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 4 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 4 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 4 Boiler 4 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 4 is rated at 420 megawatts net. Unit 4 falls 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 4 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 4 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 NMHC 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 Chromium 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 Cobalt Method 29 3 480 0 Stack Exit Filterable Particulate Method 29 3 480 0 Stack Exit Beryllium Method 29 3 480 0 Stack Exit Cadmium Method 29 3 480 0 Stack Exit Arsenic Method 29 3 480 0 Stack Exit

Thursday, February 10, 2011 Page 3 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 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 1 2 4 Test Date 5/6/2010 5/7/2010 5/7/2010 Run Start Time 11:30:00 AM 7:21:00 AM 2:35:00 PM

Run Finish Time 4:36:00 PM 12:20:00 PM 6:55:00 PM

Net Run Time, minutes 240 240 240 Dry Gas Meter Volume Sampled, dscf 125.527 127.831 127.627 126.995 Moisture Content of Stack Gas, % 14.00 14.15 14.33 14.160 Moisture Saturation at Stack Gas Temperature, % 95.43 94.81 94.31 94.850 Carbon Dioxide, % 13.85 14.25 14.24 14.113 Oxygen, % 5.62 5.21 5.23 5.353 Average Stack Gas Temperature, °F 196.67 196.67 196.42 196.587 Dry Volumetric Flow Rate, dry scfm 872,570.9 894,406.9 892,971.7 886,649.833 Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,647,261.31,680,436.5 1,680,625.0 1,669,440.93 3 Percent Isokinetic of Sampling Rate, % 98.7 98.1 98.1 98.300 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 4 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 4 8/11/2010 Emissions Summary Location: Stack Exit - Method 25A Compound: Total organic compounds (TOC) as Average Run 1 3 4 lb/mmBtuO2 3.11E-03 3.23E-03 2.66E-03 0.003 ppm 2.10E+00 2.18E+00 1.81E+00 2.030 ppm@7%O2 1.85E+00 1.92E+00 1.58E+00 1.783

Location: Stack Exit - Method 29 Compound: Antimony Average RunNumber 1 2 4 Mass_mg 0.001 0.001 0.001 0.001 lb/mmBtuO2 2.35E-07 2.25E-07 2.25E-07 0.000 Compound: Arsenic Average RunNumber 1 2 4 Mass_mg 0.001 0.001 0.001 0.001 lb/mmBtuO2 2.35E-07 2.25E-07 2.25E-07 0.000 Compound: Beryllium Average RunNumber 1 2 4 Mass_mg 0.00025 0.00025 0.00025 0.000 lb/mmBtuO2 5.87E-08 5.62E-08 5.63E-08 0.000 Compound: Cadmium Average RunNumber 1 2 4 Mass_mg 0.00055 0.00042 0.00057 0.001 lb/mmBtuO2 1.29E-07 9.44E-08 1.28E-07 0.000 Compound: Chromium Average RunNumber 1 2 4 Mass_mg 0.00116 0.00135 0.00126 0.001 lb/mmBtuO2 2.73E-07 3.03E-07 2.84E-07 0.000 Compound: Cobalt Average RunNumber 1 2 4 Mass_mg 0.00092 0.00092 0.00282 0.002 lb/mmBtuO2 2.16E-07 2.07E-07 6.35E-07 0.000 Compound: Filterable Particulate Average RunNumber 1 2 4 Mass_mg 5.4 3.3 1.8 3.500 lb/mmBtuO2 1.27E-03 7.41E-04 4.06E-04 0.001

Thursday, February 10, 2011 Page 6 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010 Compound: Lead Average RunNumber 1 2 4 Mass_mg 0.00288 0.0009 0.0008 0.002 lb/mmBtuO2 6.77E-07 2.02E-07 1.80E-07 0.000 Compound: Manganese Average RunNumber 1 2 4 Mass_mg 0.00188 0.0063 0.01027 0.006 lb/mmBtuO2 4.42E-07 1.42E-06 2.31E-06 0.000 Compound: Nickel Average RunNumber 1 2 4 Mass_mg 0.00377 0.00377 0.00302 0.004 lb/mmBtuO2 8.86E-07 8.47E-07 6.80E-07 0.000 Compound: Selenium Average RunNumber 1 2 4 Mass_mg 0.0025 0.0025 0.0025 0.003 lb/mmBtuO2 5.87E-07 5.62E-07 5.63E-07 0.000

