Name: Samuel Devlin

Title: Plant Manager

Company: Tucson Electric Power

Sign Date: 8/11/2010

Name: Larry Cottone

Title: Project Manager

Company: CCI Environmental

Sign Date: 8/11/2010

Permitted Facility Representative / Date Testing Company Representative / Date

Information Collection Request, TEP - Springerville Generation Station Unit 2

Final Test Report 

for

/ /

Based on information and belief formed 

after reasonable inquiry, I certify that the 

statements and information in this test 

report are true, accurate, and complete.

I have reviewed all testing details and 

results in this test report and hereby 

certify that the test report is authentic 

and accurate.

Thursday, February 10, 2011 Page 1 of 14
Information Collection Request, TEP - Springerville Generation Station Unit 2

8/11/2010

Facility Information:

Springerville Generating Station

Off Route 191 approx 15 Miles NE of city

P.O. Box 2222

Springerville AZ 85938

Contact: Amy Pulsifer

Phone: 928 337 7429

Fax:

Email:

Testing Company:

CCI Environmental Consultants, Inc.

3855 South 500 West, Suite I

Salt Lake City UT 84115

Contact:Larry Cottone

Phone: 801.269.0550

Fax:

Email:

Air Permit Number:

32008

Permitted Source ID/Name:

2 Unit 2 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, TS3 and 4. Unit 2 is rated at 380 megawatts 

net. Particulate matter and SO2 are controlled by dry SO2 scrubbers followed by fabric filter bag houses. 

Unit 2 falla under the acid rain regulations of the 1990 Clean Air Act Amendments including the continuous emission 

monitoring system (CEMS) requirements of 40 CFR Part 75. TEP Springerville operates CEMS for NOX, SO2, 

CO2, and flow on Unit 2 to satisfy Part 60 and 75 requirements. 

B). Control Equipment Description

Sulfur dioxide emissions are controlled by a dry scrubber. The dry scrubber is followed by a bag house to remove 

particulate matter.

Industry/SCC/NAIS 221112

Sampling Location Information:

Test Parameter Information:

AFS #: 8223 FRS #: 110000600788

SCC / Description 10100202 External Combustion Boilers - Electric Generation - Bituminous/Subbituminous 

Coal - Pulverized Coal: Dry Bottom (Bituminous Coal) 

The following state and federal regulations that apply to the proposed testing:

Location

Round

Duct

Diam.

Distance from 

upstream dist.

Distance from

downstream dist.

Number of

Traverse Ports

Equiv. 

Diam

Min.Travers 

Points

Rect. Duct 

Length /Width

Stack Exit 240 0 0 0 2000 500 4 12

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

8/11/2010

The following describes any modifications and/or deviations to the applicable test 

methods. If alternative methods were requested, see the attachments for documentation 

of request AND approval, including dates.

Not applicable.

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Stack Exit % H2O Method 1 - 4 3 120 0

Stack Exit Carbon Monoxide Method 10 3 120 0

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

Total organic compounds 

(TOC) as Propane

Stack Exit Method 25A 3 120 0

Stack Exit O2 Method 3A O2 3 120 0

Stack Exit Co2 Method 3A CO2 3 120 0

Thursday, February 10, 2011 Page 3 of 14
Information Collection Request, TEP - Springerville Generation Station Unit 2

8/11/2010

Sampling / Stack Data Results Summary

Location Stack Exit - Method 10

Average

Run Number 4 5 6

Test Date 2/26/2010 2/26/2010 2/26/2010

Run Start Time 9:18:00 AM 12:43:00 

PM

4:00:00 PM

Run Finish Time 11:18:00 AM 2:43:00 PM 6:00:00 PM

Carbon Dioxide, % 10.443 10.36 10.139 10.314

Oxygen, % 8.832 8.81 8.9216 8.855

Dry Volumetric Flow Rate, dry scfm 1100077.8 1101177.8 1096761.1 1,099,338.90

0

F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000

Moisture, %

Fuel Type Coal - 

Bituminous

Coal - 

Bituminous

Coal - 

Bituminous

Fw 10640 10640 10640 10,640.000

Fc 1800 1800 1800 1,800.000

Location Stack Exit - Method 25A

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

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

8/11/2010

Location Stack Exit - Method 3A CO2

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Location Stack Exit - Method 3A O2

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Fuel Type

Fw

Fc

Thursday, February 10, 2011 Page 5 of 14
Information Collection Request, TEP - Springerville Generation Station Unit 2

