EMISSIONS TEST REPORT 

BIG BEND STATION 

FACILITY ID NUMBER: 0570039 

EMISSION UNIT ID NO: -001 

BOILER NO. 1 

PARTICULATE MATTER, SULFUR DIOXIDE, 

AND, 

VISIBLE EMISSIONS EVALUATION 

February 25, 2009 

Prepared For: 

Tampa Electric Company 

Big Bend Power Station 

P.O. Box 111 

Tampa, Florida 33601-0111 

Prepared By: 

Tampa Electric Company 

Environmental, Health, & Safety 

Air Services Group 

Environmental, Health, & Safety 

Air Services Group 

5010 Causeway Boulevard 

Tampa, Florida 33619- 6130 
REPORT CERTIFICATION 

 The sampling and subsequent data entry/reduction detailed in this report 

was conducted at my direction, and I hereby certify that this test report is 

authentic and accurate to the best of my knowledge. 

Signature:__________________________ 

Scott E. Given 

Environmental Technician 

Test Team Lead 

Air Services Group 

Environmental Health & Safety 

Tampa Electric Company 

 I have reviewed the test performance, associated quality assurance 

activities, the resultant calculations, and the contents of this report, and certify 

that all project quality objectives have been met. This report is approved for 

submittal. 

Signature:__________________________ 

Raymond A. McDarby, Jr. 

Senior Environmental Technician 

Quality Assurance/Quality Control Specialist 

Air Services Group 

Environmental Health & Safety 

Tampa Electric Company 

 I have reviewed the testing details and results submitted in this report, 

and hereby certify that this test report is authentic and accurate to the best of 

my knowledge. 

Signature:__________________________ 

David A. Smith, QSTI 

Coordinator – Air Services Group 

Environmental Health & Safety 

Tampa Electric Company 
TABLE OF CONTENTS

SECTION PAGE NO.

1.0 SUMMARY OF RESULTS 1 

2.0 SOURCE DESCRIPTION/TEST PROCEDURES 3 

3.0 TEST RESULTS 

PARTICULATE MATTER TEST SUMMARY 6 

SULFUR DIOXIDE INFORMATION SUMMARY 7 

OPACITY DATA - SOOT BLOWING CONDITIONS SUMMARY 8 

OPACITY DATA – NON SOOT BLOWING CONDITIONS SUMMARY 9 

HEAT INPUT CALCULATIONS 10 

4.0 FIGURES 

FIGURE 1 SAMPLING LOCATION DIAGRAM 12 

APPENDICES

A. PARTICULATE MATTER CALCULATIONS

B. PARTICULATE MATTER LABORATORY ANALYTICAL DATA

C. BOILER/PRECIPITATOR OPERATIONAL DATA

D. PLANT CEMS DAHS PRINTOUTS

E. FUEL ANALYSIS

F. FIELD DATA SHEETS

G. SAMPLING EQUIPMENT CALIBRATIONS

H. CHAIN OF CUSTODY

I. TEST PARTICIPANTS
1.0 INTRODUCTION

On February 25, 2009, Tampa Electric Company’s Environmental Services, Air 

Services Group, performed source emission tests at the Big Bend Station, Boiler 

No. 1, emissions unit I.D.# -001. Testing was conducted according to 

procedures stipulated by the Florida Department of Environmental Protection 

(FDEP) for fossil fuel steam generators, and requirements in Title V Permit # 

0570039-028-AV. 

1 
2.0 DISCUSSION OF RESULTS

The particulate matter emission rate was derived by performing three USEPA 

Reference Method 5-B test runs (one soot blowing, two non soot blowing). The 

average of the three test runs was 0.02 lb/mmBtu. The FDEP permitted 

emission rate under non-soot blowing conditions is 0.03 lb/mmBtu. 

The Sulfur Dioxide (SO2) emission rate was determined using data provided by 

the Continuous Emissions Monitoring System’s (CEMS), Data Acquisition and 

Handing System (DAHS). The average emission rate for the test period was 

determined to be 0.1 lb/mmBtu, and 487 lbs/hr. The FDEP allowable emission 

rate is 6.5 lbs/mmBtu based on a two hour average, and 3310 lbs/hr based on 

scenario 3 as listed in condition A.9 of the permit. 

Visible emissions were evaluated using a United Sciences, Incorporated, Model 

500C transmissometer (S/N 5001688), during both soot blowing and non-soot 

blowing testing. The 1-hour average opacity under soot blowing conditions was 

7.0%. The 1-hour average opacity under non-soot blowing conditions was 6.7%. 

The FDEP allowable emission rate is 20 percent opacity. 

During the test performed on February 25, 2009, Boiler No. 1 was operated at an 

average heat input rate of 4001 mmBtu/hr and an average load of 398 

megawatts. The average quantity of fuel burned was 168.8 tons per hour. 

2 
3.0 SOURCE DESCRIPTION/TEST PROCEDURES

Big Bend Station is located on Big Bend Road, Ruskin, Florida at UTM 

coordinates East 361.9 North 3075.0. The Boiler No. 1 particulate matter 

sampling location consists of a shared circular stack 29.83 feet in diameter with 

four sample ports located 90 degrees apart on the stack circumference. These 

ports are located downstream of the electrostatic precipitator and the FGD 

scrubber. The sampling ports were determined to be 8.77 diameters 

downstream of the transition ductwork and 2.43 diameters upstream of the stack 

exit. Using these criteria, a total of 12 sampling points were chosen for 

particulate sampling as stipulated in the USEPA Method 1 test procedure. During 

this test, Boiler No. 2 was not operating, and was isolated from the FGD module. 

A diagram of the stack sampling location is included in Figure 1 along with other 

pertinent information on the test site. 

Boiler No. 1 is serviced by an electrostatic precipitator for the control of flyash 

emissions, and a flue gas desulfurization (FGD) system for control of sulfur 

dioxide emissions. 

During the test the boiler was fired with a solid fuel matrix comprised of 88% coal 

and 12% petroleum coke. 

