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 23
Information 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 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:

4 Unit 4 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 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/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 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 

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 NMHC

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 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

Thursday, February 10, 2011 Page 3 of 23
Information 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 1,647,261.3 1,680,436.5 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 23
Information 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 23
Information 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 23
Information 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 23
Information 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 23
Information 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 0 Facility DMS

10 Coal Burned 0.228 1000 Tons/hr 0 Facility DMS

11 Coal Burned 0.228 1000 Tons/hr 0 Facility DMS

12 Coal Burned 0.229 1000 Tons/hr 0 Facility DMS

13 Coal Burned 0.228 1000 Tons/hr 0 Facility DMS

14 Coal Burned 0.225 1000 Tons/hr 0 Facility DMS

15 Coal Burned 0.23 1000 Tons/hr 0 Facility DMS

2 Coal Burned 0.227 1000 Tons/hr 0 Facility DMS

3 Coal Burned 0.229 1000 Tons/hr 0 Facility DMS

4 Coal Burned 0.217 1000 Tons/hr 0 Facility DMS

5 Coal Burned 0.228 1000 Tons/hr 0 Facility DMS

6 Coal Burned 0.225 1000 Tons/hr 0 Facility DMS

7 Coal Burned 0.226 1000 Tons/hr 0 Facility DMS

8 Coal Burned 0.227 1000 Tons/hr 0 Facility DMS

9 Coal Burned 0.229 1000 Tons/hr 0 Facility DMS

1 Average Heat Input 3789.6 MMBtu/hr 0 Facility DMS

10 Average Heat Input 3990.2 MMBtu/hr 0 Facility DMS

11 Average Heat Input 3982.6 MMBtu/hr 0 Facility DMS

12 Average Heat Input 3927.7 MMBtu/hr 0 Facility DMS

13 Average Heat Input 3819.4 MMBtu/hr 0 Facility DMS

14 Average Heat Input 3833.3 MMBtu/hr 0 Facility DMS

15 Average Heat Input 4056.0 MMBtu/hr 0 Facility DMS

2 Average Heat Input 3938.9 MMBtu/hr 0 Facility DMS

3 Average Heat Input 4042.7 MMBtu/hr 0 Facility DMS

4 Average Heat Input 3738.3 MMBtu/hr 0 Facility DMS

5 Average Heat Input 3970.2 MMBtu/hr 0 Facility DMS

6 Average Heat Input 3850.7 MMBtu/hr 0 Facility DMS

7 Average Heat Input 3910.4 MMBtu/hr 0 Facility DMS

8 Average Heat Input 3968.1 MMBtu/hr 0 Facility DMS

9 Average Heat Input 3888.8 MMBtu/hr 0 Facility DMS

1 Flue Gas Flow Rate 845446 dscfm Calculated from 

Facility DMS

0

10 Flue Gas Flow Rate 859716 dscfm Calculated from 

Facility DMS

0

Thursday, February 10, 2011 Page 9 of 23
Information Collection Request, TEP - Springerville Generation Station Unit 4