Location: Stack Exit - OTM - 27/28 Compound: Filterable Particulate Average RunNumber 1 2 4 Mass_mg 3.54 2.55 4.05 3.380 lb/mmBtuO2 7.40E-04 5.42E-04 8.28E-04 0.001 Compound: Filterable PM2.5 Average RunNumber 1 2 4 Mass_mg 2.3 1.18 2.15 1.877 lb/mmBtuO2 4.81E-04 2.51E-04 4.40E-04 0.000 Compound: Inorganic (Aqueous) Condensible Pa Average RunNumber 1 2 4 Mass_mg 13 15 9.2 12.400 lb/mmBtuO2 2.72E-03 3.19E-03 1.88E-03 0.003 Compound: Organic Condensible Particulate Average RunNumber 1 2 4 Mass_mg 1.6 1.5 1.7 1.600 lb/mmBtuO2 3.34E-04 3.19E-04 3.48E-04 0.000 Compound: Total PM2.5 Average RunNumber 1 2 4 Mass_mg 16.9 17.68 13.05 15.877 Thursday, February 10, 2011 Page 7 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010

Process Run Data lb/mmBtuO2 3.53E-03 3.76E-03 2.67E-03 0.003

Thursday, February 10, 2011 Page 8 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 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 0.228 1000 Tons/hr Facility DMS 0 11 Coal Burned 0.228 1000 Tons/hr Facility DMS 0 12 Coal Burned 0.229 1000 Tons/hr Facility DMS 0 13 Coal Burned 0.228 1000 Tons/hr Facility DMS 0 14 Coal Burned 0.225 1000 Tons/hr Facility DMS 0 15 Coal Burned 0.23 1000 Tons/hr Facility DMS 0 2 Coal Burned 0.227 1000 Tons/hr Facility DMS 0 3 Coal Burned 0.229 1000 Tons/hr Facility DMS 0 4 Coal Burned 0.217 1000 Tons/hr Facility DMS 0 5 Coal Burned 0.228 1000 Tons/hr Facility DMS 0 6 Coal Burned 0.225 1000 Tons/hr Facility DMS 0 7 Coal Burned 0.226 1000 Tons/hr Facility DMS 0 8 Coal Burned 0.227 1000 Tons/hr Facility DMS 0 9 Coal Burned 0.229 1000 Tons/hr Facility DMS 0 1 Average Heat Input 3789.6 MMBtu/hr Facility DMS 0 10Average Heat Input 3990.2 MMBtu/hr Facility DMS 0 11 Average Heat Input 3982.6 MMBtu/hr Facility DMS 0 12 Average Heat Input 3927.7 MMBtu/hr Facility DMS 0 13 Average Heat Input 3819.4 MMBtu/hr Facility DMS 0 14 Average Heat Input 3833.3 MMBtu/hr Facility DMS 0 15 Average Heat Input 4056.0 MMBtu/hr Facility DMS 0 2 Average Heat Input 3938.9 MMBtu/hr Facility DMS 0 3 Average Heat Input 4042.7 MMBtu/hr Facility DMS 0 4 Average Heat Input 3738.3 MMBtu/hr Facility DMS 0 5 Average Heat Input 3970.2 MMBtu/hr Facility DMS 0 6 Average Heat Input 3850.7 MMBtu/hr Facility DMS 0 7 Average Heat Input 3910.4 MMBtu/hr Facility DMS 0 8 Average Heat Input 3968.1 MMBtu/hr Facility DMS 0 9 Average Heat Input 3888.8 MMBtu/hr Facility DMS 0 1 Flue Gas Flow Rate 845446 dscfm Calculated from Facility DMS 0

10Flue Gas Flow Rate 859716 dscfm Calculated from Facility DMS 0

Thursday, February 10, 2011 Page 9 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010 11 Flue Gas Flow Rate 854084 dscfm Calculated from Facility DMS 0