Particulate sampling was performed according to USEPA Method 5B 

"Determination of Nonsulfuric Acid Particulate Matter from Stationary Sources" 

Diluent gas sampling and analysis was performed according to USEPA Method 3 

"Gas Analysis for Determination of Emission Rate Correction Factor, or Excess 

Air”. Gas analysis was performed on-site using an Orsat analyzer. 

Sulfur Dioxide (SO2) and Carbon Dioxide (CO2) data were provided by the 

Continuous Emissions Monitoring System (CEMS), Data Acquisition and 

3 
Handling System (DAHS). Averages were derived from the time frame of 10:03 

through 14:27 on February 25, 2009. This data is included as Appendix B of this 

report. 

Visible emissions were assessed using the installed Continuous Opacity Monitor 

(COM), and the CEMS DAHS. 

4 
4.0 TABULATED RESULTS

5 
Environmental Services

Air Services Group

Customer: Tampa Electric Company

Facility: Big Bend Station

Sampling Location: CS0W1 - Common Stack 1 - Wet

Unit Under Test: Boiler #1

Test Date:

Operating Conditions: Non-Soot Blowing and Soot Blowing

Run 1 Run 2 Run 1s Test Average

Vm(std), scf 36.505 35.687 35.926 36.040

Bws, ratio 0.151 0.156 0.154 0.154

Md, lb/lb - mole 30.2 30.2 30.2 30.2

Ms, lb/lb - mole 28.4 28.3 28.3 28.3

Qs, acf/min 746044.67 731976.76 729258.02 735759.8

Qs(std), dscf/min 564799.94 553143.6 551308.58 556417.4

I, % 100.6 100.4 101.5 100.8

C, lbs/dscf 1.703E-06 1.767E-06 1.531E-06 1.67E-06

EM, lbs/hr 57.7 58.6 50.6 55.7

ER, lbs/MMBtu 0.025 0.026 0.023 0.02

Wednesday, February 25, 2009

6 
BIG BEND STATION

SULFUR DIOXIDE DATA FROM CEMs

Test Period Information

Start Time 10:03:00 Eastern Standard Time (EST)

Stop Time 14:27:00 Eastern Standard Time (EST)

Total Time 4:24:00

Corresponding to the time frame for the PM test.

Sulfur Dioxide Data:

RM - 19

SO2 CO2 SO2 SO2

ppmvw %, wet lb/mmBtu lbs/hr

49.7 12.2 0.1 487

Calculation Details

SO2, lb/mmBtu = SO2, ppmvw x Cf x Fc x (100 / CO2 %, wet)

where:

Cf = 1.664E-07 (lb/scf)/ppm SO2

Fc = 1800 scf/mmBtu

SO2, lbs/hr = SO2, lb/mmBtu x Heat Input, mmBtu/hr

where:

Heat Input = 3976 mmBtu/hr, from Heat Input Calculation

Unit #1

WET-BOTTOM UTILITY BOILER

February 25, 2009

CEM DATA

7 
BIG BEND STATION

VISIBLE EMISSIONS DATA FROM OPACITY MONITOR

Record# DATE TIME OPACITY1 Record# DATE TIME OPACITY1

1 2/25/09 11:40 6.000 31 2/25/09 12:10 6.300

2 2/25/09 11:41 6.100 32 2/25/09 12:11 6.700

3 2/25/09 11:42 5.900 33 2/25/09 12:12 5.400

4 2/25/09 11:43 5.700 34 2/25/09 12:13 6.300

5 2/25/09 11:44 6.000 35 2/25/09 12:14 5.800

6 2/25/09 11:45 6.000 36 2/25/09 12:15 7.200

7 2/25/09 11:46 4.700 37 2/25/09 12:16 5.900

8 2/25/09 11:47 5.300 38 2/25/09 12:17 7.600

9 2/25/09 11:48 9.500 39 2/25/09 12:18 6.600

10 2/25/09 11:49 6.600 40 2/25/09 12:19 6.000

11 2/25/09 11:50 6.400 41 2/25/09 12:20 6.600

12 2/25/09 11:51 7.200 42 2/25/09 12:21 6.300

13 2/25/09 11:52 5.600 43 2/25/09 12:22 6.200

14 2/25/09 11:53 6.500 44 2/25/09 12:23 6.500

15 2/25/09 11:54 6.300 45 2/25/09 12:24 5.800

16 2/25/09 11:55 6.900 46 2/25/09 12:25 5.100

17 2/25/09 11:56 6.900 47 2/25/09 12:26 6.400

18 2/25/09 11:57 6.100 48 2/25/09 12:27 5.500

19 2/25/09 11:58 5.000 49 2/25/09 12:28 5.900

20 2/25/09 11:59 5.800 50 2/25/09 12:29 5.800

21 2/25/09 12:00 5.300 51 2/25/09 12:30 6.800

22 2/25/09 12:01 5.300 52 2/25/09 12:31 5.800

23 2/25/09 12:02 5.700 53 2/25/09 12:32 5.900

24 2/25/09 12:03 5.700 54 2/25/09 12:33 6.000

25 2/25/09 12:04 5.900 55 2/25/09 12:34 5.800

26 2/25/09 12:05 5.800 56 2/25/09 12:35 6.300

27 2/25/09 12:06 5.800 57 2/25/09 12:36 6.500

28 2/25/09 12:07 7.300 58 2/25/09 12:37 5.600

29 2/25/09 12:08 6.700 59 2/25/09 12:38 5.600

30 2/25/09 12:09 7.000 60 2/25/09 12:39 6.400

Test Average: 6.160 %

Minimum One Minute Average: 4.700 %

Maximum One Minute Average: 9.500 %

Maximum Six Minute Average: 6.967 %

Unit #1

WET BOTTOM UTILITY BOILER

SOOTBLOWING CONDITIONS

8 
BIG BEND STATION

VISIBLE EMISSIONS DATA FROM OPACITY MONITOR

Record# DATE TIME OPACITY1 Record# DATE TIME OPACITY1

1 2/25/09 10:03 5.500 31 2/25/09 10:33 5.700

2 2/25/09 10:04 5.800 32 2/25/09 10:34 7.400

3 2/25/09 10:05 5.400 33 2/25/09 10:35 6.300

4 2/25/09 10:06 8.900 34 2/25/09 10:36 6.300

5 2/25/09 10:07 7.100 35 2/25/09 10:37 5.900

6 2/25/09 10:08 6.400 36 2/25/09 10:38 6.400

7 2/25/09 10:09 5.900 37 2/25/09 10:39 6.700

8 2/25/09 10:10 5.700 38 2/25/09 10:40 7.400

9 2/25/09 10:11 6.300 39 2/25/09 10:41 5.500

10 2/25/09 10:12 5.700 40 2/25/09 10:42 5.800

11 2/25/09 10:13 6.200 41 2/25/09 10:43 6.000

12 2/25/09 10:14 7.800 42 2/25/09 10:44 5.700

13 2/25/09 10:15 5.600 43 2/25/09 10:45 6.100

14 2/25/09 10:16 5.900 44 2/25/09 10:46 5.500

15 2/25/09 10:17 6.500 45 2/25/09 10:47 6.800

16 2/25/09 10:18 5.800 46 2/25/09 10:48 6.100

17 2/25/09 10:19 5.800 47 2/25/09 10:49 6.000

18 2/25/09 10:20 5.300 48 2/25/09 10:50 6.300

19 2/25/09 10:21 6.700 49 2/25/09 10:51 7.700

20 2/25/09 10:22 5.000 50 2/25/09 10:52 6.700

21 2/25/09 10:23 5.500 51 2/25/09 10:53 6.500

22 2/25/09 10:24 6.300 52 2/25/09 10:54 6.600

23 2/25/09 10:25 6.400 53 2/25/09 10:55 5.300

24 2/25/09 10:26 6.400 54 2/25/09 10:56 5.400

25 2/25/09 10:27 6.900 55 2/25/09 10:57 4.700

26 2/25/09 10:28 5.800 56 2/25/09 10:58 5.200

27 2/25/09 10:29 6.100 57 2/25/09 10:59 5.900

28 2/25/09 10:30 6.400 58 2/25/09 11:00 6.700

29 2/25/09 10:31 5.900 59 2/25/09 11:01 9.000

30 2/25/09 10:32 5.900 60 2/25/09 11:02 7.600

Test Average: 6.235 %

Minimum One Minute Average: 4.700 %

Maximum One Minute Average: 9.000 %

Maximum Six Minute Average: 6.717 %

Unit #1

WET BOTTOM UTILITY BOILER

NON-SOOTBLOWING CONDITIONS

9 
BIG BEND GENERATING STATION

HEAT INPUT CALCULATIONS

Gross Heat Rate, Previous Month (January): 10046 KMBtu/MWh

1.0046E+07 MMBtu/MWh

Test Time Information

Testing Start Time: 10:03

Testing End Time: 14:27

Total Test Time: 4.4 hours

Calculated Heat Input

Average Unit Load, MW = MWh / hours: 398.3 MW

Heat Input, MMBtu/h = MMBtu/MWh x MW: 4001.2 mmBtu/hr

Fuel Consumption Calculation

Laboratory Sample ID: AA99889

Btu as received: 11849 Btu/lb

Tons of Fuel Consumed, Tons/hr = (mmBtu/h / Btu/lb) x 500: 168.8 Tons/hour

Unit #1

February 25, 2009

WET-BOTTOM UTILTIY BOILER

10 
5.0 FIGURES

11 
FIGURE 1

EXHAUST STACK

426.5 ’ EL.

BIG BEND GENERATING STATION

BOILERS 1 and 2

PARTICULATE TRAVERSE POINTS

OUTLET

N

PORT LOCATION PLAN

REVISED 1-18-00

COMMON STACK1 - WET TEST LOCATION

STACK DIAMETERS DOWNSTREAM

FROM DISTURBANCE = 8.77

STACK DIAMETERS UPSTREAM

FROM DISTURBANCE = 2.43

STACK DIAMETER = 29.8333 FT. ID.

STACK AREA = 699.0246 SQ. FT.

PORT LENGTH’S = 62 IN.

TRAVERSE

 POINT 

 1

 2

 3

 

 % OF

STACK DIAMETER

 IN. FROM

STACK WALL

 4.4%

14.6%

29.6%

 15.75 IN.

 52.26 IN.

105.96 IN.

 

499 ’ EL.

165 ’ EL.

261.5 ’

FGD

PRESSURIZED

 ANNULUS

72.5 ’

 

A

B C

D

9 ’ EL.

12 
APPENDIX A

PARTICULATE MATTER CALCULATIONS 
Environmental Services

Air Services Group

40 CFR 60, Appendix A - Test Methods

Reference Method 5/17

Particulate Test Calculations

Customer: Tampa Electric Company

Facility: Big Bend Station

Sampling Location: CS0W1 - Common Stack 1 - Wet

Unit Under Test: Boiler #1

Operating Conditions: Non-Soot Blowing

Run Number: 1

Date: 02/25/09

Sample Time, θ: 60 minutes Nozzle Diameter, Dn: 0.298 inches

Barometric Pressure, Pb: 29.70 "Hg Nozzle Area, An: 0.000484 ft2

Stack Pressure, Ps: 29.69 "Hg Average Orifice Meter, ΔH: 1.330 "H2O

Effective Stack Area, As: 452.389 ft2 Sample Volume, Vm: 38.205 ft3

Pitot Coefficient, Cp: 0.84 dimensionless Average Meter Temp., Tm: 80.4 o

F

Gas Analysis: 12.0 % CO2 Average Stack Temp., Ts: 127.6 o

F

7.0 % O2 Average √Δp: 0.458 "H2O

0.0 % CO Condensate Volume, Vlc: 138.0 ml

81.0 % N2 Meter Box Y: 0.982 dimensionless

F-factor, Fd, for fuel: 9780 dscf/MMBtu

Data Calculated from Source Measurements:

Vw(std) = 4.707E-02 x Vlc 6.496 scf

Vm(std) = 17.647 x Vm x Y x (Pb + (ΔH / 13.6)) / (Tm +460) 36.505 dscf

Bws = Vw(std) / (Vm(std) + Vw(std)) 0.151 %

FDA = 1.0 - Bws 0.849 %

Md = (0.44 x %CO2) + (0.32 x %O2) + (0.28 x (%N2 + % CO)) 30.20 lb./lb. mole

Ms = (Md x FDA) + (18.0 x Bws) 28.36 lb./lb. mole

vs = 85.49 x Cp x (√Δp) x (√(Ts + 460) / (Ms x Ps)) 27.49 ft/second

Qs = vs x As x 60 746044.7 acf/minute

Qs(std) = Qs x FDA x (528 / (Ts + 460)) x (Ps / 29.92)) 564799.9 dscf/minute

I = (Ts + 460) x ((2.67E-03 x Vlc) + (Vm(std) / 17.647)) x 100 / (θ x Ps x An x vs x 60) 100.6 %

Data from Laboratory Analysis:

Total Particulate Weight From Laboratory Analysis: 0.028200 grams

Calculated Concentration and Emission Rate Data:

cs = (15.432 x grams) / Vm(std) 0.012 grains/dscf

grains/acf = cs x 17.647 x Ps x (FDA / (Ts + 460) 0.009 grains/acf

C = cs / 7000 1.703E-06 lbs/dscf

EM = C x Qs(std) x 60 57.7 lbs/hr

ER = C x Fd x (20.9 /(20.9 - %O2) 0.025 lbs/MMBtu
Environmental Services

Air Services Group

40 CFR 60, Appendix A - Test Methods

Reference Method 5/17

Particulate Test Calculations

Customer: Tampa Electric Company

Facility: Big Bend Station

Sampling Location: CS0W1 - Common Stack 1 - Wet

Unit Under Test: Boiler #1

Operating Conditions: Non-Soot Blowing

Run Number: 2

Date: 02/25/09

Sample Time, θ: 60 minutes Nozzle Diameter, Dn: 0.298 inches

Barometric Pressure, Pb: 29.81 "Hg Nozzle Area, An: 0.000484 ft2

Stack Pressure, Ps: 29.80 "Hg Average Orifice Meter, ΔH: 1.287 "H2O

Effective Stack Area, As: 452.389 ft2 Sample Volume, Vm: 37.347 ft3

Pitot Coefficient, Cp: 0.84 dimensionless Average Meter Temp., Tm: 82.3 o

F

Gas Analysis: 12.0 % CO2 Average Stack Temp., Ts: 127.4 o

F

7.0 % O2 Average √Δp: 0.450 "H2O

0.0 % CO Condensate Volume, Vlc: 140.1 ml

81.0 % N2 Meter Box Y: 0.982 dimensionless

F-factor, Fd, for fuel: 9780 dscf/MMBtu

Data Calculated from Source Measurements:

Vw(std) = 4.707E-02 x Vlc 6.595 scf

Vm(std) = 17.647 x Vm x Y x (Pb + (ΔH / 13.6)) / (Tm +460) 35.687 dscf

Bws = Vw(std) / (Vm(std) + Vw(std)) 0.156 %

FDA = 1.0 - Bws 0.844 %

Md = (0.44 x %CO2) + (0.32 x %O2) + (0.28 x (%N2 + % CO)) 30.20 lb./lb. mole

Ms = (Md x FDA) + (18.0 x Bws) 28.30 lb./lb. mole

vs = 85.49 x Cp x (√Δp) x (√(Ts + 460) / (Ms x Ps)) 26.97 ft/second

Qs = vs x As x 60 731976.8 acf/minute

Qs(std) = Qs x FDA x (528 / (Ts + 460)) x (Ps / 29.92)) 553143.6 dscf/minute

I = (Ts + 460) x ((2.67E-03 x Vlc) + (Vm(std) / 17.647)) x 100 / (θ x Ps x An x vs x 60) 100.4 %

Data from Laboratory Analysis:

Total Particulate Weight From Laboratory Analysis: 0.028600 grams

Calculated Concentration and Emission Rate Data:

cs = (15.432 x grams) / Vm(std) 0.012 grains/dscf

grains/acf = cs x 17.647 x Ps x (FDA / (Ts + 460) 0.009 grains/acf

C = cs / 7000 1.767E-06 lbs/dscf

EM = C x Qs(std) x 60 58.6 lbs/hr

ER = C x Fd x (20.9 /(20.9 - %O2) 0.026 lbs/MMBtu
Environmental Services

Air Services Group

40 CFR 60, Appendix A - Test Methods

Reference Method 5/17

Particulate Test Calculations

Customer: Tampa Electric Company

Facility: Big Bend Station

Sampling Location: CS0W1 - Common Stack 1 - Wet

Unit Under Test: Boiler #1

Operating Conditions: Soot Blowing

Run Number: 1s

Date: 02/25/09

Sample Time, θ: 60 minutes Nozzle Diameter, Dn: 0.298 inches

Barometric Pressure, Pb: 29.80 "Hg Nozzle Area, An: 0.000484 ft2

Stack Pressure, Ps: 29.79 "Hg Average Orifice Meter, ΔH: 1.280 "H2O

Effective Stack Area, As: 452.389 ft2 Sample Volume, Vm: 37.738 ft3

Pitot Coefficient, Cp: 0.84 dimensionless Average Meter Temp., Tm: 84.2 o

F

Gas Analysis: 12.0 % CO2 Average Stack Temp., Ts: 128.0 o

F

7.0 % O2 Average √Δp: 0.448 "H2O

0.0 % CO Condensate Volume, Vlc: 139.4 ml

81.0 % N2 Meter Box Y: 0.982 dimensionless

F-factor, Fd, for fuel: 9780 dscf/MMBtu

Data Calculated from Source Measurements:

Vw(std) = 4.707E-02 x Vlc 6.562 scf

Vm(std) = 17.647 x Vm x Y x (Pb + (ΔH / 13.6)) / (Tm +460) 35.926 dscf

Bws = Vw(std) / (Vm(std) + Vw(std)) 0.154 %

FDA = 1.0 - Bws 0.846 %

Md = (0.44 x %CO2) + (0.32 x %O2) + (0.28 x (%N2 + % CO)) 30.20 lb./lb. mole

Ms = (Md x FDA) + (18.0 x Bws) 28.32 lb./lb. mole

vs = 85.49 x Cp x (√Δp) x (√(Ts + 460) / (Ms x Ps)) 26.87 ft/second

Qs = vs x As x 60 729258.0 acf/minute

Qs(std) = Qs x FDA x (528 / (Ts + 460)) x (Ps / 29.92)) 551308.6 dscf/minute

I = (Ts + 460) x ((2.67E-03 x Vlc) + (Vm(std) / 17.647)) x 100 / (θ x Ps x An x vs x 60) 101.5 %

Data from Laboratory Analysis:

Total Particulate Weight From Laboratory Analysis: 0.024950 grams

Calculated Concentration and Emission Rate Data:

cs = (15.432 x grams) / Vm(std) 0.011 grains/dscf

grains/acf = cs x 17.647 x Ps x (FDA / (Ts + 460) 0.008 grains/acf

C = cs / 7000 1.531E-06 lbs/dscf

EM = C x Qs(std) x 60 50.6 lbs/hr

ER = C x Fd x (20.9 /(20.9 - %O2) 0.023 lbs/MMBtu
APPENDIX B

PARTICULATE MATTER LABORATORY ANALYTICAL DATA 
Customer Air Services Plant Big Bend Unit 1

Method EPA 5B Stack Test Completion Date 02/25/2009Analyst Sam Soth/Peggy Penner/Rory Lacey Sample Number

ACETONE BEAKER 1st weighing Date 03/02/2009 Time 14:45 % RH 34.5%

2nd weighing Date 03/03/2009 Time 9:55 % RH 35.0%

3rd weighing Date 03/03/2009 Time 16:00 % RH 33.0%

4th weighing Date 03/04/2009 Time 10:30 % RH 36.0%

***Blank*** Run 1 Run 2 Run 3 Run 1S Run 2S Run 3S

Acetone Container ID AIR3A AIR9A AIRII AIR 6A

Acetone Rinse Vol.(Va), mls 200.0000 200 200 Enter Container ID 200 Enter Container ID Enter Container ID

1st Gross Wt., grams 106.8757 104.6739 111.7003 106.3699

2nd Gross Wt., grams 106.8759 104.6728 111.6994 106.3692 

3rd Gross Wt., grams 104.6735 111.6994 106.3693

4th Gross Wt., grams 104.6731

Avg. Gross Wt., grams 106.87580 104.67330 111.69940 Enter Gross Wts. 106.36925 Enter Gross Wts. Enter Gross Wts.

Tare Wt., grams 106.87495 104.66360 111.68715 106.36255

Acetone Blank Wt., mg 0.85 0.85 0.85 0.85

Acetone Particulate Wt., mg 8.85 11.40 5.85

Acetone Residue, mg/g 0.0054

Acetone Blank Criteria

 FILTER 1st weighing Date 03/02/2009 Time 14:45 % RH 34.5%

 Date 03/03/2009 Time 9:55 % RH 35.0%

3rd weighing Date 03/03/2009 Time 16:00 % RH 33.0%

4th weighing Date Time % RH

Filter/Thimble ID 203145 203139 203144 203143

1st Gross Wt., grams 0.2508 0.2683 0.2675 0.2692

2nd Gross Wt., grams 0.2507 0.2675 0.2671 0.2693

3rd Gross Wt., grams 0.2671

4th Gross Wt., grams

Avg. Gross Wt., grams 0.25075 0.26730 0.26730 Enter Gross Wts. 0.26925 Enter Gross Wts. Enter Gross Wts.