8/11/2010

11 Flue Gas Flow Rate 854084 dscfm Calculated from 

Facility DMS

0

12 Flue Gas Flow Rate 846242 dscfm Calculated from 

Facility DMS

0

13 Flue Gas Flow Rate 813395 dscfm 0 Facility DMS, Dry

14 Flue Gas Flow Rate 818263 dscfm 0 Facility DMS, Dry

15 Flue Gas Flow Rate 867809 dscfm 0 Facility DMS, Dry

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 % 0 Unit 4 CEMS, Dry

10 Flue Gas Oxygen Content 5.2 % 0 Unit 4 CEMS, Dry

11 Flue Gas Oxygen Content 5.2 % 0 Unit 4 CEMS, Dry

12 Flue Gas Oxygen Content 5.2 % 0 Unit 4 CEMS, Dry

13 Flue Gas Oxygen Content 5.03 % 0 Unit 4 CEMS, Dry

14 Flue Gas Oxygen Content 5.03 % 0 Unit 4 CEMS, Dry

15 Flue Gas Oxygen Content 5.13 % 0 Unit 4 CEMS, Dry

2 Flue Gas Oxygen Content 5.12 % 0 Unit 4 CEMS, Dry

3 Flue Gas Oxygen Content 4.88 % 0 Unit 4 CEMS, Dry

4 Flue Gas Oxygen Content 5.62 % 0 Unit 4 CEMS, Dry

5 Flue Gas Oxygen Content 5.2 % 0 Unit 4 CEMS, Dry

6 Flue Gas Oxygen Content 5.22 % 0 Unit 4 CEMS, Dry

7 Flue Gas Oxygen Content 5.1 % 0 Unit 4 CEMS, Dry

8 Flue Gas Oxygen Content 5.1 % 0 Unit 4 CEMS, Dry

9 Flue Gas Oxygen Content 5.07 % 0 Unit 4 CEMS, Dry

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

10 Flue Gas Carbon Dioxide Content 14.23 % 0 Unit 4 CEMS, Dry

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

8/11/2010

11 Flue Gas Carbon Dioxide Content 14.3 % 0 Unit 4 CEMS, Dry

12 Flue Gas Carbon Dioxide Content 14.23 % 0 Unit 4 CEMS, Dry

13 Flue Gas Carbon Dioxide Content 14.4 % 0 Unit 4 CEMS, Dry

14 Flue Gas Carbon Dioxide Content 14.37 % 0 Unit 4 CEMS, Dry

15 Flue Gas Carbon Dioxide Content 14.33 % 0 Unit 4 CEMS, Dry

2 Flue Gas Carbon Dioxide Content 14.33 % 0 Unit 4 CEMS, Dry

3 Flue Gas Carbon Dioxide Content 14.5 % 0 Unit 4 CEMS, Dry

4 Flue Gas Carbon Dioxide Content 13.85 % 0 Unit 4 CEMS, Dry

5 Flue Gas Carbon Dioxide Content 14.25 % 0 Unit 4 CEMS, Dry

6 Flue Gas Carbon Dioxide Content 14.26 % 0 Unit 4 CEMS, Dry

7 Flue Gas Carbon Dioxide Content 14.37 % 0 Unit 4 CEMS, Dry

8 Flue Gas Carbon Dioxide Content 14.37 % 0 Unit 4 CEMS, Dry

9 Flue Gas Carbon Dioxide Content 14.33 % 0 Unit 4 CEMS, Dry

1 Flue Gas Moisture Content 14.5 % 0 Unit 4 CEMS

10 Flue Gas Moisture Content 15.03 % 0 Unit 4 CEMS

11 Flue Gas Moisture Content 15.13 % 0 Unit 4 CEMS

12 Flue Gas Moisture Content 15.3 % 0 Unit 4 CEMS

13 Flue Gas Moisture Content 15.77 % 0 Unit 4 CEMS

14 Flue Gas Moisture Content 15.6 % 0 Unit 4 CEMS

15 Flue Gas Moisture Content 15.43 % 0 Unit 4 CEMS

2 Flue Gas Moisture Content 15.47 % 0 Unit 4 CEMS

3 Flue Gas Moisture Content 15.51 % 0 Unit 4 CEMS

4 Flue Gas Moisture Content 15.08 % 0 Unit 4 CEMS

5 Flue Gas Moisture Content 15.13 % 0 Unit 4 CEMS

6 Flue Gas Moisture Content 15.34 % 0 Unit 4 CEMS

7 Flue Gas Moisture Content 15.6 % 0 Unit 4 CEMS

8 Flue Gas Moisture Content 15.6 % 0 Unit 4 CEMS

9 Flue Gas Moisture Content 15.8 % 0 Unit 4 CEMS

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

10 Flue Gas Sampling Point Temperature 188.67 Deg F 0 Facility DMS

11 Flue Gas Sampling Point Temperature 189.03 Deg F 0 Facility DMS

12 Flue Gas Sampling Point Temperature 189.3 Deg F 0 Facility DMS

13 Flue Gas Sampling Point Temperature 185.73 Deg F 0 Facility DMS

14 Flue Gas Sampling Point Temperature 185.27 Deg F 0 Facility DMS

15 Flue Gas Sampling Point Temperature 188.8 Deg F 0 Facility DMS

2 Flue Gas Sampling Point Temperature 191.86 Deg F 0 Facility DMS

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

8/11/2010

APCD Run Data

3 Flue Gas Sampling Point Temperature 188.12 Deg F 0 Facility DMS

4 Flue Gas Sampling Point Temperature 192.77 Deg F 0 Facility DMS

5 Flue Gas Sampling Point Temperature 188.87 Deg F 0 Facility DMS

6 Flue Gas Sampling Point Temperature 185.28 Deg F 0 Facility DMS

7 Flue Gas Sampling Point Temperature 195.13 Deg F 0 Facility DMS

8 Flue Gas Sampling Point Temperature 195.03 Deg F 0 Facility DMS

9 Flue Gas Sampling Point Temperature 192.07 Deg F 0 Facility DMS

1 Unit Gross Electrical Output 436.01 Mwe 0 Facility DMS

10 Unit Gross Electrical Output 442 Mwe 0 Facility DMS

11 Unit Gross Electrical Output 442 Mwe 0 Facility DMS

12 Unit Gross Electrical Output 442 Mwe 0 Facility DMS

13 Unit Gross Electrical Output 443 Mwe 0 Facility DMS

