Name: Samuel Devlin

Title: Plant Manager Company: Tucson Electric Power Sign Date: 8/11/2010 Name: Larry Cottone Title: Project Manager Company: CCI Environmental Sign Date: 8/11/2010 Permitted Facility Representative / Date Testing Company Representative / Date 

### Information Collection Request, TEP - Springerville Generation Station Unit 2 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 10, 2011 Page 1 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 Facility Information: Springerville Generating Station Off Route 191 approx 15 Miles NE of city P.O. Box 2222 Springerville AZ 85938 Contact: Amy Pulsifer Phone: 928 337 7429 Fax: Email: Testing Company: CCI Environmental Consultants, Inc. 3855 South 500 West, Suite I

Salt Lake City UT 84115 Contact: Larry Cottone Phone: 801.269.0550 Fax: Email:

Air Permit Number: 32008 Permitted Source ID/Name: Unit 2 Boiler 2 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: A). Process Description and Operation The Tucson Electric Power Company (TEP) operates four coal-fired boilers at their Springerville Generating Station (SGS) near Springerville, Arizona. They are designated as Units 1, 2, TS3 and 4. Unit 2 is rated at 380 megawatts net. Particulate matter and SO2 are controlled by dry SO2 scrubbers followed by fabric filter bag houses. Unit 2 falla under the acid rain regulations of the 1990 Clean Air Act Amendments including the continuous emission monitoring system (CEMS) requirements of 40 CFR Part 75. TEP Springerville operates CEMS for NOX, SO2, CO2, and flow on Unit 2 to satisfy Part 60 and 75 requirements. B). Control Equipment Description Sulfur dioxide emissions are controlled by a dry scrubber. The dry scrubber is followed by a bag house to remove particulate matter. Industry/SCC/NAIS 221112

Sampling Location Information:

Test Parameter Information: AFS #: 8223 FRS #: 110000600788

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 240 2000 500 4 0 12 0 0

Thursday, February 10, 2011 Page 2 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010

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. Not applicable. Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location % H2O Method 1 - 4 3 120 0 Stack Exit Carbon Monoxide Method 10 3 120 0 Stack Exit Custom Method 18 3 120 0 Methane (CH4) Stack Exit Total organic compounds

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

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

Thursday, February 10, 2011 Page 3 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 Sampling / Stack Data Results Summary
Location Stack Exit - Method 10 Average Run Number 4 5 6 Test Date 2/26/2010 2/26/2010 2/26/2010 Run Start Time 9:18:00 AM 12:43:00 PM 4:00:00 PM

Run Finish Time 11:18:00 AM 2:43:00 PM 6:00:00 PM Carbon Dioxide, % 10.443 10.36 10.139 10.314 Oxygen, % 8.832 8.81 8.9216 8.855 Dry Volumetric Flow Rate, dry scfm 1100077.8 1101177.8 1096761.1 1,099,338.90 0 F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000 Moisture, % Fuel Type Coal - Bituminous Coal -

Bituminous Coal -

Bituminous Fw 10640 10640 10640 10,640.000 Fc 1800 1800 1800 1,800.000

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

Thursday, February 10, 2011 Page 4 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 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

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 10, 2011 Page 5 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 Emissions Summary

Process Run Data Location: Stack Exit - Method 10 Compound: Carbon Monoxide Average Run 4 5 6 lb/mmBtuO2 1.98E+00 1.35E+00 8.74E-01 1.401 ppm 1.60E+03 1.10E+03 7.05E+02 1,135.000 ppm@7%O2 1.84E+03 1.26E+03 8.18E+02 1,306.000

Location: Stack Exit - Method 25A Compound: Total organic compounds (TOC) as Average Run 1 2 3 lb/mmBtuO2 1.40E-04 0.00E+00 0.00E+00 0.000 ppm 7.44E-02 0.00E+00 0.00E+00 0.025 ppm@7%O2 8.34E-02 0.00E+00 0.00E+00 0.028

Thursday, February 10, 2011 Page 6 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 Process Run Data