Tare Wt., grams 0.25035 0.24795 0.25010 0.25015

Filter Particulate Wt., mg 19.35 17.20 19.10

Difference, milligrams 0.4

Total Sample Particulate Wt., mg 28.20 28.60 24.95

OK to subtract acetone blank

Start Here
APPENDIX C

BOILER/PRECIPITATOR OPERATIONAL DATA


APPENDIX D

PLANT CEMS DAHS PRINTOUTS
CEM Data

Date Time SO21 CO21

02/25/2009 10:03 48.7 12.1

02/25/2009 10:04 48.9 12.1

02/25/2009 10:05 48 12

02/25/2009 10:06 51.1 12.1

02/25/2009 10:07 50.9 12.1

02/25/2009 10:08 49.3 12.1

02/25/2009 10:09 49.8 12

02/25/2009 10:10 51.1 12

02/25/2009 10:11 50.7 12.1

02/25/2009 10:12 51 12.1

02/25/2009 10:13 51 12.1

02/25/2009 10:14 49.4 12

02/25/2009 10:15 49.6 12.1

02/25/2009 10:16 47.4 12

02/25/2009 10:17 45.3 12

02/25/2009 10:18 46.5 12.1

02/25/2009 10:19 46.8 12

02/25/2009 10:20 46.4 12

02/25/2009 10:21 48.4 12.1

02/25/2009 10:22 47.4 12.1

02/25/2009 10:23 44.7 12.1

02/25/2009 10:24 48.2 12.1

02/25/2009 10:25 49.1 12.1

02/25/2009 10:26 48.7 12.1

02/25/2009 10:27 49.8 12.1

02/25/2009 10:28 50.5 12.1

02/25/2009 10:29 49 12.1

02/25/2009 10:30 50.5 12.1

02/25/2009 10:31 51.6 12.1

02/25/2009 10:32 51.6 12.1

02/25/2009 10:33 48.8 12.1

02/25/2009 10:34 49.1 12.1

02/25/2009 10:35 49 12.2

02/25/2009 10:36 47.6 12.1

02/25/2009 10:37 49.2 12.1

02/25/2009 10:38 48.9 12.1

02/25/2009 10:39 49.6 12.1

02/25/2009 10:40 49.7 12.1

02/25/2009 10:41 49.2 12.1

02/25/2009 10:42 49.5 12.1

Page 1 of 6
CEM Data

Date Time SO21 CO21

02/25/2009 10:43 50 12.1

02/25/2009 10:44 50.8 12.1

02/25/2009 10:45 51.2 12.1

02/25/2009 10:46 52.1 12.1

02/25/2009 10:47 51.4 12.1

02/25/2009 10:48 50.7 12.1

02/25/2009 10:49 49.1 12.1

02/25/2009 10:50 45.8 12.1

02/25/2009 10:51 46.7 12.1

02/25/2009 10:52 47.1 12.1

02/25/2009 10:53 47.8 12.1

02/25/2009 10:54 47.7 12.1

02/25/2009 10:55 48.3 12.1

02/25/2009 10:56 48.3 12.1

02/25/2009 10:57 49.2 12.1

02/25/2009 10:58 49.7 12.1

02/25/2009 10:59 49.9 12.2

02/25/2009 11:00 49.7 12.2

02/25/2009 11:01 50.4 12.1

02/25/2009 11:02 49.4 12.1

02/25/2009 11:03 51 12.1

02/25/2009 11:04 52.2 12.1

02/25/2009 11:05 51.9 12.2

02/25/2009 11:06 50.9 12.2

02/25/2009 11:07 49 12.1

02/25/2009 11:08 47.5 12.1

02/25/2009 11:09 47.7 12.1

02/25/2009 11:10 48.8 12.1

02/25/2009 11:11 47.9 12.1

02/25/2009 11:12 48.5 12.1

02/25/2009 11:13 49.6 12.1

02/25/2009 11:14 50.1 12.2

02/25/2009 11:15 51.2 12.1

02/25/2009 11:16 50.4 12.1

02/25/2009 11:17 50.2 12.1

02/25/2009 11:18 52.1 12.1

02/25/2009 11:19 52.2 12.1

02/25/2009 11:20 48.6 12.1

02/25/2009 11:21 50.8 12.1

02/25/2009 11:22 50.2 12.1

Page 2 of 6
CEM Data

Date Time SO21 CO21

02/25/2009 11:23 48.5 12.2

02/25/2009 11:24 47.8 12.2

02/25/2009 11:25 47.7 12.1

02/25/2009 11:26 47.3 12.1

02/25/2009 11:27 48.2 12.1

02/25/2009 11:28 48 12.1

02/25/2009 11:29 50.2 12.1

02/25/2009 11:30 50.2 12.1

02/25/2009 11:31 50.8 12.1

02/25/2009 11:32 51.3 12.1

02/25/2009 11:33 51.2 12.1

02/25/2009 11:34 51.2 12.1

02/25/2009 11:35 51 12.1

02/25/2009 11:36 51.9 12.1

02/25/2009 11:37 50.1 12.1

02/25/2009 11:38 48.3 12.1

02/25/2009 11:39 48.2 12.1

02/25/2009 11:40 48 12

02/25/2009 11:41 48 12.1

02/25/2009 11:42 49 12.1

02/25/2009 11:43 49.3 12.1

02/25/2009 11:44 48.5 12.1

02/25/2009 11:45 49.7 12

02/25/2009 11:46 49.8 12

02/25/2009 11:47 49.6 12.1

02/25/2009 11:48 52.5 12.2

02/25/2009 11:49 50.8 12.1

02/25/2009 11:50 52 12.1

02/25/2009 11:51 51.9 12

02/25/2009 11:52 53.4 12.2

02/25/2009 11:53 49.8 12.2

02/25/2009 11:54 47.4 12.1

02/25/2009 11:55 47.4 12.1

02/25/2009 11:56 47.4 12.1

02/25/2009 11:57 49.4 12.1

02/25/2009 11:58 49.8 12.2

02/25/2009 11:59 49.3 12.1

02/25/2009 12:00 49.8 12.1

02/25/2009 12:01 51.1 12.1

02/25/2009 12:02 50.8 12.1

Page 3 of 6
CEM Data

Date Time SO21 CO21

02/25/2009 12:03 50.7 12.1

02/25/2009 12:04 52.2 12.1

02/25/2009 12:05 51.9 12.1

02/25/2009 12:06 52.4 12.1

02/25/2009 12:07 54.2 12.2

02/25/2009 12:08 52 12.2

02/25/2009 12:09 51.5 12.2

02/25/2009 12:10 50.5 12.2

02/25/2009 12:11 48.7 12.2

02/25/2009 12:12 48.7 12.1

02/25/2009 12:13 49.9 12.1

02/25/2009 12:14 49.1 12.2

02/25/2009 12:15 50 12.2

02/25/2009 12:16 49.6 12.1

02/25/2009 12:17 46.2 12.1

02/25/2009 12:18 50.2 12.1

02/25/2009 12:19 51.3 12.1

02/25/2009 12:20 52.3 12.1

02/25/2009 12:21 52.9 12.1

02/25/2009 12:22 51.7 12.1