14 Unit Gross Electrical Output 443.67 Mwe 0 Facility DMS

15 Unit Gross Electrical Output 442 Mwe 0 Facility DMS

2 Unit Gross Electrical Output 441.89 Mwe 0 Facility DMS

3 Unit Gross Electrical Output 447 Mwe 0 Facility DMS

4 Unit Gross Electrical Output 416 Mwe 0 Facility DMS

5 Unit Gross Electrical Output 442 Mwe 0 Facility DMS

6 Unit Gross Electrical Output 442 Mwe 0 Facility DMS

7 Unit Gross Electrical Output 443 Mwe 0 Facility DMS

8 Unit Gross Electrical Output 443 Mwe 0 Facility DMS

9 Unit Gross Electrical Output 443 Mwe 0 Facility DMS

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 23
Information 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 23
Information Collection Request, TEP - Springerville Generation Station Unit 4

8/11/2010

Run Name Value UOM Comments

1 Fuel Higher Heating Value 8985 Btu/lb

10 Fuel Higher Heating Value 8985 Btu/lb

11 Fuel Higher Heating Value 8985 Btu/lb

12 Fuel 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 %

10 Fuel Moisture 24.74 %

11 Fuel Moisture 24.74 %

12 Fuel 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

10 Fuel Mercury Content 0.08 ug/g

11 Fuel Mercury Content 0.08 ug/g

12 Fuel Mercury Content 0.08 ug/g

13 Fuel Mercury Content 0.08 ug/g

14 Fuel 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 23
Information 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

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 0.2 ug/g

14 Fuel 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

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 5 ug/g

10 Fuel Nickel Content 5 ug/g

11 Fuel Nickel Content 5 ug/g

12 Fuel 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 23
Information 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

10 Fuel Arsenic Content 1 ug/g

11 Fuel Arsenic Content 1 ug/g

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 5 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 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

10 Fuel Beryllium Content 0.3 ug/g

11 Fuel Beryllium Content 0.3 ug/g

12 Fuel Beryllium Content 0.3 ug/g

13 Fuel Beryllium Content 0.3 ug/g

14 Fuel 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 23
Information 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

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 8 ug/g

10 Fuel Manganese Content 8 ug/g

11 Fuel Manganese Content 8 ug/g

12 Fuel 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

10 Fuel Chlorine Content 10 ug/g

11 Fuel Chlorine Content 10 ug/g

12 Fuel 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 23
Information 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

10 Fuel Fluorine Content 53 ug/g

11 Fuel Fluorine Content 53 ug/g

12 Fuel 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

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 5.47 %

10 Fuel Ash 5.47 %

11 Fuel Ash 5.47 %

12 Fuel Ash 5.47 %

Thursday, February 10, 2011 Page 18 of 23
Information Collection Request, TEP - Springerville Generation Station Unit 4

8/11/2010

13 Fuel Ash 5.61 %

14 Fuel 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 %

10 Fuel Sulfur 0.23 %

11 Fuel Sulfur 0.23 %

12 Fuel Sulfur 0.23 %

13 Fuel Sulfur 0.25 %

14 Fuel 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

10 Fuel Cobalt 2 ug/g

11 Fuel Cobalt 2 ug/g

12 Fuel 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

10 Fuel Selenium Content 1 ug/g

Thursday, February 10, 2011 Page 19 of 23
Information Collection Request, TEP - Springerville Generation Station Unit 4

8/11/2010

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

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 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 23
Information 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 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 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

1063

1.554999562

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 872,570.9 894,406.9 892,971.7 886,649.833

Actual Wet Volumetric Flue Gas Flow Rate, acfm 1,647,261.3 1,680,436.5 1,680,625.0 1,669,440.9

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 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 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