12Flue Gas Flow Rate 846242 dscfm Calculated from Facility DMS 0

13 Flue Gas Flow Rate 813395 dscfm Facility DMS, Dry 0 14Flue Gas Flow Rate 818263 dscfm Facility DMS, Dry 0 15 Flue Gas Flow Rate 867809 dscfm Facility DMS, Dry 0 2 Flue Gas Flow Rate 842758 dscfm Calculated from Facility DMS 0

3 Flue Gas Flow Rate 855020 dscfm Calculated from Facility DMS 0

4 Flue Gas Flow Rate 827754 dscfm Calculated from Facility DMS 0

5 Flue Gas Flow Rate 854407 dscfm Calculated from Facility DMS 0

6 Flue Gas Flow Rate 828127 dscfm Calculated from Facility DMS 0

7 Flue Gas Flow Rate 834669 dscfm Calculated from Facility DMS 0

8 Flue Gas Flow Rate 847024 dscfm Calculated from Facility DMS 0

9 Flue Gas Flow Rate 832041 dscfm Calculated from Facility DMS 0

1 Flue Gas Oxygen Content 5.6 % Unit 4 CEMS, Dry 0 10Flue Gas Oxygen Content 5.2 % Unit 4 CEMS, Dry 0 11 Flue Gas Oxygen Content 5.2 % Unit 4 CEMS, Dry 0 12Flue Gas Oxygen Content 5.2 % Unit 4 CEMS, Dry 0 13 Flue Gas Oxygen Content 5.03 % Unit 4 CEMS, Dry 0 14 Flue Gas Oxygen Content 5.03 % Unit 4 CEMS, Dry 0 15 Flue Gas Oxygen Content 5.13 % Unit 4 CEMS, Dry 0 2 Flue Gas Oxygen Content 5.12 % Unit 4 CEMS, Dry 0 3 Flue Gas Oxygen Content 4.88 % Unit 4 CEMS, Dry 0 4 Flue Gas Oxygen Content 5.62 % Unit 4 CEMS, Dry 0 5 Flue Gas Oxygen Content 5.2 % Unit 4 CEMS, Dry 0 6 Flue Gas Oxygen Content 5.22 % Unit 4 CEMS, Dry 0 7 Flue Gas Oxygen Content 5.1 % Unit 4 CEMS, Dry 0 8 Flue Gas Oxygen Content 5.1 % Unit 4 CEMS, Dry 0 9 Flue Gas Oxygen Content 5.07 % Unit 4 CEMS, Dry 0 1 Flue Gas Carbon Dioxide Content 14 % Unit 4 CEMS, Dry 0 10Flue Gas Carbon Dioxide Content 14.23 % Unit 4 CEMS, Dry 0

