Average

RunNumber 1 2 3

Mass_mg 312100 315100 326500 317,900.000

Location: Stack Exit - Method 10

Compound: Carbon Monoxide

Average

Run 1 2 3

lb/mmBtuO2 6.76E+00 6.89E+00 6.74E+00 6.797

ppm 7.15E+03 7.27E+03 7.31E+03 7,243.333

ppm@7%O2 6.26E+03 6.24E+03 6.27E+03 6,256.667

Location: Stack Exit - Method 25A

Compound: Total organic compounds (TOC) as 

Average

Run 1 2 3

lb/mmBtuO2 2.64E-03 3.26E-03 3.24E-03 0.003

ppm 1.77E+00 2.18E+00 2.23E+00 2.060

ppm@7%O2 1.55E+00 1.87E+00 1.91E+00 1.777

Thursday, February 03, 2011 Page 7 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

Process Run Data

APCD Run Data

Process Lab Run Data

Run Name Value UOM Comments

Target

Value

1 Coal Burned 477.4 1000 Tons/hr 450

2 Coal Burned 477.4 1000 Tons/hr 450

3 Coal Burned 477.4 1000 Tons/hr 450

1 Average Heat Input 4451.5 MMBtu/hr 4500

2 Average Heat Input 4451.5 MMBtu/hr 4500

3 Average Heat Input 4451.5 MMBtu/hr 4500

1 Steam Output 2885.9 1000 lb steam/hr 3000

2 Steam Output 2885.9 1000 lb steam/hr 3000

3 Steam Output 2885.9 1000 lb steam/hr 3000

1 Flue Gas Flow Rate 1E+06 dscfm 1E+06

1 Pressure Drop Across FGD (if applicable) 4.08 in H20 4

1 FGD Scrubber Liquor pH 5.63 pH 5.5

1 FGD Scrubber Liquor Flow Rate 50.1 gal/min 60

1 Sorbent Type and Sorbent Injection Rate (if 

applicable)

11992 lb/hr 12000

1 Flue Gas Carbon Dioxide Content 11.8 % 12

1 Flue Gas Sampling Point Temperature 126.4 Deg F 128

1 Flue Gas Pressure 0.823 atm 0.82

1 Unit Gross Electrical Output 467 Mwe 450

1 Unit Net Electric Generation 460 MWh 460

Run Name Value UOM Comments

Target

Value

1 LOW NOX BURNERS 0 0

1 WET SCRUBBER 0 0

1 BAGHOUSE 0 0

Run Name Value UOM Comments

1 Fuel Higher Heating Value 11431 Btu/lb

1 Fuel Moisture 13.53 %

2 Fuel Higher Heating Value 11242 Btu/lb

2 Fuel Moisture 13.71 %

3 Fuel Higher Heating Value 11415 Btu/lb

Thursday, February 03, 2011 Page 8 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

3 Fuel Moisture 13.64 %

Thursday, February 03, 2011 Page 9 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

Sampling / Stack Data Results Detail

Location Stack Exit - Method 1 - 4

Average

Run Number 1 2 3

Test Date 4/20/2010 4/20/2010 4/20/2010

Run Start Time 10:24:00 AM 1:42:00 PM 4:57:00 PM

Run Finish Time 1:00:00 PM 4:06:00 PM 7:23:00 PM

Net Traversing Points 12 12 12

Net Run Time, minutes 120 120 120

Nozzle Diameter, inches 0.245 0.245 0.245 0.245

Pitot Tube Coefficient 0.84 0.84 0.84 0.840

Dry Gas Meter Calibration Factor 0.9888 0.9888 0.9888 0.989

Barometric Pressure, inches of Mercury 24.59 24.59 24.59 24.590

Average Orifice Meter Differential, inches H2O 1.74 1.72 1.76 1.740

Dry Gas Meter Volume Sampled, cubic feet 96.260 96.670 96.830 96.587

Average Dry Gas Meter Temperature, °F 84.83 82.94 80.15 82.640

Dry Gas Meter Volume Sampled, dscf 76.204 76.790 77.324 76.773

Total Moisture Liquid collected, g 312.1 315.1 326.5 317.900

Volume of Water Vapor, standard cubic feet 14.69 14.83 15.37 14.963

Moisture Content of Stack Gas, % 16.16 16.19 16.58 16.310

Moisture Saturation at Stack Gas Temperature, % 16.08 16.28 16.64 16.333

Dry Mole Fraction 0.8392 0.8381 0.8342 0.837

Carbon Dioxide, % 14.1 14.36 14.37 14.277

Oxygen, % 5.01 4.7 4.69 4.800

Carbon Monoxide & Nitrogen, % 80.89 80.94 80.94 80.923

Fuel Factor 1.13 1.13 1.13

Dry Molecular Weight, lb/lb-Mole 30.46 30.49 30.49 30.480

Wet Molecular weight, lb/lb-Mole 28.47 28.47 28.42 28.453

Flue Gas Static Pressure, inches of H2O -0.2 -0.2 -0.2 -0.200

Absolute Flue Gas Pressure, inches of Mercury 24.58 24.58 24.58 24.580

Average Stack Gas Temperature, °F 125.04 125.50 126.29 125.610

Average Velocity Head, inches of H2O 0.6084500125

8032

0.611170401

886897

0.626860445

192168

0.615

Average Stack Gas Velocity, feet/second 51.22 51.35 52.09 51.553

Stack Cross-Sectional Area, square feet 627.722 627.722 627.722 627.722

Dry Volumetric Flow Rate, dry scfm 1,200,306.9 1,200,831.9 1,210,834.7 1,203,991.1

67

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,929,115.3 1,934,011.5 1,961,882.3 1,941,669.7

00

Percent Isokinetic of Sampling Rate, % 101.4 102.2 102.0 101.867

Percent Excess Air, % 30.7 28.2 28.1 29.000

F-Factor, dscfm/MMBtu @ %O2 9888 10099 9829 9,938.667

Round Duct Diameter, inches 339.25 339.25 339.25

Rectangular Duct Width, inches 0 0 0

Rectangular Duct Length, inches 0 0 0

Fw 10906 11147 10857 10,970.000

Fc 1880 1914 1867 1,887.000

Thursday, February 03, 2011 Page 10 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

Location Stack Exit - Method 10

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

Thursday, February 03, 2011 Page 11 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

Location Stack Exit - Method 25A

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

Thursday, February 03, 2011 Page 12 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

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

Thursday, February 03, 2011 Page 13 of 14
3242 Deseret Power Electric Cooperative

6/10/2010

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

Thursday, February 03, 2011 Page 14 of 14