Run Name Value UOM Comments Target Value 1 Coal Burned 0.1917 1000 Tons/hr 0 2 Coal Burned 0.1932 1000 Tons/hr 0 3 Coal Burned 0.1937 1000 Tons/hr 0 4 Coal Burned 0.1761 1000 Tons/hr 0 5 Coal Burned 0.1757 1000 Tons/hr 0 6 Coal Burned 0.1775 1000 Tons/hr 0 1 Average Heat Input 3466.5 MMBtu/hr 0 2 Average Heat Input 3495.3 MMBtu/hr 0 3 Average Heat Input 3503.3 MMBtu/hr 0 4 Average Heat Input 3300.2 MMBtu/hr 0 5 Average Heat Input 3291.5 MMBtu/hr 0 6 Average Heat Input 3326.0 MMBtu/hr 0 1 Flue Gas Flow Rate 1E+06 scfm 0 2 Flue Gas Flow Rate 1E+06 scfm 0 3 Flue Gas Flow Rate 1E+06 scfm 0 4 Flue Gas Flow Rate 1E+06 scfm 0 5 Flue Gas Flow Rate 1E+06 scfm 0 6 Flue Gas Flow Rate 1E+06 scfm 0 1 Flue Gas Carbon Dioxide Content 9.26 % wet 0 2 Flue Gas Carbon Dioxide Content 9.4 % Wet 0 3 Flue Gas Carbon Dioxide Content 9.52 % wet 0 4 Flue Gas Carbon Dioxide Content 9.2 % wet 0 5 Flue Gas Carbon Dioxide Content 9.17 % wet 0 6 Flue Gas Carbon Dioxide Content 9.3 % wet 0 1 Flue Gas Sampling Point Temperature 189.27 Deg F 0 2 Flue Gas Sampling Point Temperature 188.03 Deg F 0 3 Flue Gas Sampling Point Temperature 188.08 Deg F 0 4 Flue Gas Sampling Point Temperature 196.7 Deg F 0 5 Flue Gas Sampling Point Temperature 197.03 Deg F 0 6 Flue Gas Sampling Point Temperature 197.97 Deg F 0 1 Gross Electrical power generation 412 MW/hr 0 2 Gross Electrical power generation 412 MW/hr 0 3 Gross Electrical power generation 412 MW/hr 0

Thursday, February 10, 2011 Page 7 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010

APCD Run Data

Process Lab Run Data 4 Gross Electrical power generation 391 MW/hr 0 5 Gross Electrical power generation 391 MW/hr 0 6 Gross Electrical power generation 391 MW/hr 0

Run Name Value UOM Comments Target Value 1 DRY SCRUBBER 217.69 gal/min 0 2 DRY SCRUBBER 204.74 gal/min 0 3 DRY SCRUBBER 197.45 gal/min 0 4 DRY SCRUBBER 191.17 gal/min 0 5 DRY SCRUBBER 194.43 gal/min 0 6 DRY SCRUBBER 200.4 gal/min 0

Run Name Value UOM Comments 1 Fuel Higher Heating Value 9383 Btu/lb 2 Fuel Higher Heating Value 9383 Btu/lb 3 Fuel Higher Heating Value 9383 Btu/lb 4 Fuel Higher Heating Value 9383 Btu/lb 5 Fuel Higher Heating Value 9383 Btu/lb 6 Fuel Higher Heating Value 9383 Btu/lb 1 Fuel Moisture 18.25 % 2 Fuel Moisture 18.25 % 3 Fuel Moisture 18.25 % 4 Fuel Moisture 18.25 % 5 Fuel Moisture 18.25 % 6 Fuel Moisture 18.25 % 1 Fuel Mercury Content 0.13 ug/g 2 Fuel Mercury Content 0.13 ug/g 3 Fuel Mercury Content 0.13 ug/g 4 Fuel Mercury Content 0.13 ug/g 5 Fuel Mercury Content 0.13 ug/g 6 Fuel Mercury Content 0.13 ug/g 1 Fuel Cadmium Content 0.4 ug/g 2 Fuel Cadmium Content 0.4 ug/g 3 Fuel Cadmium Content 0.4 ug/g 4 Fuel Cadmium Content 0.4 ug/g 5 Fuel Cadmium Content 0.4 ug/g 6 Fuel Cadmium Content 0.4 ug/g 1 Ultimate/Proximate Analysis

Thursday, February 10, 2011 Page 8 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 2 Ultimate/Proximate Analysis 3 Ultimate/Proximate Analysis 4 Ultimate/Proximate Analysis 5 Ultimate/Proximate Analysis 6 Ultimate/Proximate Analysis 1 Fuel Nickel Content 5 ug/g 2 Fuel Nickel Content 5 ug/g 3 Fuel Nickel Content 5 ug/g 4 Fuel Nickel Content 5 ug/g 5 Fuel Nickel Content 5 ug/g 6 Fuel Nickel Content 5 ug/g 1 Fuel Arsenic Content 7 ug/g 2 Fuel Arsenic Content 7 ug/g 3 Fuel Arsenic Content 7 ug/g 4 Fuel Arsenic Content 7 ug/g 5 Fuel Arsenic Content 7 ug/g 6 Fuel Arsenic Content 7 ug/g 1 Fuel Chromium Content 8 ug/g 2 Fuel Chromium Content 8 ug/g 3 Fuel Chromium Content 8 ug/g 4 Fuel Chromium Content 8 ug/g 5 Fuel Chromium Content 8 ug/g 6 Fuel Chromium Content 8 ug/g 1 Fuel Beryllium Content 0.7 ug/g 2 Fuel Beryllium Content 0.7 ug/g 3 Fuel Beryllium Content 0.7 ug/g 4 Fuel Beryllium Content 0.7 ug/g 5 Fuel Beryllium Content 0.7 ug/g 6 Fuel Beryllium Content 0.7 ug/g 1 Fuel Lead Content 7 ug/g 2 Fuel Lead Content 7 ug/g 3 Fuel Lead Content 7 ug/g 4 Fuel Lead Content 7 ug/g 5 Fuel Lead Content 7 ug/g 6 Fuel Lead Content 7 ug/g 1 Fuel Manganese Content 71 ug/g 2 Fuel Manganese Content 71 ug/g 3 Fuel Manganese Content 71 ug/g 4 Fuel Manganese Content 71 ug/g 5 Fuel Manganese Content 71 ug/g 6 Fuel Manganese Content 71 ug/g 1 Fuel Chlorine Content, Dry 19 ug/g 2 Fuel Chlorine Content, Dry 19 ug/g

