### Name: Kristin DuBois

Title: Environmental Officer Company: Golden Valley Electric Association Sign Date: 8/16/2010 Name: William M Hudson III Title: President Company: Alaska Source Testing LLC Sign Date: 8/16/2010 Permitted Facility Representative / Date Testing Company Representative / Date



## Golden Valley Electric Association Healy Power Plant

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.

Saturday, January 29, 2011 Page 1 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010 Facility Information: Golden Valley Electric Association Healy P 2.5 Mile Healy Spur Road
PO Box 297 Healy AK 99743-0297 Contact: Kris DuBois Phone: 907-451-5627 Fax: 907-451-5633 Email: KEDuBois@gvea.com Testing Company: Alaska Source Testing LLC
520 W 58th Ave Unit A

Anchorage AK 99518 Contact: William M Hudson III Phone: 907-562-2880 Fax: 907-569-4225 Email: aktestin@alaska.net

Air Permit Number: AQ0173TVP01 Permitted Source ID/Name: Coal-Fired Steam Generator 1 Permitted Maximum Process Rate: 327 MMBtu/hr (unit's rating) Max. Normal Operation Process Rate: 350 MMBtu/hr Target Process Test Rate 350 MMBtu/hr

Description of the source (including control equipment). Please see the attachments for source or process flow diagram: The Foster-Wheeler coal-fired boiler is rated at 327 MMBtu/hr. The unit is fired with pulverized coal using distillatefuel during startup. The unit is equipped with a 12-module ICA reverse gas baghouse for particulate control, lowNOx burners for NOx control and sorbent injection for SO2 control. Industry/SCC/NAIS 221112

Sampling Location Information: AFS #: 6288 FRS #: 110041252621

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 0 180 300 6 60 28 43 101 Regulation Description Compound Limit Unit Section 114 of CAA Sulfur Dioxide 0 ppm corrected Section 114 of CAA Nitrogen oxides (NOx) 0 ppm corrected Section 114 of CAA Hydrogen Chloride 0 lb/million BTU using O2 Section 114 of CAA Hydrogen Fluoride 0 lb/million BTU using O2 Section 114 of CAA O2 0 percent(%) Section 114 of CAA Co2 0 percent(%) Section 114 of CAA moisture 0 percent(%) Section 114 of CAA hydrogen cyanide 0 lb/million BTU using O2



### Saturday, January 29, 2011 Page 2 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010

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.
None Test Parameter Information: Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location % H2O Method 1 - 4 3 180 0 results in M26A data Stack Hydrogen Chloride Method 26A 3 180 0 Stack Hydrogen Fluoride Method 26A 3 180 0 Stack O2 Method 3A O2 3 180 0 Tedlar bag used for Run 1 Stack

Co2 Method 3A CO2 3 180 0 Tedlar bag used for Run 1 Stack

Sulfur Dioxide Method 6C 3 60 0 Stack Nitrogen oxides (NOx) Method 7E 3 60 0 Stack



### Saturday, January 29, 2011 Page 3 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010 Sampling / Stack Data Results Summary



### Location Stack - Method 26A Average Run Number 1 2 3
Test Date 5/25/2010 5/26/2010 5/27/2010 Run Start Time 1:20:00 PM 1:20:00 PM 1:20:00 PM Run Finish Time 4:14:00 PM 4:14:00 PM 4:14:00 PM Net Run Time, minutes 180 180 180 Dry Gas Meter Volume Sampled, dscf 115.342 94.673 93.191 101.069 Moisture Content of Stack Gas, % 13.27 13.41 13.24 13.307 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Carbon Dioxide, % 14.2 14.2 14.14 14.180 Oxygen, % 5.7 5.67 5.86 5.743 Average Stack Gas Temperature, °F 322.27 322.13 321.23 321.877 Dry Volumetric Flow Rate, dry scfm 72,806.4 75,175.4 74,780.2 74,254.000 Actual Wet Volumetric Flue Gas Flow Rate, acfm 127,920.6 132,227.5 131,666.5 130,604.867 Percent Isokinetic of Sampling Rate, % 100.6 106.1 104.9 103.867 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



### Saturday, January 29, 2011 Page 4 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010
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



### Saturday, January 29, 2011 Page 5 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010
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



### Saturday, January 29, 2011 Page 6 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010 Emissions Summary

Process Run Data 

### Location: Stack - Method 26A Compound: Hydrogen Chloride Average RunNumber 1 2 3 Mass_mg 0 0.42 0.55 0.323 lb/mmBtuO2 0.00E+00 1.31E-04 1.77E-04 0.000 mg/dscm 0.00E+00 1.57E-01 2.08E-01 0.122 

### Compound: Hydrogen Fluoride Average RunNumber 1 2 3 Mass_mg 8.3 8 10.2 8.833 lb/mmBtuO2 2.13E-03 2.50E-03 3.28E-03 0.003 mg/dscm 2.54E+00 2.98E+00 3.87E+00 3.130



### Location: Stack - Method 6C 

### Compound: Sulfur Dioxide Average Run 1 2 3 lb/mmBtuO2 3.37E-01 3.51E-01 3.50E-01 0.346 ppm 1.52E+02 1.55E+02 1.58E+02 155.000 ppm@7%O2 1.38E+02 1.43E+02 1.43E+02 141.333