Thursday, February 10, 2011 Page 10 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010 11 Flue Gas Carbon Dioxide Content 14.3 % Unit 4 CEMS, Dry 0 12Flue Gas Carbon Dioxide Content 14.23 % Unit 4 CEMS, Dry 0 13 Flue Gas Carbon Dioxide Content 14.4 % Unit 4 CEMS, Dry 0 14 Flue Gas Carbon Dioxide Content 14.37 % Unit 4 CEMS, Dry 0 15 Flue Gas Carbon Dioxide Content 14.33 % Unit 4 CEMS, Dry 0 2 Flue Gas Carbon Dioxide Content 14.33 % Unit 4 CEMS, Dry 0 3 Flue Gas Carbon Dioxide Content 14.5 % Unit 4 CEMS, Dry 0 4 Flue Gas Carbon Dioxide Content 13.85 % Unit 4 CEMS, Dry 0 5 Flue Gas Carbon Dioxide Content 14.25 % Unit 4 CEMS, Dry 0 6 Flue Gas Carbon Dioxide Content 14.26 % Unit 4 CEMS, Dry 0 7 Flue Gas Carbon Dioxide Content 14.37 % Unit 4 CEMS, Dry 0 8 Flue Gas Carbon Dioxide Content 14.37 % Unit 4 CEMS, Dry 0 9 Flue Gas Carbon Dioxide Content 14.33 % Unit 4 CEMS, Dry 0 1 Flue Gas Moisture Content 14.5 % Unit 4 CEMS 0 10Flue Gas Moisture Content 15.03 % Unit 4 CEMS 0 11 Flue Gas Moisture Content 15.13 % Unit 4 CEMS 0 12Flue Gas Moisture Content 15.3 % Unit 4 CEMS 0 13 Flue Gas Moisture Content 15.77 % Unit 4 CEMS 0 14 Flue Gas Moisture Content 15.6 % Unit 4 CEMS 0 15 Flue Gas Moisture Content 15.43 % Unit 4 CEMS 0 2 Flue Gas Moisture Content 15.47 % Unit 4 CEMS 0 3 Flue Gas Moisture Content 15.51 % Unit 4 CEMS 0 4 Flue Gas Moisture Content 15.08 % Unit 4 CEMS 0 5 Flue Gas Moisture Content 15.13 % Unit 4 CEMS 0 6 Flue Gas Moisture Content 15.34 % Unit 4 CEMS 0 7 Flue Gas Moisture Content 15.6 % Unit 4 CEMS 0 8 Flue Gas Moisture Content 15.6 % Unit 4 CEMS 0 9 Flue Gas Moisture Content 15.8 % Unit 4 CEMS 0 1 Flue Gas Sampling Point Temperature 201.41 Deg F Facility DMS 0 10Flue Gas Sampling Point Temperature 188.67 Deg F Facility DMS 0 11 Flue Gas Sampling Point Temperature 189.03 Deg F Facility DMS 0 12Flue Gas Sampling Point Temperature 189.3 Deg F Facility DMS 0 13 Flue Gas Sampling Point Temperature 185.73 Deg F Facility DMS 0 14Flue Gas Sampling Point Temperature 185.27 Deg F Facility DMS 0 15 Flue Gas Sampling Point Temperature 188.8 Deg F Facility DMS 0 2 Flue Gas Sampling Point Temperature 191.86 Deg F Facility DMS 0

Thursday, February 10, 2011 Page 11 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010

APCD Run Data 3 Flue Gas Sampling Point Temperature 188.12 Deg F Facility DMS 0 4 Flue Gas Sampling Point Temperature 192.77 Deg F Facility DMS 0 5 Flue Gas Sampling Point Temperature 188.87 Deg F Facility DMS 0 6 Flue Gas Sampling Point Temperature 185.28 Deg F Facility DMS 0 7 Flue Gas Sampling Point Temperature 195.13 Deg F Facility DMS 0 8 Flue Gas Sampling Point Temperature 195.03 Deg F Facility DMS 0 9 Flue Gas Sampling Point Temperature 192.07 Deg F Facility DMS 0 1 Unit Gross Electrical Output 436.01 Mwe Facility DMS 0 10Unit Gross Electrical Output 442 Mwe Facility DMS 0 11 Unit Gross Electrical Output 442 Mwe Facility DMS 0 12Unit Gross Electrical Output 442 Mwe Facility DMS 0 13 Unit Gross Electrical Output 443 Mwe Facility DMS 0 14 Unit Gross Electrical Output 443.67 Mwe Facility DMS 0 15 Unit Gross Electrical Output 442 Mwe Facility DMS 0 2 Unit Gross Electrical Output 441.89 Mwe Facility DMS 0 3 Unit Gross Electrical Output 447 Mwe Facility DMS 0 4 Unit Gross Electrical Output 416 Mwe Facility DMS 0 5 Unit Gross Electrical Output 442 Mwe Facility DMS 0 6 Unit Gross Electrical Output 442 Mwe Facility DMS 0 7 Unit Gross Electrical Output 443 Mwe Facility DMS 0 8 Unit Gross Electrical Output 443 Mwe Facility DMS 0 9 Unit Gross Electrical Output 443 Mwe Facility DMS 0

Run Name Value UOM Comments Target Value 1 DRY SCRUBBER 75.21 gal/min. 10 DRY SCRUBBER 62.14 gal/min. 11 DRY SCRUBBER 62.02 gal/min. 12 DRY SCRUBBER 62 gal/min. 13 DRY SCRUBBER 81.75 gal/min. 14 DRY SCRUBBER 85.61 gal/min. 15 DRY SCRUBBER 92.71 gal/min. 2 DRY SCRUBBER 74.75 gal/min. 3 DRY SCRUBBER 100.07 gal/min. 4 DRY SCRUBBER 58.81 gal/min. 5 DRY SCRUBBER 70.94 gal/min.