8/11/2010

Emissions Summary

Process Run Data

Location: Stack Exit - Method 10

Compound: Carbon Monoxide

Average

Run 4 5 6

lb/mmBtuO2 1.98E+00 1.35E+00 8.74E-01 1.401

ppm 1.60E+03 1.10E+03 7.05E+02 1,135.000

ppm@7%O2 1.84E+03 1.26E+03 8.18E+02 1,306.000

Location: Stack Exit - Method 25A

Compound: Total organic compounds (TOC) as 

Average

Run 1 2 3

lb/mmBtuO2 1.40E-04 0.00E+00 0.00E+00 0.000

ppm 7.44E-02 0.00E+00 0.00E+00 0.025

ppm@7%O2 8.34E-02 0.00E+00 0.00E+00 0.028

Thursday, February 10, 2011 Page 6 of 14
Information Collection Request, TEP - Springerville Generation Station Unit 2

8/11/2010

Process Run Data

Run Name Value UOM Comments

Target

Value

1 Coal Burned 0.1917 1000 Tons/hr 0

2 Coal Burned 0.1932 1000 Tons/hr 0

3 Coal Burned 0.1937 1000 Tons/hr 0

4 Coal Burned 0.1761 1000 Tons/hr 0

5 Coal Burned 0.1757 1000 Tons/hr 0

6 Coal Burned 0.1775 1000 Tons/hr 0

1 Average Heat Input 3466.5 MMBtu/hr 0

2 Average Heat Input 3495.3 MMBtu/hr 0

3 Average Heat Input 3503.3 MMBtu/hr 0

4 Average Heat Input 3300.2 MMBtu/hr 0

5 Average Heat Input 3291.5 MMBtu/hr 0

6 Average Heat Input 3326.0 MMBtu/hr 0

1 Flue Gas Flow Rate 1E+06 scfm 0

2 Flue Gas Flow Rate 1E+06 scfm 0

3 Flue Gas Flow Rate 1E+06 scfm 0

4 Flue Gas Flow Rate 1E+06 scfm 0

5 Flue Gas Flow Rate 1E+06 scfm 0

6 Flue Gas Flow Rate 1E+06 scfm 0

1 Flue Gas Carbon Dioxide Content 9.26 % 0 wet

2 Flue Gas Carbon Dioxide Content 9.4 % 0 Wet

3 Flue Gas Carbon Dioxide Content 9.52 % 0 wet

4 Flue Gas Carbon Dioxide Content 9.2 % 0 wet

5 Flue Gas Carbon Dioxide Content 9.17 % 0 wet

6 Flue Gas Carbon Dioxide Content 9.3 % 0 wet

1 Flue Gas Sampling Point Temperature 189.27 Deg F 0

2 Flue Gas Sampling Point Temperature 188.03 Deg F 0

3 Flue Gas Sampling Point Temperature 188.08 Deg F 0

4 Flue Gas Sampling Point Temperature 196.7 Deg F 0

5 Flue Gas Sampling Point Temperature 197.03 Deg F 0

6 Flue Gas Sampling Point Temperature 197.97 Deg F 0

1 Gross Electrical power generation 412 MW/hr 0

2 Gross Electrical power generation 412 MW/hr 0

3 Gross Electrical power generation 412 MW/hr 0

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

8/11/2010

APCD Run Data

Process Lab Run Data

4 Gross Electrical power generation 391 MW/hr 0

5 Gross Electrical power generation 391 MW/hr 0

6 Gross Electrical power generation 391 MW/hr 0

Run Name Value UOM Comments

Target

Value

1 DRY SCRUBBER 217.69 gal/min 0

2 DRY SCRUBBER 204.74 gal/min 0

3 DRY SCRUBBER 197.45 gal/min 0

