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 23
Information 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 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:

3 Unit 3 Boiler

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/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 0 0 0 2000 500 4 12

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Thursday, February 10, 2011 Page 2 of 23
Information 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 

Location Points Comments

Stack Exit % H2O Method 1 - 4 3 120 0

Stack Exit Custom Method 18 3 120 0 Methane (CH4)

Total organic compounds 

(TOC) as Propane

Stack Exit Method 25A 3 120 0

Stack Exit Total PM2.5 OTM - 27/28 3 480 0

Inorganic (Aqueous) 

Condensible Part.

Stack Exit OTM - 27/28 3 480 0

Organic Condensible 

Particulate

Stack Exit 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

Organic Condensible 

Particulate

Stack Exit 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

Inorganic (Aqueous) 

Condensible Part.

Stack Exit Method 5/OTM-28 3 240 0

Thursday, February 10, 2011 Page 3 of 23
Information 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 1,750,745.3 1,714,365.7 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 23
Information 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 23
Information 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 23
Information 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 23
Information 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 23
Information 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 0 Facility DMS

10 Coal Burned 0.223 1000 Tons/hr 0 Facility DMS

11 Coal Burned 0.226 1000 Tons/hr 0 Facility DMS

12 Coal Burned 0.226 1000 Tons/hr 0 Facility DMS

13 Coal Burned 0.223 1000 Tons/hr 0 Facility DMS

14 Coal Burned 0.217 1000 Tons/hr 0 Facility DMS

15 Coal Burned 0.221 1000 Tons/hr 0 Facility DMS

2 Coal Burned 0.223 1000 Tons/hr 0 Facility DMS

3 Coal Burned 0.224 1000 Tons/hr 0 Facility DMS

4 Coal Burned 0.22 1000 Tons/hr 0 Facility DMS

5 Coal Burned 0.224 1000 Tons/hr 0 Facility DMS

6 Coal Burned 0.225 1000 Tons/hr 0 Facility DMS

7 Coal Burned 0.224 1000 Tons/hr 0 Facility DMS

8 Coal Burned 0.225 1000 Tons/hr 0 Facility DMS

9 Coal Burned 0.225 1000 Tons/hr 0 Facility DMS

1 Average Heat Input 3789.6 MMBtu/hr 0 Facility DMS

10 Average Heat Input 3757.5 MMBtu/hr 0 Facility DMS

11 Average Heat Input 3776.9 MMBtu/hr 0 Facility DMS

12 Average Heat Input 3776.9 MMBtu/hr 0 Facility DMS

13 Average Heat Input 3914.8 MMBtu/hr 0 Facility DMS

14 Average Heat Input 3796.4 MMBtu/hr 0 Facility DMS

15 Average Heat Input 3834.2 MMBtu/hr 0 Facility DMS

2 Average Heat Input 3807.2 MMBtu/hr 0 Facility DMS

3 Average Heat Input 3837.9 MMBtu/hr 0 Facility DMS

4 Average Heat Input 3804.9 MMBtu/hr 0 Facility DMS

5 Average Heat Input 3859.9 MMBtu/hr 0 Facility DMS

6 Average Heat Input 3841 MMBtu/hr 0 Facility DMS

7 Average Heat Input 3857.4 MMBtu/hr 0 Facility DMS

8 Average Heat Input 3847 MMBtu/hr 0 Facility DMS

9 Average Heat Input 3822.5 MMBtu/hr 0 Facility DMS

1 Flue Gas Flow Rate 832390 dscfm 0 Facility DMS, Dry

10 Flue Gas Flow Rate 824382 dscfm 0 Facility DMS, Dry

11 Flue Gas Flow Rate 829622 dscfm 0 Facility DMS, Dry

Thursday, February 10, 2011 Page 9 of 23
Information Collection Request, TEP - Springerville Generation Station Unit 3