02/25/2009 12:23 50.5 12.1

02/25/2009 12:24 49.7 12.1

02/25/2009 12:25 49 12.1

02/25/2009 12:26 49.2 12.1

02/25/2009 12:27 48.8 12.1

02/25/2009 12:28 47.8 12.1

02/25/2009 12:29 48.8 12.1

02/25/2009 12:30 49.2 12.1

02/25/2009 12:31 49.4 12.1

02/25/2009 12:32 49.5 12.1

02/25/2009 12:33 50 12.1

02/25/2009 12:34 50.5 12.1

02/25/2009 12:35 50.9 12.1

02/25/2009 12:36 53.2 12.2

02/25/2009 12:37 52.5 12.1

02/25/2009 12:38 50.3 12.1

02/25/2009 12:39 50.5 12.2

02/25/2009 12:40 49.9 12.2

02/25/2009 12:41 46.8 12.2

02/25/2009 12:42 47.5 12.2

Page 4 of 6
CEM Data

Date Time SO21 CO21

02/25/2009 13:31 49.3 12.3

02/25/2009 13:32 46.8 12.2

02/25/2009 13:33 49.4 12.2

02/25/2009 13:34 51 12.3

02/25/2009 13:35 49.8 12.2

02/25/2009 13:36 50.8 12.3

02/25/2009 13:37 50.5 12.2

02/25/2009 13:38 50.9 12.2

02/25/2009 13:39 52.6 12.2

02/25/2009 13:40 52.3 12.2

02/25/2009 13:41 50.2 12.3

02/25/2009 13:42 49.2 12.2

02/25/2009 13:43 49 12.2

02/25/2009 13:44 48.6 12.2

02/25/2009 13:45 48.1 12.2

02/25/2009 13:46 48.6 12.3

02/25/2009 13:47 48.3 12.3

02/25/2009 13:48 49.2 12.2

02/25/2009 13:49 50 12.2

02/25/2009 13:50 50.4 12.3

02/25/2009 13:51 50.8 12.2

02/25/2009 13:52 50.5 12.2

02/25/2009 13:53 52 12.2

02/25/2009 13:54 53.5 12.2

02/25/2009 13:55 51.9 12.2

02/25/2009 13:56 52.3 12.2

02/25/2009 13:57 49.8 12.2

02/25/2009 13:58 49.1 12.1

02/25/2009 13:59 48.2 12.2

02/25/2009 14:00 48.5 12.1

02/25/2009 14:01 48.2 12.1

02/25/2009 14:02 47.6 12.1

02/25/2009 14:03 48.2 12.1

02/25/2009 14:04 49.2 12.1

02/25/2009 14:05 49.2 12.1

02/25/2009 14:06 49.1 12.1

02/25/2009 14:07 50.6 12.1

02/25/2009 14:08 50.2 12.1

02/25/2009 14:09 50.9 12.1

02/25/2009 14:10 50.3 12.1

Page 5 of 6
CEM Data

Date Time SO21 CO21

02/25/2009 14:11 46.9 12.2

02/25/2009 14:12 48.5 12.2

02/25/2009 14:13 48 12.1

02/25/2009 14:14 48.5 12.2

02/25/2009 14:15 48.5 12.2

02/25/2009 14:16 47.6 12.1

02/25/2009 14:17 47.5 12.2

02/25/2009 14:18 50.3 12.3

02/25/2009 14:19 51.1 12.3

02/25/2009 14:20 51.4 12.2

02/25/2009 14:21 51.3 12.3

02/25/2009 14:22 52.2 12.3

02/25/2009 14:23 52.4 12.3

02/25/2009 14:24 52.5 12.4

02/25/2009 14:25 51 12.3

02/25/2009 14:26 50.1 12.3

02/25/2009 14:27 48.4 12.3

Averages: 49.68921 12.15021

Page 6 of 6
APPENDIX E

FUEL ANALYSIS 
Laboratory Services

5012 Causeway Blvd * Tampa Fl. 33619 * Ph (813)630-7378 * Fax (813)630-7360 * DOH #E54272

Report For:

Laboratory ID: AA99889

Date and Time Collected:

Sampled By:

Sample Information

Description: FRANK WADE

Location Code:

Report Date: 03/31/2009

Big Bend 1 Compliance

TE_BB_1_COMP_COAL

Project Account Code:

Sample Collection Method: Date of Sample Receipt: 03/04/2009

Laboratory Results

02/25/2009 3:45:00 PM

PARAMETER Result

Qualifier

Code

Test

Method Analyst Units

Upper

MDL Limit

Violation

Check

Analysis

Date & Time

Lower

Limit

60 Mesh Residual Moisture, Coal % ASTM D-5142 KAPXJ 3.51 03/13/2009 9:15:00 AM

Ash, as Determined % 0.01 ASTM D-5142 KAPXJ 8.66 03/13/2009 9:15:00 AM

Ash, as Received % 0.01 ASTM D-3174 KAPXJ 7.98 03/18/2009 10:39:00 AM

Ash, Dry Basis % 0.01 ASTM D-3174 KAPXJ 8.98 03/18/2009 10:39:00 AM

BTU in Coal, as Determined BTU/Lb. 1 ASTM D-5865 KAPXJ 12866 03/18/2009 10:08:00 AM

BTU, as Received BTU/Lb 100 ASTM D-5865 KAPXJ 11849 03/18/2009 12:56:00 PM

BTU, Dry Basis BTU/Lb. 100 ASTM D-5865 KAPXJ 13334 03/18/2009 12:56:00 PM

BTU, Moisture-Ash Free BTU/Lb. 100 ASTM D-5865 KAPXJ 14650 03/18/2009 12:56:00 PM

Calculated Heat Input, mmBtu/hr mmBtu/hr KARAM 4001 03/24/2009 10:09:00 AM

PM non-sootblowing, lbs/mmBtu lb/mmBtu EPA RM-5/17 KARAM 0.02 03/24/2009 10:09:00 AM

PM sootblowing, lbs/mmBtu lb/mmBtu EPA RM-5/17 KARAM 0.02 03/24/2009 10:09:00 AM

Pounds SO2 / Million BTU Lbs. 

SO2/MMBTU

4.92 Calculated KAPXJ 03/18/2009 12:56:00 PM

SO2 emission rate, lbs/hr lbs/hr EPA - RM6C KARAM 487 03/24/2009 10:09:00 AM

Sulfur in Coal, as Determined % 0.01 ASTM D-4239 KAEMD 3.33 03/09/2009 1:59:00 PM

Sulfur, as Received % 0.02 ASTM D-4239 KAPXJ 3.07 03/18/2009 10:39:00 AM

Sulfur, Dry Basis % 0.08 ASTM D-4239 KAPXJ 3.45 03/18/2009 10:39:00 AM

Total Moisture % 0.1 ASTM D-3173 KAPXJ 11.14 03/18/2009 10:39:00 AM

Comments

Ray McDarby,

Manager, Laboratory Services

All results calculated on a wet to wet basis, unless otherwise indicated.

