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 3 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 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 Facility Information: Springerville Generating Station Off Route 191 approx 15 Miles NE of city P.O. Box 2222 Springerville AZ85938 Contact:Amy Pulsifer Phone: 928 337 7429 Fax: Email: Testing Company: CCI Environmental Consultants, Inc. 3855 South 500 West, Suite I

Salt Lake City UT84115 Contact:Larry Cottone Phone:801.269.0550 Fax: Email:

Air Permit Number: 32008 Permitted Source ID/Name: Unit 3 Boiler 3 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, 3 and 4. Unit 3 is rated at 420 megawatts net. Unit 3 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 3 to satisfy Part 60 and 75 requirements. B). Control Equipment Description NOx is controlled by Selective Catalytic Reduction (SCR) that uses ammonia injection technology. Sulfur dioxide emissions are controlled by a dry scrubber. The dry scrubber is followed by a bag house to remove particulate matter. Industry/SCC/NAIS221112

Sampling Location Information:

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

SCC / Description10100202 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

Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location Thursday, February 10, 2011 Page 2 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 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 Custom Method 18 3 120 0 Methane (CH4) Stack Exit Total organic compounds

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

Total PM2.5 OTM - 27/28 3 480 0 Stack Exit Inorganic (Aqueous)

Condensible Part. OTM - 27/28 3 480 0 Stack Exit Organic Condensible

Particulate OTM - 27/28 3 480 0 Stack Exit

Filterable Particulate OTM - 27/28 3 480 0 Stack Exit Filterable PM2.5 OTM - 27/28 3 480 0 Stack Exit Cadmium Method 29 3 480 0 Stack Exit Selenium Method 29 3 480 0 Stack Exit Nickel Method 29 3 480 0 Stack Exit Manganese Method 29 3 480 0 Stack Exit Lead Method 29 3 480 0 Stack Exit Antimony Method 29 3 480 0 Stack Exit Arsenic Method 29 3 480 0 Stack Exit Cobalt Method 29 3 480 0 Stack Exit Beryllium Method 29 3 480 0 Stack Exit Filterable Particulate Method 29 3 480 0 Stack Exit Chromium Method 29 3 480 0 Stack Exit Organic Condensible

Particulate Method 5/OTM-28 3 240 0 Stack Exit

Total Particulate Method 5/OTM-28 3 240 0 Stack Exit Filterable Particulate Method 5/OTM-28 3 240 0 Stack Exit Inorganic (Aqueous)

Condensible Part. Method 5/OTM-28 3 240 0 Stack Exit

Thursday, February 10, 2011 Page 3 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 Sampling / Stack Data Results Summary 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 29 Average Run Number 2 3 4 Test Date 2/25/2010 2/26/2010 2/26/2010 Run Start Time 1:10:00 PM 7:45:00 AM 1:28:00 PM

Run Finish Time 6:00:00 PM 12:17:00 PM 5:28:00 PM

Net Run Time, minutes 240 240 240 Dry Gas Meter Volume Sampled, dscf 138.335 134.273 133.974 135.527 Moisture Content of Stack Gas, % 13.34 14.36 14.35 14.017 Moisture Saturation at Stack Gas Temperature, % 95.34 95.17 96.30 95.603 Carbon Dioxide, % 14 14.1 14.2 14.100 Oxygen, % 5.5 5.4 5.3 5.400 Average Stack Gas Temperature, °F 196.98 196.83 197.46 197.090 Dry Volumetric Flow Rate, dry scfm 940,991.6 909,617.4 908,233.2 919,614.067 Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,750,745.31,714,365.7 1,710,972.7 1,725,361.23 3 Percent Isokinetic of Sampling Rate, % 100.9 101.3 101.2 101.133 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

Thursday, February 10, 2011 Page 4 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 Location Stack Exit - OTM - 27/28 Average Run Number Test Date Run Start Time Run Finish Time Net Run Time, minutes Dry Gas Meter Volume Sampled, dscf Moisture Content of Stack Gas, % Moisture Saturation at Stack Gas Temperature, % Carbon Dioxide, % Oxygen, % Average Stack Gas Temperature, °F Dry Volumetric Flow Rate, dry scfm Actual Wet Volumetric Flue Gas Flow Rate, acfm Percent Isokinetic of Sampling Rate, % F-Factor, dscfm/MMBtu @ %O2 Fw Fc

Thursday, February 10, 2011 Page 5 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 Emissions Summary Location: Stack Exit - Method 25A Compound: Total organic compounds (TOC) as Average Run 1 2 3 lb/mmBtuO2 5.16E-05 0.00E+00 9.06E-06 0.000 ppm 3.46E-02 0.00E+00 6.00E-03 0.014 ppm@7%O2 3.06E-02 0.00E+00 5.38E-03 0.012