Thursday, February 10, 2011 Page 9 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 3 Fuel Chlorine Content, Dry 19 ug/g 4 Fuel Chlorine Content, Dry 19 ug/g 5 Fuel Chlorine Content, Dry 19 ug/g 6 Fuel Chlorine Content, Dry 19 ug/g 1 Fuel Fluorine Content, Dry 70 ug/g 2 Fuel Fluorine Content, Dry 70 ug/g 3 Fuel Fluorine Content, Dry 70 ug/g 4 Fuel Fluorine Content, Dry 70 ug/g 5 Fuel Fluorine Content, Dry 70 ug/g 6 Fuel Fluorine Content, Dry 70 ug/g 1 Fuel Selenium Content 2 ug/g 2 Fuel Selenium Content 2 ug/g 3 Fuel Selenium Content 2 ug/g 4 Fuel Selenium Content 2 ug/g 5 Fuel Selenium Content 2 ug/g 6 Fuel Selenium Content 2 ug/g 1 Fuel Antimony Content 2 ug/g 2 Fuel Antimony Content 2 ug/g 3 Fuel Antimony Content 2 ug/g 4 Fuel Antimony Content 2 ug/g 5 Fuel Antimony Content 2 ug/g 6 Fuel Antimony Content 2 ug/g 1 Fuel Cobalt Conntent 2 ug/g 2 Fuel Cobalt Conntent 2 ug/g 3 Fuel Cobalt Conntent 2 ug/g 4 Fuel Cobalt Conntent 2 ug/g 5 Fuel Cobalt Conntent 2 ug/g 6 Fuel Cobalt Conntent 2 ug/g 1 Fuel Ash Content 13.32 % 2 Fuel Ash Content 13.32 % 3 Fuel Ash Content 13.32 % 4 Fuel Ash Content 13.32 % 5 Fuel Ash Content 13.32 % 6 Fuel Ash Content 13.32 % 1 Fuel Sulphur Content 1.12 %

Thursday, February 10, 2011 Page 10 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 Sampling / Stack Data Results Detail
Location Stack Exit - Method 10 Average Run Number 4 5 6 Test Date 2/26/2010 2/26/2010 2/26/2010 Run Start Time 9:18:00 AM 12:43:00 PM 4:00:00 PM Run Finish Time 11:18:00 AM 2:43:00 PM 6:00:00 PM Carbon Dioxide, % 10.443 10.36 10.139 10.314 Oxygen, % 8.832 8.81 8.9216 8.855 Fuel Factor 1.16 1.17 1.18 Dry Volumetric Flow Rate, dry scfm 1100077.8 1101177.8 1096761.1 1,099,338.9 00 F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000 Moisture, % Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 2017 2017 2017 2,017.000 Operating Units ppm ppm ppm No. Readings/Avg. 4 4 4 4.000 Calibration Set 30 30 30 30.000 Calibration Pre Zero Cylinder ID Nitrogen Nitrogen Nitrogen Calibration Pre Zero Cylinder Instrument Response 0 6 2 2.667 Calibration Pre Zero Cylinder Bias 0 0.3 0.1 0.133 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC126112-CO CC126112- CO CC126112-

CO Calibration Pre High Cylinder Instrument Response 950.4 981.3 974 968.567 Calibration Pre High Cylinder Bias -0.06 1.47 1.11 0.840 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID Nitrogen Nitrogen Nitrogen Calibration Post Zero Cylinder Instrument Response 0.6 2 0.1 0.900 Calibration Post Zero Cylinder Bias 0.03 0.1 0 0.043 Calibration Post Zero Cylinder Drift 0.03 0.2 0.1 0.110 Calibration Post High Cylinder ID CC126112-CO CC126112- CO CC126112-

CO Calibration Post High Cylinder Instrument Response 981.3 974 960.8 972.033 Calibration Post High Cylinder Bias 1.47 1.11 0.45 1.010 Calibration Post High Cylinder Drift 1.53 0.36 0.66 0.850 Cavg 1581.7 1093.1 696.4 1,123.733 Cavg Units ppmvd ppmvd ppmvd Cgas 1604.4114 1095.7555 704.8842 1,135.017 Cgas Units ppmvd ppmvd ppmvd Fuel Type Coal - Bituminous Coal -

Bituminous Coal -

Bituminous Fw 10640 10640 10640 10,640.000 Fc 1800 1800 1800 1,800.000 Cgasw 0 0 0 0.000 Cgasw Units

Thursday, February 10, 2011 Page 11 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 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 10, 2011 Page 12 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 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 10, 2011 Page 13 of 14Information Collection Request, TEP - Springerville Generation Station Unit 2
8/11/2010 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 10, 2011 Page 14 of 14