### 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: Boiler 1-1 7790 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 3240 2484 4 0 12 0 0

Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location % H2O Method 1 - 4 3 180 0 Stack Exit Carbon Monoxide Method 10 3 120 0 Stack Exit Total organic compounds

(TOC) as Propane Method 25A 3 120 0 Stack Exit

Co2 Method 3A CO2 3 120 0 Stack Exit O2 Method 3A O2 3 120 0 Stack Exit



### Thursday, February 03, 2011 Page 2 of 14

### 3242 Deseret Power Electric Cooperative
6/10/2010 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. 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