4 DRY SCRUBBER 191.17 gal/min 0

5 DRY SCRUBBER 194.43 gal/min 0

6 DRY SCRUBBER 200.4 gal/min 0

Run Name Value UOM Comments

1 Fuel Higher Heating Value 9383 Btu/lb

2 Fuel Higher Heating Value 9383 Btu/lb

3 Fuel Higher Heating Value 9383 Btu/lb

4 Fuel Higher Heating Value 9383 Btu/lb

5 Fuel Higher Heating Value 9383 Btu/lb

6 Fuel Higher Heating Value 9383 Btu/lb

1 Fuel Moisture 18.25 %

2 Fuel Moisture 18.25 %

3 Fuel Moisture 18.25 %

4 Fuel Moisture 18.25 %

5 Fuel Moisture 18.25 %

6 Fuel Moisture 18.25 %

1 Fuel Mercury Content 0.13 ug/g

2 Fuel Mercury Content 0.13 ug/g

3 Fuel Mercury Content 0.13 ug/g

4 Fuel Mercury Content 0.13 ug/g

5 Fuel Mercury Content 0.13 ug/g

6 Fuel Mercury Content 0.13 ug/g

1 Fuel Cadmium Content 0.4 ug/g

2 Fuel Cadmium Content 0.4 ug/g

3 Fuel Cadmium Content 0.4 ug/g

4 Fuel Cadmium Content 0.4 ug/g

5 Fuel Cadmium Content 0.4 ug/g

6 Fuel Cadmium Content 0.4 ug/g

1 Ultimate/Proximate Analysis

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

8/11/2010

2 Ultimate/Proximate Analysis

3 Ultimate/Proximate Analysis

4 Ultimate/Proximate Analysis

5 Ultimate/Proximate Analysis

6 Ultimate/Proximate Analysis

1 Fuel Nickel Content 5 ug/g

2 Fuel Nickel Content 5 ug/g

3 Fuel Nickel Content 5 ug/g

4 Fuel Nickel Content 5 ug/g

5 Fuel Nickel Content 5 ug/g

6 Fuel Nickel Content 5 ug/g

1 Fuel Arsenic Content 7 ug/g

2 Fuel Arsenic Content 7 ug/g

3 Fuel Arsenic Content 7 ug/g

4 Fuel Arsenic Content 7 ug/g

5 Fuel Arsenic Content 7 ug/g

6 Fuel Arsenic Content 7 ug/g

1 Fuel Chromium Content 8 ug/g

2 Fuel Chromium Content 8 ug/g

3 Fuel Chromium Content 8 ug/g

4 Fuel Chromium Content 8 ug/g

5 Fuel Chromium Content 8 ug/g

6 Fuel Chromium Content 8 ug/g

1 Fuel Beryllium Content 0.7 ug/g

2 Fuel Beryllium Content 0.7 ug/g

3 Fuel Beryllium Content 0.7 ug/g

4 Fuel Beryllium Content 0.7 ug/g

5 Fuel Beryllium Content 0.7 ug/g

6 Fuel Beryllium Content 0.7 ug/g

1 Fuel Lead Content 7 ug/g

2 Fuel Lead Content 7 ug/g

3 Fuel Lead Content 7 ug/g

4 Fuel Lead Content 7 ug/g

5 Fuel Lead Content 7 ug/g

6 Fuel Lead Content 7 ug/g

1 Fuel Manganese Content 71 ug/g

2 Fuel Manganese Content 71 ug/g

3 Fuel Manganese Content 71 ug/g

4 Fuel Manganese Content 71 ug/g

5 Fuel Manganese Content 71 ug/g

6 Fuel Manganese Content 71 ug/g

1 Fuel Chlorine Content, Dry 19 ug/g

2 Fuel Chlorine Content, Dry 19 ug/g

Thursday, February 10, 2011 Page 9 of 14
Information Collection Request, TEP - Springerville Generation Station Unit 2