Location: Stack Exit - Method 29 Compound: Antimony Average RunNumber 2 3 4 Mass_mg 0.00175 0.00175 0.00175 0.002 lb/mmBtuO2 3.70E-07 3.79E-07 3.77E-07 0.000 Compound: Arsenic Average RunNumber 2 3 4 Mass_mg 0.0035 0.0035 0.0035 0.004 lb/mmBtuO2 7.40E-07 7.58E-07 7.55E-07 0.000 Compound: Beryllium Average RunNumber 2 3 4 Mass_mg 0.00003 0.00003 0.00003 0.000 lb/mmBtuO2 6.35E-09 6.50E-09 6.47E-09 0.000 Compound: Cadmium Average RunNumber 2 3 4 Mass_mg 0.00045 0.00043 0.00022 0.000 lb/mmBtuO2 9.52E-08 9.31E-08 4.74E-08 0.000 Compound: Chromium Average RunNumber 2 3 4 Mass_mg 0.0027 0.00267 0.00225 0.003 lb/mmBtuO2 5.71E-07 5.78E-07 4.85E-07 0.000 Compound: Cobalt Average RunNumber 2 3 4 Mass_mg 0.00024 0.00034 0.00025 0.000 lb/mmBtuO2 5.08E-08 7.36E-08 5.39E-08 0.000 Compound: Filterable Particulate Average RunNumber 2 3 4 Mass_mg 3.2 2.4 2.6 2.733 lb/mmBtuO2 6.77E-04 5.20E-04 5.61E-04 0.001

Thursday, February 10, 2011 Page 6 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 Compound: Lead Average RunNumber 2 3 4 Mass_mg 0.00175 0.00175 0.00189 0.002 lb/mmBtuO2 3.70E-07 3.79E-07 4.08E-07 0.000 Compound: Manganese Average RunNumber 2 3 4 Mass_mg 0.00257 0.0376 0.00203 0.014 lb/mmBtuO2 5.44E-07 8.14E-06 4.38E-07 0.000 Compound: Nickel Average RunNumber 2 3 4 Mass_mg 0.00832 0.00725 0.00697 0.008 lb/mmBtuO2 1.76E-06 1.57E-06 1.50E-06 0.000 Compound: Selenium Average RunNumber 2 3 4 Mass_mg 0.0035 0.0035 0.0035 0.004 lb/mmBtuO2 7.40E-07 7.58E-07 7.55E-07 0.000

Location: Stack Exit - OTM - 27/28 Compound: Filterable Particulate Average RunNumber 1 2 3 Mass_mg 3 3.4 1.9 2.767 lb/mmBtuO2 6.58E-04 6.93E-04 3.85E-04 0.001 Compound: Filterable PM2.5 Average RunNumber 1 2 3 Mass_mg 1 2 0.1 1.033 lb/mmBtuO2 2.19E-04 4.08E-04 2.03E-05 0.000 Compound: Inorganic (Aqueous) Condensible Pa Average RunNumber 1 2 3 Mass_mg 164.3 200.8 11 125.367 lb/mmBtuO2 3.60E-02 4.09E-02 2.23E-03 0.026 Compound: Organic Condensible Particulate Average RunNumber 1 2 3 Mass_mg 4.3 3.7 4.4 4.133 lb/mmBtuO2 9.43E-04 7.54E-04 8.92E-04 0.001 Compound: Total PM2.5 Average RunNumber 1 2 3 Mass_mg 169.63 206.5 17.3 131.143 Thursday, February 10, 2011 Page 7 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010

Process Run Data lb/mmBtuO2 3.72E-02 4.21E-02 3.51E-03 0.028

Thursday, February 10, 2011 Page 8 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 Process Run Data

Run Name Value UOM Comments Target Value 1 Coal Burned 0.224 1000 Tons/hr Facility DMS 0 10 Coal Burned 0.223 1000 Tons/hr Facility DMS 0 11 Coal Burned 0.226 1000 Tons/hr Facility DMS 0 12 Coal Burned 0.226 1000 Tons/hr Facility DMS 0 13 Coal Burned 0.223 1000 Tons/hr Facility DMS 0 14 Coal Burned 0.217 1000 Tons/hr Facility DMS 0 15 Coal Burned 0.221 1000 Tons/hr Facility DMS 0 2 Coal Burned 0.223 1000 Tons/hr Facility DMS 0 3 Coal Burned 0.224 1000 Tons/hr Facility DMS 0 4 Coal Burned 0.22 1000 Tons/hr Facility DMS 0 5 Coal Burned 0.224 1000 Tons/hr Facility DMS 0 6 Coal Burned 0.225 1000 Tons/hr Facility DMS 0 7 Coal Burned 0.224 1000 Tons/hr Facility DMS 0 8 Coal Burned 0.225 1000 Tons/hr Facility DMS 0 9 Coal Burned 0.225 1000 Tons/hr Facility DMS 0 1 Average Heat Input 3789.6 MMBtu/hr Facility DMS 0 10Average Heat Input 3757.5 MMBtu/hr Facility DMS 0 11 Average Heat Input 3776.9 MMBtu/hr Facility DMS 0 12Average Heat Input 3776.9 MMBtu/hr Facility DMS 0 13 Average Heat Input 3914.8 MMBtu/hr Facility DMS 0 14 Average Heat Input 3796.4 MMBtu/hr Facility DMS 0 15 Average Heat Input 3834.2 MMBtu/hr Facility DMS 0 2 Average Heat Input 3807.2 MMBtu/hr Facility DMS 0 3 Average Heat Input 3837.9 MMBtu/hr Facility DMS 0 4 Average Heat Input 3804.9 MMBtu/hr Facility DMS 0 5 Average Heat Input 3859.9 MMBtu/hr Facility DMS 0 6 Average Heat Input 3841 MMBtu/hr Facility DMS 0 7 Average Heat Input 3857.4 MMBtu/hr Facility DMS 0 8 Average Heat Input 3847 MMBtu/hr Facility DMS 0 9 Average Heat Input 3822.5 MMBtu/hr Facility DMS 0 1 Flue Gas Flow Rate 832390 dscfm Facility DMS, Dry 0 10Flue Gas Flow Rate 824382 dscfm Facility DMS, Dry 0 11 Flue Gas Flow Rate 829622 dscfm Facility DMS, Dry 0