8/11/2010

12 Flue Gas Flow Rate 822115 dscfm 0 Facility DMS

13 Flue Gas Flow Rate 845461 dscfm 0 Facility DMS

14 Flue Gas Flow Rate 828792 dscfm 0 Facility DMS

15 Flue Gas Flow Rate 838968 dscfm 0 Facility DMS

2 Flue Gas Flow Rate 835474 dscfm 0 Facility DMS, Dry

3 Flue Gas Flow Rate 829242 dscfm 0 Facility DMS, Dry

4 Flue Gas Flow Rate 826545 dscfm 0 Facility DMS, Dry

5 Flue Gas Flow Rate 828449 dscfm 0 Facility DMS, Dry

6 Flue Gas Flow Rate 830827 dscfm 0 Facility DMS, Dry

7 Flue Gas Flow Rate 829805 dscfm 0 Facility DMS, Dry

8 Flue Gas Flow Rate 829503 dscfm 0 Facility DMS, Dry

9 Flue Gas Flow Rate 834323 dscfm 0 Facility DMS, Dry

1 Flue Gas Oxygen Content 5.6 % 0 Unit 3 CEMS, Dry

10 Flue Gas Oxygen Content 5.5 % 0 Unit 3 CEMS, Dry

11 Flue Gas Oxygen Content 5.6 % 0 Unit 3 CEMS, Dry

12 Flue Gas Oxygen Content 5.6 % 0 Unit 3 CEMS, Dry

13 Flue Gas Oxygen Content 5.79 % 0 Unit 3 CEMS, Dry

14 Flue Gas Oxygen Content 5.96 % 0 Unit 3 CEMS, Dry

15 Flue Gas Oxygen Content 5.97 % 0 Unit 3 CEMS, Dry

2 Flue Gas Oxygen Content 5.6 % 0 Unit 3 CEMS, Dry

3 Flue Gas Oxygen Content 5.3 % 0 Unit 3 CEMS, Dry

4 Flue Gas Oxygen Content 5.5 % 0 Unit 3 CEMS, Dry

5 Flue Gas Oxygen Content 5.4 % 0 Unit 3 CEMS, Dry

6 Flue Gas Oxygen Content 5.3 % 0 Unit 3 CEMS, Dry

7 Flue Gas Oxygen Content 5.2 % 0 Unit 3 CEMS, Dry

8 Flue Gas Oxygen Content 5.3 % 0 Unit 3 CEMS, Dry

9 Flue Gas Oxygen Content 5.4 % 0 Unit 3 CEMS, Dry

1 Flue Gas Carbon Dioxide Content 14 % 0 Unit 3 CEMS, Dry

10 Flue Gas Carbon Dioxide Content 14 % 0 Unit 3 CEMS, Dry

11 Flue Gas Carbon Dioxide Content 14 % 0 Unit 3 CEMS, Dry

12 Flue Gas Carbon Dioxide Content 14 % 0 Unit 3 CEMS, Dry

13 Flue Gas Carbon Dioxide Content 13.76 % 0 Unit 3 CEMS, Dry

14 Flue Gas Carbon Dioxide Content 13.61 % 0 Unit 3 CEMS, Dry

15 Flue Gas Carbon Dioxide Content 13.58 % 0 Unit 3 CEMS, Dry

2 Flue Gas Carbon Dioxide Content 14 % 0 Unit 3 CEMS, Dry

3 Flue Gas Carbon Dioxide Content 14.2 % 0 Unit 3 CEMS, Dry

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

8/11/2010

4 Flue Gas Carbon Dioxide Content 14 % 0 Unit 3 CEMS, Dry

5 Flue Gas Carbon Dioxide Content 14.1 % 0 Unit 3 CEMS, Dry

6 Flue Gas Carbon Dioxide Content 14.2 % 0 Unit 3 CEMS, Dry

7 Flue Gas Carbon Dioxide Content 14.3 % 0 Unit 3 CEMS, Dry

8 Flue Gas Carbon Dioxide Content 14.2 % 0 Unit 3 CEMS, Dry

9 Flue Gas Carbon Dioxide Content 14.1 % 0 Unit 3 CEMS, Dry

1 Flue Gas Moisture Content 14.5 % 0 Unit 3 CEMS

10 Flue Gas Moisture Content 14.7 % 0 Unit 3 CEMS

11 Flue Gas Moisture Content 15.3 % 0 Unit 3 CEMS

12 Flue Gas Moisture Content 15.3 % 0 Unit 3 CEMS

13 Flue Gas Moisture Content 14.83 % 0 Unit 3 CEMS

14 Flue Gas Moisture Content 15.05 % 0 Unit 3 CEMS

15 Flue Gas Moisture Content 15.19 % 0 Unit 3 CEMS

2 Flue Gas Moisture Content 14.6 % 0 Unit 3 CEMS

