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:

1 Coal-Fired Steam Generator

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 distillate 

fuel 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 0 101 43 60 180 300 6 28

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 

Location Points Comments

Stack % 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

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

Stack Sulfur Dioxide Method 6C 3 60 0

Stack Nitrogen oxides (NOx) Method 7E 3 60 0

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, "H200

2 BAGHOUSE 7.73 differential pressure, "H200

3 BAGHOUSE 7.75 differential pressure, "H200

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