Thursday, February 10, 2011 Page 9 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 12Flue Gas Flow Rate 822115 dscfm Facility DMS 0 13 Flue Gas Flow Rate 845461 dscfm Facility DMS 0 14Flue Gas Flow Rate 828792 dscfm Facility DMS 0 15 Flue Gas Flow Rate 838968 dscfm Facility DMS 0 2 Flue Gas Flow Rate 835474 dscfm Facility DMS, Dry 0 3 Flue Gas Flow Rate 829242 dscfm Facility DMS, Dry 0 4 Flue Gas Flow Rate 826545 dscfm Facility DMS, Dry 0 5 Flue Gas Flow Rate 828449 dscfm Facility DMS, Dry 0 6 Flue Gas Flow Rate 830827 dscfm Facility DMS, Dry 0 7 Flue Gas Flow Rate 829805 dscfm Facility DMS, Dry 0 8 Flue Gas Flow Rate 829503 dscfm Facility DMS, Dry 0 9 Flue Gas Flow Rate 834323 dscfm Facility DMS, Dry 0 1 Flue Gas Oxygen Content 5.6 % Unit 3 CEMS, Dry 0 10Flue Gas Oxygen Content 5.5 % Unit 3 CEMS, Dry 0 11 Flue Gas Oxygen Content 5.6 % Unit 3 CEMS, Dry 0 12Flue Gas Oxygen Content 5.6 % Unit 3 CEMS, Dry 0 13 Flue Gas Oxygen Content 5.79 % Unit 3 CEMS, Dry 0 14Flue Gas Oxygen Content 5.96 % Unit 3 CEMS, Dry 0 15 Flue Gas Oxygen Content 5.97 % Unit 3 CEMS, Dry 0 2 Flue Gas Oxygen Content 5.6 % Unit 3 CEMS, Dry 0 3 Flue Gas Oxygen Content 5.3 % Unit 3 CEMS, Dry 0 4 Flue Gas Oxygen Content 5.5 % Unit 3 CEMS, Dry 0 5 Flue Gas Oxygen Content 5.4 % Unit 3 CEMS, Dry 0 6 Flue Gas Oxygen Content 5.3 % Unit 3 CEMS, Dry 0 7 Flue Gas Oxygen Content 5.2 % Unit 3 CEMS, Dry 0 8 Flue Gas Oxygen Content 5.3 % Unit 3 CEMS, Dry 0 9 Flue Gas Oxygen Content 5.4 % Unit 3 CEMS, Dry 0 1 Flue Gas Carbon Dioxide Content 14 % Unit 3 CEMS, Dry 0 10Flue Gas Carbon Dioxide Content 14 % Unit 3 CEMS, Dry 0 11 Flue Gas Carbon Dioxide Content 14 % Unit 3 CEMS, Dry 0 12Flue Gas Carbon Dioxide Content 14 % Unit 3 CEMS, Dry 0 13 Flue Gas Carbon Dioxide Content 13.76 % Unit 3 CEMS, Dry 0 14Flue Gas Carbon Dioxide Content 13.61 % Unit 3 CEMS, Dry 0 15 Flue Gas Carbon Dioxide Content 13.58 % Unit 3 CEMS, Dry 0 2 Flue Gas Carbon Dioxide Content 14 % Unit 3 CEMS, Dry 0 3 Flue Gas Carbon Dioxide Content 14.2 % Unit 3 CEMS, Dry 0