### Location: Stack - Method 7E 

### Compound: Nitrogen oxides (NOx) Average Run 1 2 3 lb/mmBtuO2 2.66E-01 2.73E-01 2.61E-01 0.267 ppm 1.67E+02 1.68E+02 1.65E+02 166.667 ppm@7%O2 1.52E+02 1.56E+02 1.49E+02 152.333



### Saturday, January 29, 2011 Page 7 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010 Process Run Data

APCD Run Data

Process Lab Run Data 

### Run Name Value UOM Comments Target Value 1 Total Heat Input 343.6 MMBtu/hr 350


### 2 Total Heat Input 354.3 MMBtu/hr 350
3 Total Heat Input 350.8 MMBtu/hr 350
1 Coal Feed Rate 49485 lb/hr 50000


### 2 Coal Feed Rate 50348 lb/hr 50000
3 Coal Feed Rate 50926 lb/hr 50000
1 Steam Output 246.2 1000lb steam/hr 246


### 2 Steam Output 246 1000lb steam/hr 246
3 Steam Output 246 1000lb steam/hr 246
1 Gross electrical Output 27.7 MW 28


### 2 Gross electrical Output 28.2 MW 28
3 Gross electrical Output 28 MW 28
1 Net Electrical Output 25.2 MW 25


### 2 Net Electrical Output 25.6 MW 25
3 Net Electrical Output 25.7 MW 25
1 Heat Input 0 Million Btus 350

Run Name Value UOM Comments Target Value 

### 1 BAGHOUSE 7.72 differential pressure, "H20 0
2 BAGHOUSE 7.73 differential pressure, "H20 0


### 3 BAGHOUSE 7.75 differential pressure, "H20 0
1 LOW NOX BURNERS 0 0
2 LOW NOX BURNERS 0 0


### 3 LOW NOX BURNERS 0 0
1 sorbent injection 49.5 lb/hr 0
2 sorbent injection 49.4 lb/hr 0


### 3 sorbent injection 47.2 lb/hr 0

Run Name Value UOM Comments 1 coal analysis for chlorine and fluorine 0 1 coal analysis for GCV 0



### Saturday, January 29, 2011 Page 8 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010 Sampling / Stack Data Results Detail



### Location Stack - Method 26A Average Run Number 1 2 3 Test Date 5/25/2010 5/26/2010 5/27/2010 Run Start Time 1:20:00 PM 1:20:00 PM 1:20:00 PM Run Finish Time 4:14:00 PM 4:14:00 PM 4:14:00 PM Net Traversing Points 30 30 30 Net Run Time, minutes 180 180 180 Nozzle Diameter, inches 0.22 0.191 0.191 0.201 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 1.01 1.01 1.01 1.010 Barometric Pressure, inches of Mercury 28.91 28.92 28.83 28.887 Average Orifice Meter Differential, inches H2O 2.09 1.31 1.30 1.567 Dry Gas Meter Volume Sampled, cubic feet 125.919 103.697 101.912 110.509 Average Dry Gas Meter Temperature, °F 105.52 106.47 103.80 105.263 Dry Gas Meter Volume Sampled, dscf 115.342 94.673 93.191 101.069 Total Moisture Liquid collected, g 375 311.5 302 329.500 Volume of Water Vapor, standard cubic feet 17.65 14.66 14.22 15.510 Moisture Content of Stack Gas, % 13.27 13.41 13.24 13.307 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Dry Mole Fraction 0.8673 0.8659 0.8676 0.867 Carbon Dioxide, % 14.2 14.2 14.14 14.180 Oxygen, % 5.7 5.67 5.86 5.743 Carbon Monoxide & Nitrogen, % 80.1 80.13 80 80.077 Fuel Factor 1.07 1.07 1.06 Dry Molecular Weight, lb/lb-Mole 30.50 30.50 30.50 30.500 Wet Molecular weight, lb/lb-Mole 28.84 28.82 28.85 28.837 Flue Gas Static Pressure, inches of H2O 2.5 2.5 2 2.333 Absolute Flue Gas Pressure, inches of Mercury 29.09 29.10 28.98 29.057 Average Stack Gas Temperature, °F 322.27 322.13 321.23 321.877 Average Velocity Head, inches of H2O 1.0392610114 1705 1.110073650

68314 1.098559112

18525 1.083
Average Stack Gas Velocity, feet/second 70.69 73.07 72.76 72.173 Stack Cross-Sectional Area, square feet 30.160 30.160 30.160 30.160 Dry Volumetric Flow Rate, dry scfm 72,806.4 75,175.4 74,780.2 74,254.000 Actual Wet Volumetric Flue Gas Flow Rate, acfm 127,920.6 132,227.5 131,666.5 130,604.867 Percent Isokinetic of Sampling Rate, % 100.6 106.1 104.9 103.867 Percent Excess Air, % 36.9 36.6 38.4 37.300 F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000 Round Duct Diameter, inches 0 0 0 Rectangular Duct Width, inches 43 43 43 Rectangular Duct Length, inches 101 101 101 Fw 10640 10640 10640 10,640.000 Fc 1800 1800 1800 1,800.000



### Saturday, January 29, 2011 Page 9 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010
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



### Saturday, January 29, 2011 Page 10 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010
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



### Saturday, January 29, 2011 Page 11 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010
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



### Saturday, January 29, 2011 Page 12 of 13

### Golden Valley Electric Association Healy Power Plant
8/16/2010
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



### Saturday, January 29, 2011 Page 13 of 13