Thursday, February 10, 2011 Page 12 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010

Process Lab Run Data 6 DRY SCRUBBER 68.91 gal/min. 7 DRY SCRUBBER 62.14 gal/min. 8 DRY SCRUBBER 69.82 gal/min. 9 DRY SCRUBBER 76.19 gal/min. 1 SCR Ammonia Injection Rate 203.8 lbs/hr 10 SCR Ammonia Injection Rate 167.06 lbs/hr 11 SCR Ammonia Injection Rate 167.77 lbs/hr 12 SCR Ammonia Injection Rate 168.53 lbs/hr 13 SCR Ammonia Injection Rate 202.05 lbs/hr 14 SCR Ammonia Injection Rate 199.82 lbs/hr 15 SCR Ammonia Injection Rate 189.57 lbs/hr 2 SCR Ammonia Injection Rate 198.04 lbs/hr 3 SCR Ammonia Injection Rate 181.18 lbs/hr 4 SCR Ammonia Injection Rate 152.22 lbs/hr 5 SCR Ammonia Injection Rate 191.51 lbs/hr 6 SCR Ammonia Injection Rate 187.35 lbs/hr 7 SCR Ammonia Injection Rate 161.48 lbs/hr 8 SCR Ammonia Injection Rate 152.32 lbs/hr 9 SCR Ammonia Injection Rate 153.68 lbs/hr 1 SCR Ammonia Slip 1.66 ppm 10 SCR Ammonia Slip 1.06 ppm 11 SCR Ammonia Slip 1.23 ppm 12 SCR Ammonia Slip 1.5 ppm 13 SCR Ammonia Slip 1.87 ppm 14 SCR Ammonia Slip 1.81 ppm 15 SCR Ammonia Slip 1.76 ppm 2 SCR Ammonia Slip 1.85 ppm 3 SCR Ammonia Slip 1.64 ppm 4 SCR Ammonia Slip 1.48 ppm 5 SCR Ammonia Slip 1.44 ppm 6 SCR Ammonia Slip 1.72 ppm 7 SCR Ammonia Slip 1.61 ppm 8 SCR Ammonia Slip 1.24 ppm 9 SCR Ammonia Slip 1.55 ppm

Run Name Value UOM Comments Thursday, February 10, 2011 Page 13 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010 Run Name Value UOM Comments 1 Fuel Higher Heating Value 8985 Btu/lb 10Fuel Higher Heating Value 8985 Btu/lb 11 Fuel Higher Heating Value 8985 Btu/lb 12Fuel Higher Heating Value 8985 Btu/lb 13 Fuel Higher Heating Value 8956 Btu/lb 14 Fuel Higher Heating Value 8956 Btu/lb 15 Fuel Higher Heating Value 8904 Btu/lb 2 Fuel Higher Heating Value 8959 Btu/lb 3 Fuel Higher Heating Value 9093 Btu/lb 4 Fuel Higher Heating Value 8982 Btu/lb 5 Fuel Higher Heating Value 8985 Btu/lb 6 Fuel Higher Heating Value 8959 Btu/lb 7 Fuel Higher Heating Value 8959 Btu/lb 8 Fuel Higher Heating Value 8956 Btu/lb 9 Fuel Higher Heating Value 8956 Btu/lb 1 Fuel Moisture 24.74 % 10Fuel Moisture 24.74 % 11 Fuel Moisture 24.74 % 12Fuel Moisture 24.74 % 13 Fuel Moisture 24.82 % 14 Fuel Moisture 24.82 % 15 Fuel Moisture 25.27 % 2 Fuel Moisture 24.18 % 3 Fuel Moisture 23.9 % 4 Fuel Moisture 24.21 % 5 Fuel Moisture 24.74 % 6 Fuel Moisture 24.18 % 7 Fuel Moisture 24.18 % 8 Fuel Moisture 24.82 % 9 Fuel Moisture 24.82 % 1 Fuel Mercury Content 0.08 ug/g 10Fuel Mercury Content 0.08 ug/g 11 Fuel Mercury Content 0.08 ug/g 12Fuel Mercury Content 0.08 ug/g 13 Fuel Mercury Content 0.08 ug/g 14Fuel Mercury Content 0.08 ug/g 15 Fuel Mercury Content 0.06 ug/g 2 Fuel Mercury Content 0.1 ug/g 3 Fuel Mercury Content 0.07 ug/g 4 Fuel Mercury Content 0.04 ug/g 5 Fuel Mercury Content 0.08 ug/g 6 Fuel Mercury Content 0.1 ug/g