Thursday, February 10, 2011 Page 10 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 4 Flue Gas Carbon Dioxide Content 14 % Unit 3 CEMS, Dry 0 5 Flue Gas Carbon Dioxide Content 14.1 % Unit 3 CEMS, Dry 0 6 Flue Gas Carbon Dioxide Content 14.2 % Unit 3 CEMS, Dry 0 7 Flue Gas Carbon Dioxide Content 14.3 % Unit 3 CEMS, Dry 0 8 Flue Gas Carbon Dioxide Content 14.2 % Unit 3 CEMS, Dry 0 9 Flue Gas Carbon Dioxide Content 14.1 % Unit 3 CEMS, Dry 0 1 Flue Gas Moisture Content 14.5 % Unit 3 CEMS 0 10Flue Gas Moisture Content 14.7 % Unit 3 CEMS 0 11 Flue Gas Moisture Content 15.3 % Unit 3 CEMS 0 12Flue Gas Moisture Content 15.3 % Unit 3 CEMS 0 13 Flue Gas Moisture Content 14.83 % Unit 3 CEMS 0 14Flue Gas Moisture Content 15.05 % Unit 3 CEMS 0 15 Flue Gas Moisture Content 15.19 % Unit 3 CEMS 0 2 Flue Gas Moisture Content 14.6 % Unit 3 CEMS 0 3 Flue Gas Moisture Content 14.8 % Unit 3 CEMS 0 4 Flue Gas Moisture Content 14.6 % Unit 3 CEMS 0 5 Flue Gas Moisture Content 14.7 % Unit 3 CEMS 0 6 Flue Gas Moisture Content 14.7 % Unit 3 CEMS 0 7 Flue Gas Moisture Content 14.8 % Unit 3 CEMS 0 8 Flue Gas Moisture Content 14.9 % Unit 3 CEMS 0 9 Flue Gas Moisture Content 14.5 % Unit 3 CEMS 0 1 Flue Gas Sampling Point Temperature 201.41 Deg F Facility DMS 0 10Flue Gas Sampling Point Temperature 201.2 Deg F Facility DMS 0 11 Flue Gas Sampling Point Temperature 202.7 Deg F Facility DMS 0 12Flue Gas Sampling Point Temperature 202.7 Deg F Facility DMS 0 13 Flue Gas Sampling Point Temperature 205.93 Deg F Facility DMS 0 14Flue Gas Sampling Point Temperature 207.36 Deg F Facility DMS 0 15 Flue Gas Sampling Point Temperature 207.31 Deg F Facility DMS 0 2 Flue Gas Sampling Point Temperature 201.33 Deg F Facility DMS 0 3 Flue Gas Sampling Point Temperature 200.56 Deg F Facility DMS 0 4 Flue Gas Sampling Point Temperature 201.37 Deg F Facility DMS 0 5 Flue Gas Sampling Point Temperature 200.21 Deg F Facility DMS 0 6 Flue Gas Sampling Point Temperature 200.7 Deg F Facility DMS 0 7 Flue Gas Sampling Point Temperature 201.2 Deg F Facility DMS 0 8 Flue Gas Sampling Point Temperature 200.87 Deg F Facility DMS 0 9 Flue Gas Sampling Point Temperature 200.53 Deg F Facility DMS 0

Thursday, February 10, 2011 Page 11 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010

APCD Run Data 1 Unit Gross Electrical Output 436.01 Mwe Facility DMS 0 10Unit Gross Electrical Output 436 Mwe Facility DMS 0 11 Unit Gross Electrical Output 436 Mwe Facility DMS 0 12Unit Gross Electrical Output 436 Mwe Facility DMS 0 13 Unit Gross Electrical Output 430.65 Mwe Facility DMS 0 14 Unit Gross Electrical Output 414.33 Mwe Facility DMS 0 15 Unit Gross Electrical Output 423.52 Mwe Facility DMS 0 2 Unit Gross Electrical Output 435.7 Mwe Facility DMS 0 3 Unit Gross Electrical Output 436.52 Mwe Facility DMS 0 4 Unit Gross Electrical Output 431.99 Mwe Facility DMS 0 5 Unit Gross Electrical Output 437.57 Mwe Facility DMS 0 6 Unit Gross Electrical Output 435.98 Mwe Facility DMS 0 7 Unit Gross Electrical Output 436 Mwe Facility DMS 0 8 Unit Gross Electrical Output 435.97 Mwe Facility DMS 0 9 Unit Gross Electrical Output 436 Mwe Facility DMS 0

Run Name Value UOM Comments Target Value 1 DRY SCRUBBER 88.74 gal/min. 10 DRY SCRUBBER 72.98 gal/min. 11 DRY SCRUBBER 73.49 gal/min. 12DRY SCRUBBER 74.16 gal/min. 13 DRY SCRUBBER 81.68 gal/min. 14 DRY SCRUBBER 82.82 gal/min. 15 DRY SCRUBBER 79.7 gal/min. 2 DRY SCRUBBER 81.62 gal/min. 3 DRY SCRUBBER 73.58 gal/min. 4 DRY SCRUBBER 83.77 gal/min. 5 DRY SCRUBBER 84.15 gal/min. 6 DRY SCRUBBER 73.63 gal/min. 7 DRY SCRUBBER 95.98 gal/min. 8 DRY SCRUBBER 99.49 gal/min. 9 DRY SCRUBBER 99.94 gal/min. 1 SCR Amonia Injection Rate 278.78 lbs/hr 10 SCR Amonia Injection Rate 284.4 lbs/hr 11 SCR Amonia Injection Rate 284.4 lbs/hr

Thursday, February 10, 2011 Page 12 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010