8/11/2010

3 Fuel Chlorine Content, Dry 19 ug/g

4 Fuel Chlorine Content, Dry 19 ug/g

5 Fuel Chlorine Content, Dry 19 ug/g

6 Fuel Chlorine Content, Dry 19 ug/g

1 Fuel Fluorine Content, Dry 70 ug/g

2 Fuel Fluorine Content, Dry 70 ug/g

3 Fuel Fluorine Content, Dry 70 ug/g

4 Fuel Fluorine Content, Dry 70 ug/g

5 Fuel Fluorine Content, Dry 70 ug/g

6 Fuel Fluorine Content, Dry 70 ug/g

1 Fuel Selenium Content 2 ug/g

2 Fuel Selenium Content 2 ug/g

3 Fuel Selenium Content 2 ug/g

4 Fuel Selenium Content 2 ug/g

5 Fuel Selenium Content 2 ug/g

6 Fuel Selenium Content 2 ug/g

1 Fuel Antimony Content 2 ug/g

2 Fuel Antimony Content 2 ug/g

3 Fuel Antimony Content 2 ug/g

4 Fuel Antimony Content 2 ug/g

5 Fuel Antimony Content 2 ug/g

6 Fuel Antimony Content 2 ug/g

1 Fuel Cobalt Conntent 2 ug/g

2 Fuel Cobalt Conntent 2 ug/g

3 Fuel Cobalt Conntent 2 ug/g

4 Fuel Cobalt Conntent 2 ug/g

5 Fuel Cobalt Conntent 2 ug/g

6 Fuel Cobalt Conntent 2 ug/g

1 Fuel Ash Content 13.32 %

2 Fuel Ash Content 13.32 %

3 Fuel Ash Content 13.32 %

4 Fuel Ash Content 13.32 %

5 Fuel Ash Content 13.32 %

6 Fuel Ash Content 13.32 %

1 Fuel Sulphur Content 1.12 %

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

8/11/2010

Sampling / Stack Data Results Detail

Location Stack Exit - Method 10

Average

Run Number 4 5 6

Test Date 2/26/2010 2/26/2010 2/26/2010

Run Start Time 9:18:00 AM 12:43:00 PM 4:00:00 PM

Run Finish Time 11:18:00 AM 2:43:00 PM 6:00:00 PM

Carbon Dioxide, % 10.443 10.36 10.139 10.314

Oxygen, % 8.832 8.81 8.9216 8.855

Fuel Factor 1.16 1.17 1.18

Dry Volumetric Flow Rate, dry scfm 1100077.8 1101177.8 1096761.1 1,099,338.9

00

F-Factor, dscfm/MMBtu @ %O2 9780 9780 9780 9,780.000

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range 2017 2017 2017 2,017.000

Operating Units ppm ppm ppm

No. Readings/Avg. 4 4 4 4.000

Calibration Set 30 30 30 30.000

Calibration Pre Zero Cylinder ID Nitrogen Nitrogen Nitrogen

Calibration Pre Zero Cylinder Instrument Response 0 6 2 2.667

Calibration Pre Zero Cylinder Bias 0 0.3 0.1 0.133

Calibration Pre Zero Cylinder Drift 0 0 0 0.000

Calibration Pre High Cylinder ID CC126112-CO CC126112-

CO

CC126112-

CO

Calibration Pre High Cylinder Instrument Response 950.4 981.3 974 968.567

Calibration Pre High Cylinder Bias -0.06 1.47 1.11 0.840

Calibration Pre High Cylinder Drift 0 0 0 0.000

Calibration Post Zero Cylinder ID Nitrogen Nitrogen Nitrogen

Calibration Post Zero Cylinder Instrument Response 0.6 2 0.1 0.900

Calibration Post Zero Cylinder Bias 0.03 0.1 0 0.043

Calibration Post Zero Cylinder Drift 0.03 0.2 0.1 0.110

Calibration Post High Cylinder ID CC126112-CO CC126112-

CO

CC126112-

CO

Calibration Post High Cylinder Instrument Response 981.3 974 960.8 972.033

Calibration Post High Cylinder Bias 1.47 1.11 0.45 1.010

Calibration Post High Cylinder Drift 1.53 0.36 0.66 0.850

Cavg 1581.7 1093.1 696.4 1,123.733

Cavg Units ppmvd ppmvd ppmvd

Cgas 1604.4114 1095.7555 704.8842 1,135.017

Cgas Units ppmvd ppmvd ppmvd

Fuel Type Coal - 

Bituminous

Coal - 

Bituminous

Coal - 

Bituminous

Fw 10640 10640 10640 10,640.000

Fc 1800 1800 1800 1,800.000

Cgasw 0 0 0 0.000

Cgasw Units

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

8/11/2010

Location Stack Exit - Method 25A

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Thursday, February 10, 2011 Page 12 of 14
Information Collection Request, TEP - Springerville Generation Station Unit 2

8/11/2010

Location Stack Exit - Method 3A CO2

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Thursday, February 10, 2011 Page 13 of 14
Information Collection Request, TEP - Springerville Generation Station Unit 2

8/11/2010

Location Stack Exit - Method 3A O2

Average

Run Number

Test Date

Run Start Time

Run Finish Time

Carbon Dioxide, %

Oxygen, %

Fuel Factor

Dry Volumetric Flow Rate, dry scfm

F-Factor, dscfm/MMBtu @ %O2

Moisture, %

Analyzer Make

Analyzer Model

Analyzer Serial Number

Operating Range

Operating Units

No. Readings/Avg.

Calibration Set

Calibration Pre Zero Cylinder ID

Calibration Pre Zero Cylinder Instrument Response

Calibration Pre Zero Cylinder Bias

Calibration Pre Zero Cylinder Drift

Calibration Pre High Cylinder ID

Calibration Pre High Cylinder Instrument Response

Calibration Pre High Cylinder Bias

Calibration Pre High Cylinder Drift

Calibration Post Zero Cylinder ID

Calibration Post Zero Cylinder Instrument Response

Calibration Post Zero Cylinder Bias

Calibration Post Zero Cylinder Drift

Calibration Post High Cylinder ID

Calibration Post High Cylinder Instrument Response

Calibration Post High Cylinder Bias

Calibration Post High Cylinder Drift

Cavg

Cavg Units

Cgas

Cgas Units

Fuel Type

Fw

Fc

Cgasw

Cgasw Units

Thursday, February 10, 2011 Page 14 of 14