Thursday, February 10, 2011 Page 14 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010 7 Fuel Mercury Content 0.1 ug/g 8 Fuel Mercury Content 0.08 ug/g 9 Fuel Mercury Content 0.08 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 0.2 ug/g 14Fuel Cadmium Content 0.2 ug/g 15 Fuel Cadmium Content 0.2 ug/g 2 Fuel Cadmium Content 0.2 ug/g 3 Fuel Cadmium Content 1 ug/g 4 Fuel Cadmium Content 0.2 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 12 Ultimate/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 5 ug/g 10Fuel Nickel Content 5 ug/g 11 Fuel Nickel Content 5 ug/g 12Fuel Nickel Content 5 ug/g 13 Fuel Nickel Content 5 ug/g 14 Fuel Nickel Content 5 ug/g 15 Fuel Nickel Content 5 ug/g 2 Fuel Nickel Content 6 ug/g 3 Fuel Nickel Content 5 ug/g 4 Fuel Nickel Content 6 ug/g

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

Thursday, February 10, 2011 Page 16 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010 3 Fuel Beryllium Content 0.3 ug/g 4 Fuel Beryllium Content 0.3 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 2 ug/g 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 8 ug/g 10Fuel Manganese Content 8 ug/g 11 Fuel Manganese Content 8 ug/g 12Fuel Manganese Content 8 ug/g 13 Fuel Manganese Content 8 ug/g 14 Fuel Manganese Content 8 ug/g 15 Fuel Manganese Content 11 ug/g 2 Fuel Manganese Content 6 ug/g 3 Fuel Manganese Content 6 ug/g 4 Fuel Manganese Content 7 ug/g 5 Fuel Manganese Content 8 ug/g 6 Fuel Manganese Content 6 ug/g 7 Fuel Manganese Content 6 ug/g 8 Fuel Manganese Content 8 ug/g 9 Fuel Manganese Content 8 ug/g 1 Fuel Chlorine Content 10 ug/g 10Fuel Chlorine Content 10 ug/g 11 Fuel Chlorine Content 10 ug/g 12Fuel Chlorine Content 10 ug/g 13 Fuel Chlorine Content 10 ug/g 14 Fuel Chlorine Content 10 ug/g

Thursday, February 10, 2011 Page 17 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010 15 Fuel Chlorine Content 10 ug/g 2 Fuel Chlorine Content 10 ug/g 3 Fuel Chlorine Content 13 ug/g 4 Fuel Chlorine Content 11 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 9 Fuel Chlorine Content 10 ug/g 1 Fuel Fluorine Content 53 ug/g 10Fuel Fluorine Content 53 ug/g 11 Fuel Fluorine Content 53 ug/g 12Fuel Fluorine Content 53 ug/g 13 Fuel Fluorine Content 59 ug/g 14 Fuel Fluorine Content 59 ug/g 15 Fuel Fluorine Content 59 ug/g 2 Fuel Fluorine Content 68 ug/g 3 Fuel Fluorine Content 56 ug/g 4 Fuel Fluorine Content 58 ug/g 5 Fuel Fluorine Content 53 ug/g 6 Fuel Fluorine Content 68 ug/g 7 Fuel Fluorine Content 68 ug/g 8 Fuel Fluorine Content 59 ug/g 9 Fuel Fluorine Content 59 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 5.47 % 10Fuel Ash 5.47 % 11 Fuel Ash 5.47 % 12Fuel Ash 5.47 %