Process Lab Run Data 12 SCR Amonia Injection Rate 282.54 lbs/hr 13 SCR Amonia Injection Rate 208.44 lbs/hr 14 SCR Amonia Injection Rate 190.46 lbs/hr 15 SCR Amonia Injection Rate 208.59 lbs/hr 2 SCR Amonia Injection Rate 280.57 lbs/hr 3 SCR Amonia Injection Rate 284.16 lbs/hr 4 SCR Amonia Injection Rate 278.16 lbs/hr 5 SCR Amonia Injection Rate 284.4 lbs/hr 6 SCR Amonia Injection Rate 280.57 lbs/hr 7 SCR Amonia Injection Rate 284.2 lbs/hr 8 SCR Amonia Injection Rate 284.2 lbs/hr 9 SCR Amonia Injection Rate 284.2 lbs/hr 1 SCR Amonia Dilution Ration 13.65 lbs-hr/lbs--hr 10 SCR Amonia Dilution Ration 13.33 lbs-hr/lbs--hr 11 SCR Amonia Dilution Ration 13.33 lbs-hr/lbs--hr 12 SCR Amonia Dilution Ration 13.41 lbs-hr/lbs--hr 13 SCR Amonia Dilution Ration 15.46 lbs-hr/lbs--hr 14 SCR Amonia Dilution Ration 17.19 lbs-hr/lbs--hr 15 SCR Amonia Dilution Ration 15.63 lbs-hr/lbs--hr 2 SCR Amonia Dilution Ration 13.52 lbs-hr/lbs--hr 3 SCR Amonia Dilution Ration 13.34 lbs-hr/lbs--hr 4 SCR Amonia Dilution Ration 13.69 lbs-hr/lbs--hr 5 SCR Amonia Dilution Ration 13.33 lbs-hr/lbs--hr 6 SCR Amonia Dilution Ration 13.52 lbs-hr/lbs--hr 7 SCR Amonia Dilution Ration 13.34 lbs-hr/lbs--hr 8 SCR Amonia Dilution Ration 13.34 lbs-hr/lbs--hr 9 SCR Amonia Dilution Ration 13.34 lbs-hr/lbs--hr

Run Name Value UOM Comments 1 Fuel Higher Heating Value 8849 Btu/lb 10Fuel Higher Heating Value 8753 Btu/lb 11 Fuel Higher Heating Value 8753 Btu/lb 12Fuel Higher Heating Value 8753 Btu/lb 13 Fuel Higher Heating Value 8743 Btu/lb 14Fuel Higher Heating Value 8743 Btu/lb 15 Fuel Higher Heating Value 8743 Btu/lb

Thursday, February 10, 2011 Page 13 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 2 Fuel Higher Heating Value 8843 Btu/lb 3 Fuel Higher Heating Value 8845 Btu/lb 4 Fuel Higher Heating Value 8843 Btu/lb 5 Fuel Higher Heating Value 8845 Btu/lb 6 Fuel Higher Heating Value 8845 Btu/lb 7 Fuel Higher Heating Value 8845 Btu/lb 8 Fuel Higher Heating Value 8845 Btu/lb 9 Fuel Higher Heating Value 8845 Btu/lb 1 Fuel Moisture 26.85 % 10Fuel Moisture 26.57 % 11 Fuel Moisture 26.57 % 12Fuel Moisture 26.57 % 13 Fuel Moisture 27.56 % 14Fuel Moisture 27.56 % 15 Fuel Moisture 27.56 % 2 Fuel Moisture 27.05 % 3 Fuel Moisture 26.42 % 4 Fuel Moisture 27.05 % 5 Fuel Moisture 26.42 % 6 Fuel Moisture 26.42 % 7 Fuel Moisture 26.42 % 8 Fuel Moisture 26.42 % 9 Fuel Moisture 26.42 % 1 Fuel Mercury Content 0.05 ug/g 10Fuel Mercury Content 0.05 ug/g 11 Fuel Mercury Content 0.05 ug/g 12Fuel Mercury Content 0.05 ug/g 13 Fuel Mercury Content 0.068 ug/g 14Fuel Mercury Content 0.068 ug/g 15 Fuel Mercury Content 0.068 ug/g 2 Fuel Mercury Content 0.05 ug/g 3 Fuel Mercury Content 0.05 ug/g 4 Fuel Mercury Content 0.05 ug/g 5 Fuel Mercury Content 0.05 ug/g 6 Fuel Mercury Content 0.05 ug/g 7 Fuel Mercury Content 0.05 ug/g 8 Fuel Mercury Content 0.05 ug/g 9 Fuel Mercury Content 0.05 ug/g 1 Fuel Cadmium Content 0.2 ug/g 10Fuel Cadmium Content 0.2 ug/g 11 Fuel Cadmium Content 0.2 ug/g 12Fuel Cadmium Content 0.2 ug/g 13 Fuel Cadmium Content 0.02 ug/g