3 Flue Gas Moisture Content 14.8 % 0 Unit 3 CEMS

4 Flue Gas Moisture Content 14.6 % 0 Unit 3 CEMS

5 Flue Gas Moisture Content 14.7 % 0 Unit 3 CEMS

6 Flue Gas Moisture Content 14.7 % 0 Unit 3 CEMS

7 Flue Gas Moisture Content 14.8 % 0 Unit 3 CEMS

8 Flue Gas Moisture Content 14.9 % 0 Unit 3 CEMS

9 Flue Gas Moisture Content 14.5 % 0 Unit 3 CEMS

1 Flue Gas Sampling Point Temperature 201.41 Deg F 0 Facility DMS

10 Flue Gas Sampling Point Temperature 201.2 Deg F 0 Facility DMS

11 Flue Gas Sampling Point Temperature 202.7 Deg F 0 Facility DMS

12 Flue Gas Sampling Point Temperature 202.7 Deg F 0 Facility DMS

13 Flue Gas Sampling Point Temperature 205.93 Deg F 0 Facility DMS

14 Flue Gas Sampling Point Temperature 207.36 Deg F 0 Facility DMS

15 Flue Gas Sampling Point Temperature 207.31 Deg F 0 Facility DMS

2 Flue Gas Sampling Point Temperature 201.33 Deg F 0 Facility DMS

3 Flue Gas Sampling Point Temperature 200.56 Deg F 0 Facility DMS

4 Flue Gas Sampling Point Temperature 201.37 Deg F 0 Facility DMS

5 Flue Gas Sampling Point Temperature 200.21 Deg F 0 Facility DMS

6 Flue Gas Sampling Point Temperature 200.7 Deg F 0 Facility DMS

7 Flue Gas Sampling Point Temperature 201.2 Deg F 0 Facility DMS

8 Flue Gas Sampling Point Temperature 200.87 Deg F 0 Facility DMS

9 Flue Gas Sampling Point Temperature 200.53 Deg F 0 Facility DMS

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

8/11/2010

APCD Run Data

1 Unit Gross Electrical Output 436.01 Mwe 0 Facility DMS

10 Unit Gross Electrical Output 436 Mwe 0 Facility DMS

11 Unit Gross Electrical Output 436 Mwe 0 Facility DMS

12 Unit Gross Electrical Output 436 Mwe 0 Facility DMS

13 Unit Gross Electrical Output 430.65 Mwe 0 Facility DMS

14 Unit Gross Electrical Output 414.33 Mwe 0 Facility DMS

15 Unit Gross Electrical Output 423.52 Mwe 0 Facility DMS

2 Unit Gross Electrical Output 435.7 Mwe 0 Facility DMS

3 Unit Gross Electrical Output 436.52 Mwe 0 Facility DMS

4 Unit Gross Electrical Output 431.99 Mwe 0 Facility DMS

5 Unit Gross Electrical Output 437.57 Mwe 0 Facility DMS

6 Unit Gross Electrical Output 435.98 Mwe 0 Facility DMS

7 Unit Gross Electrical Output 436 Mwe 0 Facility DMS

8 Unit Gross Electrical Output 435.97 Mwe 0 Facility DMS

9 Unit Gross Electrical Output 436 Mwe 0 Facility DMS

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.

12 DRY 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 23
Information 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

10 Fuel Higher Heating Value 8753 Btu/lb

11 Fuel Higher Heating Value 8753 Btu/lb

12 Fuel Higher Heating Value 8753 Btu/lb

13 Fuel Higher Heating Value 8743 Btu/lb

14 Fuel Higher Heating Value 8743 Btu/lb

15 Fuel Higher Heating Value 8743 Btu/lb

Thursday, February 10, 2011 Page 13 of 23
Information 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 %