Thursday, February 10, 2011 Page 18 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010 13 Fuel Ash 5.61 % 14Fuel Ash 5.61 % 15 Fuel Ash 5.61 % 2 Fuel Ash 5.98 % 3 Fuel Ash 5.44 % 4 Fuel Ash 5.74 % 5 Fuel Ash 5.47 % 6 Fuel Ash 5.98 % 7 Fuel Ash 5.98 % 8 Fuel Ash 5.61 % 9 Fuel Ash 5.61 % 1 Fuel Sulfur 0.23 % 10Fuel Sulfur 0.23 % 11 Fuel Sulfur 0.23 % 12Fuel Sulfur 0.23 % 13 Fuel Sulfur 0.25 % 14Fuel Sulfur 0.25 % 15 Fuel Sulfur 0.24 % 2 Fuel Sulfur 0.23 % 3 Fuel Sulfur 0.24 % 4 Fuel Sulfur 0.22 % 5 Fuel Sulfur 0.23 % 6 Fuel Sulfur 0.23 % 7 Fuel Sulfur 0.23 % 8 Fuel Sulfur 0.25 % 9 Fuel Sulfur 0.25 % 1 Fuel Cobalt 2 ug/g 10Fuel Cobalt 2 ug/g 11 Fuel Cobalt 2 ug/g 12Fuel Cobalt 2 ug/g 13 Fuel Cobalt 2 ug/g 14 Fuel Cobalt 2 ug/g 15 Fuel Cobalt 2 ug/g 2 Fuel Cobalt 2 ug/g 3 Fuel Cobalt 2 ug/g 4 Fuel Cobalt 2 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

Thursday, February 10, 2011 Page 19 of 23Information Collection Request, TEP - Springerville Generation Station Unit 4 8/11/2010 11 Fuel Selenium Content 1 ug/g 12Fuel Selenium Content 1 ug/g 13 Fuel Selenium Content 1 ug/g 14 Fuel 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 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 4 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 4 8/11/2010 Location Stack Exit - Method 29 Average Run Number 1 2 4 Test Date 5/6/2010 5/7/2010 5/7/2010 Run Start Time 11:30:00 AM7:21:00 AM 2:35:00 PM Run Finish Time 4:36:00 PM12:20:00 PM 6:55:00 PM Net Traversing Points 28 28 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 1.005 1.005 1.005 1.005 Barometric Pressure, inches of Mercury 23.03 23.18 23.18 23.130 Average Orifice Meter Differential, inches H2O 1.11 1.15 1.15 1.137 Dry Gas Meter Volume Sampled, cubic feet 166.177 167.080 168.432 167.230 Average Dry Gas Meter Temperature, °F 82.63 79.29 84.52 82.147 Dry Gas Meter Volume Sampled, dscf 125.527 127.831 127.627 126.995 Total Moisture Liquid collected, g 434.2 447.7 453.5 445.133 Volume of Water Vapor, standard cubic feet 20.44 21.07 21.35 20.953 Moisture Content of Stack Gas, % 14.00 14.15 14.33 14.160 Moisture Saturation at Stack Gas Temperature, % 95.43 94.81 94.31 94.850 Dry Mole Fraction 0.86 0.8585 0.8567 0.858 Carbon Dioxide, % 13.85 14.25 14.24 14.113 Oxygen, % 5.62 5.21 5.23 5.353 Carbon Monoxide & Nitrogen, % 80.53 80.54 80.53 80.533 Fuel Factor 1.10 1.10 1.10 Dry Molecular Weight, lb/lb-Mole 30.44 30.49 30.49 30.473 Wet Molecular weight, lb/lb-Mole 28.70 28.72 28.70 28.707 Flue Gas Static Pressure, inches of H2O -1.5 -1.5 -1.5 -1.500 Absolute Flue Gas Pressure, inches of Mercury 22.92 23.07 23.07 23.020 Average Stack Gas Temperature, °F 196.67 196.67 196.42 196.587 Average Velocity Head, inches of H2O 1.4834382528 10631.554999562

23841 1.554867231

51899 1.531 Average Stack Gas Velocity, feet/second 87.39 89.15 89.16 88.567 Stack Cross-Sectional Area, square feet 314.159 314.159 314.159 314.159 Dry Volumetric Flow Rate, dry scfm 872,570.9 894,406.9 892,971.7886,649.833 Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,647,261.3 1,680,436.5 1,680,625.01,669,440.9 33 Percent Isokinetic of Sampling Rate, % 98.7 98.1 98.1 98.300 Percent Excess Air, % 35.9 32.5 32.6 33.667 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 4 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