Thursday, February 10, 2011 Page 14 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 14Fuel Cadmium Content 0.02 ug/g 15 Fuel Cadmium Content 0.02 ug/g 2 Fuel Cadmium Content 0.02 ug/g 3 Fuel Cadmium Content 0.2 ug/g 4 Fuel Cadmium Content 0.02 ug/g 5 Fuel Cadmium Content 0.2 ug/g 6 Fuel Cadmium Content 0.2 ug/g 7 Fuel Cadmium Content 0.2 ug/g 8 Fuel Cadmium Content 0.2 ug/g 9 Fuel Cadmium Content 0.2 ug/g 1 Ultimate/Proximate Analysis 10Ultimate/Proximate Analysis 11 Ultimate/Proximate Analysis 12Ultimate/Proximate Analysis 13 Ultimate/Proximate Analysis 14Ultimate/Proximate Analysis 15 Ultimate/Proximate Analysis 2 Ultimate/Proximate Analysis 3 Ultimate/Proximate Analysis 4 Ultimate/Proximate Analysis 5 Ultimate/Proximate Analysis 6 Ultimate/Proximate Analysis 7 Ultimate/Proximate Analysis 8 Ultimate/Proximate Analysis 9 Ultimate/Proximate Analysis 1 Fuel Nickel Content 3 ug/g 10Fuel Nickel Content 6 ug/g 11 Fuel Nickel Content 6 ug/g 12Fuel Nickel Content 6 ug/g 13 Fuel Nickel Content 4 ug/g 14Fuel Nickel Content 4 ug/g 15 Fuel Nickel Content 4 ug/g 2 Fuel Nickel Content 3 ug/g 3 Fuel Nickel Content 4 ug/g 4 Fuel Nickel Content 3 ug/g 5 Fuel Nickel Content 4 ug/g 6 Fuel Nickel Content 4 ug/g 7 Fuel Nickel Content 4 ug/g 8 Fuel Nickel Content 4 ug/g 9 Fuel Nickel Content 4 ug/g 1 Fuel Arsenic Content 1 ug/g 10Fuel Arsenic Content 1 ug/g 11 Fuel Arsenic Content 1 ug/g

Thursday, February 10, 2011 Page 15 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 12Fuel Arsenic Content 1 ug/g 13 Fuel Arsenic Content 1 ug/g 14Fuel Arsenic Content 1 ug/g 15 Fuel Arsenic Content 1 ug/g 2 Fuel Arsenic Content 1 ug/g 3 Fuel Arsenic Content 1 ug/g 4 Fuel Arsenic Content 1 ug/g 5 Fuel Arsenic Content 1 ug/g 6 Fuel Arsenic Content 1 ug/g 7 Fuel Arsenic Content 1 ug/g 8 Fuel Arsenic Content 1 ug/g 9 Fuel Arsenic Content 1 ug/g 1 Fuel Chromium Content 4 ug/g 10Fuel Chromium Content 5 ug/g 11 Fuel Chromium Content 5 ug/g 12Fuel Chromium Content 5 ug/g 13 Fuel Chromium Content 3.8 ug/g 14Fuel Chromium Content 3.8 ug/g 15 Fuel Chromium Content 3.8 ug/g 2 Fuel Chromium Content 4 ug/g 3 Fuel Chromium Content 5 ug/g 4 Fuel Chromium Content 4 ug/g 5 Fuel Chromium Content 5 ug/g 6 Fuel Chromium Content 5 ug/g 7 Fuel Chromium Content 5 ug/g 8 Fuel Chromium Content 5 ug/g 9 Fuel Chromium Content 5 ug/g 1 Fuel Beryllium Content 0.2 ug/g 10Fuel Beryllium Content 0.4 ug/g 11 Fuel Beryllium Content 0.4 ug/g 12Fuel Beryllium Content 0.4 ug/g 13 Fuel Beryllium Content 0.2 ug/g 14Fuel Beryllium Content 0.2 ug/g 15 Fuel Beryllium Content 0.2 ug/g 2 Fuel Beryllium Content 0.2 ug/g 3 Fuel Beryllium Content 0.3 ug/g 4 Fuel Beryllium Content 0.2 ug/g 5 Fuel Beryllium Content 0.3 ug/g 6 Fuel Beryllium Content 0.3 ug/g 7 Fuel Beryllium Content 0.3 ug/g 8 Fuel Beryllium Content 0.3 ug/g 9 Fuel Beryllium Content 0.3 ug/g 1 Fuel Lead Content 0 ug/g

Thursday, February 10, 2011 Page 16 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 10Fuel Lead Content 2 ug/g 11 Fuel Lead Content 2 ug/g 12Fuel Lead Content 2 ug/g 13 Fuel Lead Content 2 ug/g 14Fuel Lead Content 2 ug/g 15 Fuel Lead Content 2 ug/g 2 Fuel Lead Content 2 ug/g 3 Fuel Lead Content 2 ug/g 4 Fuel Lead Content 2 ug/g 5 Fuel Lead Content 2 ug/g 6 Fuel Lead Content 2 ug/g 7 Fuel Lead Content 2 ug/g 8 Fuel Lead Content 2 ug/g 9 Fuel Lead Content 2 ug/g 1 Fuel Manganese Content 10 ug/g 10Fuel Manganese Content 12 ug/g 11 Fuel Manganese Content 12 ug/g 12Fuel Manganese Content 12 ug/g 13 Fuel Manganese Content 7 ug/g 14Fuel Manganese Content 7 ug/g 15 Fuel Manganese Content 7 ug/g 2 Fuel Manganese Content 8 ug/g 3 Fuel Manganese Content 9 ug/g 4 Fuel Manganese Content 8 ug/g 5 Fuel Manganese Content 9 ug/g 6 Fuel Manganese Content 9 ug/g 7 Fuel Manganese Content 9 ug/g 8 Fuel Manganese Content 9 ug/g 9 Fuel Manganese Content 9 ug/g 1 Fuel Chlorine Content 14 ug/g 10Fuel Chlorine Content 27 ug/g 11 Fuel Chlorine Content 27 ug/g 12Fuel Chlorine Content 27 ug/g 13 Fuel Chlorine Content 12 ug/g 14Fuel Chlorine Content 12 ug/g 15 Fuel Chlorine Content 12 ug/g 2 Fuel Chlorine Content 10 ug/g 3 Fuel Chlorine Content 10 ug/g 4 Fuel Chlorine Content 10 ug/g 5 Fuel Chlorine Content 10 ug/g 6 Fuel Chlorine Content 10 ug/g 7 Fuel Chlorine Content 10 ug/g 8 Fuel Chlorine Content 10 ug/g