10 Fuel Moisture 26.57 %

11 Fuel Moisture 26.57 %

12 Fuel Moisture 26.57 %

13 Fuel Moisture 27.56 %

14 Fuel 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

10 Fuel Mercury Content 0.05 ug/g

11 Fuel Mercury Content 0.05 ug/g

12 Fuel Mercury Content 0.05 ug/g

13 Fuel Mercury Content 0.068 ug/g

14 Fuel 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

10 Fuel Cadmium Content 0.2 ug/g

11 Fuel Cadmium Content 0.2 ug/g

12 Fuel Cadmium Content 0.2 ug/g

13 Fuel Cadmium Content 0.02 ug/g

Thursday, February 10, 2011 Page 14 of 23
Information Collection Request, TEP - Springerville Generation Station Unit 3

8/11/2010

14 Fuel 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

10 Ultimate/Proximate Analysis

11 Ultimate/Proximate Analysis

12 Ultimate/Proximate Analysis

13 Ultimate/Proximate Analysis

14 Ultimate/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

10 Fuel Nickel Content 6 ug/g

11 Fuel Nickel Content 6 ug/g

12 Fuel Nickel Content 6 ug/g

13 Fuel Nickel Content 4 ug/g

14 Fuel 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

10 Fuel Arsenic Content 1 ug/g

11 Fuel Arsenic Content 1 ug/g

Thursday, February 10, 2011 Page 15 of 23
Information Collection Request, TEP - Springerville Generation Station Unit 3

8/11/2010

12 Fuel 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 4 ug/g

10 Fuel Chromium Content 5 ug/g

11 Fuel Chromium Content 5 ug/g

12 Fuel Chromium Content 5 ug/g

13 Fuel Chromium Content 3.8 ug/g

14 Fuel 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

10 Fuel Beryllium Content 0.4 ug/g

11 Fuel Beryllium Content 0.4 ug/g

12 Fuel Beryllium Content 0.4 ug/g

13 Fuel Beryllium Content 0.2 ug/g

14 Fuel 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 23
Information Collection Request, TEP - Springerville Generation Station Unit 3

8/11/2010

10 Fuel Lead Content 2 ug/g

11 Fuel Lead Content 2 ug/g

12 Fuel Lead Content 2 ug/g

13 Fuel Lead Content 2 ug/g

14 Fuel 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

10 Fuel Manganese Content 12 ug/g

11 Fuel Manganese Content 12 ug/g

12 Fuel Manganese Content 12 ug/g

13 Fuel Manganese Content 7 ug/g

14 Fuel 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

10 Fuel Chlorine Content 27 ug/g

11 Fuel Chlorine Content 27 ug/g

12 Fuel Chlorine Content 27 ug/g

13 Fuel Chlorine Content 12 ug/g

14 Fuel 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 23
Information 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

10 Fuel Fluorine Content 59 ug/g

11 Fuel Fluorine Content 59 ug/g

12 Fuel Fluorine Content 59 ug/g

13 Fuel Fluorine Content 62.8 ug/g

14 Fuel 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

10 Fuel Antimony 1 ug/g

11 Fuel Antimony 1 ug/g

12 Fuel Antimony 1 ug/g

13 Fuel Antimony 1 ug/g

14 Fuel 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 %

10 Fuel Ash 5.7 %

11 Fuel Ash 5.7 %

12 Fuel Ash 5.7 %

13 Fuel Ash 4.574 %

14 Fuel 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 23
Information 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 %

10 Fuel Sulfur 0.24 %

11 Fuel Sulfur 0.24 %

12 Fuel Sulfur 0.24 %

13 Fuel Sulfur 0.168 %

14 Fuel 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

10 Fuel Cobalt 3 ug/g

11 Fuel Cobalt 3 ug/g

12 Fuel Cobalt 3 ug/g

13 Fuel Cobalt 2 ug/g

14 Fuel 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

10 Fuel Selenium Content 1 ug/g

11 Fuel Selenium Content 1 ug/g

12 Fuel 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

Thursday, February 10, 2011 Page 19 of 23
Information 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 23
Information 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 23
Information 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 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 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

2223

1.615184955

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 940,991.6 909,617.4 908,233.2 919,614.067

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,750,745.3 1,714,365.7 1,710,972.7 1,725,361.2

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 10640 10,640.000

Fc 1800 1800 1800 1,800.000

Thursday, February 10, 2011 Page 22 of 23
Information 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