Thursday, February 10, 2011 Page 17 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 9 Fuel Chlorine Content 10 ug/g 1 Fuel Fluorine Content 60 ug/g 10Fuel Fluorine Content 59 ug/g 11 Fuel Fluorine Content 59 ug/g 12Fuel Fluorine Content 59 ug/g 13 Fuel Fluorine Content 62.8 ug/g 14Fuel Fluorine Content 62.8 ug/g 15 Fuel Fluorine Content 62.8 ug/g 2 Fuel Fluorine Content 66 ug/g 3 Fuel Fluorine Content 69 ug/g 4 Fuel Fluorine Content 66 ug/g 5 Fuel Fluorine Content 69 ug/g 6 Fuel Fluorine Content 69 ug/g 7 Fuel Fluorine Content 69 ug/g 8 Fuel Fluorine Content 69 ug/g 9 Fuel Fluorine Content 69 ug/g 1 Fuel Antimony 1 ug/g 10Fuel Antimony 1 ug/g 11 Fuel Antimony 1 ug/g 12Fuel Antimony 1 ug/g 13 Fuel Antimony 1 ug/g 14Fuel Antimony 1 ug/g 15 Fuel Antimony 1 ug/g 2 Fuel Antimony 1 ug/g 3 Fuel Antimony 1 ug/g 4 Fuel Antimony 1 ug/g 5 Fuel Antimony 1 ug/g 6 Fuel Antimony 1 ug/g 7 Fuel Antimony 1 ug/g 8 Fuel Antimony 1 ug/g 9 Fuel Antimony 1 ug/g 1 Fuel Ash 12.3 % 10Fuel Ash 5.7 % 11 Fuel Ash 5.7 % 12Fuel Ash 5.7 % 13 Fuel Ash 4.574 % 14Fuel Ash 4.574 % 15 Fuel Ash 4.574 % 2 Fuel Ash 12.94 % 3 Fuel Ash 11.45 % 4 Fuel Ash 12.94 % 5 Fuel Ash 11.45 % 6 Fuel Ash 11.45 %

Thursday, February 10, 2011 Page 18 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 7 Fuel Ash 11.45 % 8 Fuel Ash 11.45 % 9 Fuel Ash 11.45 % 1 Fuel Sulfur 0.17 % 10Fuel Sulfur 0.24 % 11 Fuel Sulfur 0.24 % 12Fuel Sulfur 0.24 % 13 Fuel Sulfur 0.168 % 14Fuel Sulfur 0.168 % 15 Fuel Sulfur 0.168 % 2 Fuel Sulfur 0.18 % 3 Fuel Sulfur 0.2 % 4 Fuel Sulfur 0.18 % 5 Fuel Sulfur 0.2 % 6 Fuel Sulfur 0.2 % 7 Fuel Sulfur 0.2 % 8 Fuel Sulfur 0.2 % 9 Fuel Sulfur 0.2 % 1 Fuel Cobalt 1 ug/g 10Fuel Cobalt 3 ug/g 11 Fuel Cobalt 3 ug/g 12Fuel Cobalt 3 ug/g 13 Fuel Cobalt 2 ug/g 14Fuel Cobalt 2 ug/g 15 Fuel Cobalt 2 ug/g 2 Fuel Cobalt 1 ug/g 3 Fuel Cobalt 2 ug/g 4 Fuel Cobalt 1 ug/g 5 Fuel Cobalt 2 ug/g 6 Fuel Cobalt 2 ug/g 7 Fuel Cobalt 2 ug/g 8 Fuel Cobalt 2 ug/g 9 Fuel Cobalt 2 ug/g 1 Fuel Selenium Content 1 ug/g 10Fuel Selenium Content 1 ug/g 11 Fuel Selenium Content 1 ug/g 12Fuel Selenium Content 1 ug/g 13 Fuel Selenium Content 1 ug/g 14Fuel Selenium Content 1 ug/g 15 Fuel Selenium Content 1 ug/g 2 Fuel Selenium Content 1 ug/g 3 Fuel Selenium Content 1 ug/g 4 Fuel Selenium Content 1 ug/g

Thursday, February 10, 2011 Page 19 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 5 Fuel Selenium Content 1 ug/g 6 Fuel Selenium Content 1 ug/g 7 Fuel Selenium Content 1 ug/g 8 Fuel Selenium Content 1 ug/g 9 Fuel Selenium Content 1 ug/g

Thursday, February 10, 2011 Page 20 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 Sampling / Stack Data Results Detail 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 21 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 Location Stack Exit - Method 29 Average Run Number 2 3 4 Test Date 2/25/2010 2/26/2010 2/26/2010 Run Start Time 1:10:00 PM7:45:00 AM 1:28:00 PM Run Finish Time 6:00:00 PM12:17:00 PM 5:28:00 PM Net Traversing Points 50 52 28 Net Run Time, minutes 240 240 240 Nozzle Diameter, inches 0.187 0.187 0.187 0.187 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 0.962 0.962 0.962 0.962 Barometric Pressure, inches of Mercury 23.21 23.18 23.21 23.200 Average Orifice Meter Differential, inches H2O 1.35 1.25 1.25 1.283 Dry Gas Meter Volume Sampled, cubic feet 183.188 176.418 178.389 179.332 Average Dry Gas Meter Temperature, °F 64.01 59.08 66.73 63.273 Dry Gas Meter Volume Sampled, dscf 138.335 134.273 133.974 135.527 Total Moisture Liquid collected, g 452.3 478.5 477 469.267 Volume of Water Vapor, standard cubic feet 21.29 22.52 22.45 22.087 Moisture Content of Stack Gas, % 13.34 14.36 14.35 14.017 Moisture Saturation at Stack Gas Temperature, % 95.34 95.17 96.30 95.603 Dry Mole Fraction 0.8666 0.8564 0.8565 0.860 Carbon Dioxide, % 14 14.1 14.2 14.100 Oxygen, % 5.5 5.4 5.3 5.400 Carbon Monoxide & Nitrogen, % 80.5 80.5 80.5 80.500 Fuel Factor 1.10 1.10 1.10 Dry Molecular Weight, lb/lb-Mole 30.46 30.47 30.48 30.470 Wet Molecular weight, lb/lb-Mole 28.80 28.68 28.69 28.723 Flue Gas Static Pressure, inches of H2O -1.7 -1.7 -1.7 -1.700 Absolute Flue Gas Pressure, inches of Mercury 23.09 23.06 23.09 23.080 Average Stack Gas Temperature, °F 196.98 196.83 197.46 197.090 Average Velocity Head, inches of H2O 1.6933098691 22231.615184955

63819 1.609723506

08897 1.639 Average Stack Gas Velocity, feet/second 92.88 90.95 90.77 91.533 Stack Cross-Sectional Area, square feet 314.159 314.159 314.159 314.159 Dry Volumetric Flow Rate, dry scfm 940,991.6 909,617.4 908,233.2919,614.067 Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,750,745.3 1,714,365.7 1,710,972.71,725,361.2 33 Percent Isokinetic of Sampling Rate, % 100.9 101.3 101.2 101.133 Percent Excess Air, % 34.9 34.1 33.2 34.067 F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000 Round Duct Diameter, inches 240 240 240 Rectangular Duct Width, inches 0 0 0 Rectangular Duct Length, inches 0 0 0 Fw 10640 10640 1064010,640.000 Fc 1800 1800 1800 1,800.000

Thursday, February 10, 2011 Page 22 of 23Information Collection Request, TEP - Springerville Generation Station Unit 3 8/11/2010 Location Stack Exit - OTM - 27/28 Average Run Number Test Date Run Start Time Run Finish Time Net Traversing Points Net Run Time, minutes Nozzle Diameter, inches Pitot Tube Coefficient Dry Gas Meter Calibration Factor Barometric Pressure, inches of Mercury Average Orifice Meter Differential, inches H2O Dry Gas Meter Volume Sampled, cubic feet Average Dry Gas Meter Temperature, °F Dry Gas Meter Volume Sampled, dscf Total Moisture Liquid collected, g Volume of Water Vapor, standard cubic feet Moisture Content of Stack Gas, % Moisture Saturation at Stack Gas Temperature, % Dry Mole Fraction Carbon Dioxide, % Oxygen, % Carbon Monoxide & Nitrogen, % Fuel Factor Dry Molecular Weight, lb/lb-Mole Wet Molecular weight, lb/lb-Mole Flue Gas Static Pressure, inches of H2O Absolute Flue Gas Pressure, inches of Mercury Average Stack Gas Temperature, °F Average Velocity Head, inches of H2O Average Stack Gas Velocity, feet/second Stack Cross-Sectional Area, square feet Dry Volumetric Flow Rate, dry scfm Actual Wet Volumetric Flue Gas Flow Rate, acfm Percent Isokinetic of Sampling Rate, % Percent Excess Air, % F-Factor, dscfm/MMBtu @ %O2 Round Duct Diameter, inches Rectangular Duct Width, inches Rectangular Duct Length, inches Fw Fc

Thursday, February 10, 2011 Page 23 of 23