Should there be any questions regarding this report, please contact:

(813) 630-7878

For Peggy Penner,

Report Number: Page 1 of 1 "General Report" AA99889-033109-14

All of the results presented in this report pertain to results for sample AA99889
APPENDIX F

FIELD DATA SHEETS 



APPENDIX G

SAMPLING EQUIPMENT CALIBRATIONS 
SUMMARY OF EQUIPMENT CALIBRATIONS

EQUIPMENT CAL DATE METHOD RESULTS

CONSOLE (MB 06)

INITIAL 02/11/2009 USEPA RM 5 0.982

POST TEST 02/27/2009 (ORIFICE) 0.997

NOZZLE (SN10)

INITIAL 02/23/2009 CALIPER 0.298

POST TEST 02/27/2009 MEASUREMENTS 0.297

PYROMETER (PY 10) 10/24/2008 ASTM THERMOMETER + 2o

 F

PITOT TUBE (PT 11) 10/24/2008 USEPA RM 2 Cp = 0.84

BAROMETER (BR 07) 02/23/2009 NWS COMPARISON + 0.01" Hg
Environmental Services

Air Services Group

Red Team

Manufacturer: Thermo Anderson Calibration Date:

Model Number:MST-C1 Barometric Pressure: 30.11 "Hg

Instrument Code Number: ^MB06 Theoretical Critical Vacuum: 14.20 "Hg

LabWorks Sample Number: Calibrated By:

Pump Code Number: P2

Initial Final Total

ΔH Time Volume Volume Volume Inlet Outlet Inlet Outlet

"H2O Minutes ft3 ft3 ft3

oF oF oF oF

0.65 15 903.100 909.957 6.857 65 71 68 73

1.20 15 911.500 920.654 9.154 68 74 68 74

2.00 15 890.600 902.315 11.715 63 71 62 71

3.80 15 923.500 939.455 15.955 57 71 60 72

Orifice K' Actual

Serial Orifice Vacuum Initial Final Average

Number Coefficient "Hg oF oF oF

48 0.3452 24.0 68 68 68.0

55 0.4596 22.0 68 68 68.0

63 0.5923 20.0 68 68 68.0

73 0.8106 68 68 68.0

Dry Gas Meter Calibration Calibration

Volume Volume Volume Y ΔHα

Corrected Corrected Nominal Value QA/QC Value QA/QC

Vm(std), ft3 Vcr(std), ft3 Vcr(std), ft3 (ratio) + 0.02 "H2O + 0.2

6.892 6.785 6.745 0.984 0.003 1.794 -0.070

9.183 9.034 8.980 0.984 0.002 1.862 -0.002

11.870 11.642 11.573 0.981 -0.001 1.884 0.019

16.291 15.933 15.839 0.978 -0.004 1.917 0.053

Averages: 0.982 1.864

Review/Approval:

USEPA Reference Method 5

Dry Gas Meter Calibration

Critical Orifice Method

Quarterly Calibration

02/11/2009

GDB

IMPORTANT

For valid test results, the Actual Vacuum should be 1 to 2 "Hg greater than the Theoretical Critical Vacuum Shown above.

The Critical Orifice Coefficient, K', should be in English units.

IMPORTANT

Dry Gas Meter Readings

Initial Temperatures Final Tempertures

For Calibration Y, the ratio of the reading of the calibration orifice to the dry gas meter, acceptable tolerance from average is + 0.02.

For Calibration ΔHα, the acceptable tolerance of individual values from the average is + 0.2.

13-Feb-09

Critical Orifice Readings

Ambient Temperatures

CALCULATED DATA

Critical Orifice
Environmental Services

Air Services Group

Manufacturer: Thermo Calibration Date:

Model Number:MST Barometric Pressure: 30.2 "Hg

Instrument Code Number: MB06 Theoretical Critical Vacuum: 14.25 "Hg

LabWorks Sample Number: Calibrated By:

Associated Test: Team: RED

Initial Final Total

ΔH Time Volume Volume Volume Inlet Outlet Inlet Outlet

"H2O Minutes ft3 ft3 ft3

oF oF oF oF

1.2 10 94.300 100.305 6.005 71 73 71 74

1.2 10 100.305 106.315 6.010 71 74 72 75

1.2 10 106.315 112.341 6.026 72 75 73 76

Orifice K' Actual

Serial Orifice Vacuum Initial Final Average

Number Coefficient "Hg oF oF oF

55 0.4596 21.0 74 74 74.0

55 0.4596 21.0 74 74 74.0

55 0.4596 21.0 74 74 74.0

Dry Gas Meter Calibration Calibration

Volume Volume Volume Y ΔHα

Corrected Corrected Nominal Value QA/QC Value QA/QC

Vm(std), ft3 Vcr(std), ft3 Vcr(std), ft3 (ratio) + 0.02 "H2O + 0.2

6.028 6.006 6.021 0.996 0.000 1.873 0.003

6.024 6.006 6.021 0.997 0.000 1.871 0.000

6.029 6.006 6.021 0.996 0.000 1.867 -0.003

Averages: 0.997 1.870

Prior Y: 0.982

% Difference:(+/-5%) -1.48% PASS

Review/Approval: Date:

BB #1

IMPORTANT

IMPORTANT

For valid test results, the Actual Vacuum should be 1 to 2 "Hg greater than the Theoretical Critical Vacuum Shown above.

The Critical Orifice Coefficient, K', should be in English units.

Ambient Temperatures

Dry Gas Meter Readings

Initial Temperatures Final Tempertures

Critical Orifice Readings

USEPA Reference Method 5

Dry Gas Meter Calibration

Critical Orifice Method

GDB

02/27/2009

POST - TEST CALIBRATION CHECK

2-Mar-09

CALCULATED DATA

For Calibration Y, the ratio of the reading of the calibration orifice to the dry gas meter, acceptable tolerance from average is + 0.02.

For Calibration ΔHα, the acceptable tolerance of individual values from the average is + 0.2.

Critical Orifice
Environmental Services

Air Services Group

Shared Resource

Calibration Date: Responsible Party:

Nozzle Maximum Average

I.D. D1 D2 D3 Difference, " Dn, inches

^SN01 0.291 0.294 0.298 0.003 0.116

^SN04 0.324 0.323 0.324 0.000 0.127

^SN05 0.382 0.383 0.379 0.002 0.150

^SN06 0.497 0.500 0.500 0.001 0.196

^SN09 0.693 0.699 0.693 0.002 0.274

^SN10 0.758 0.753 0.760 0.003 0.298

^SN12 0.984 0.982 0.986 0.002 0.387

^SN15 0.416 0.418 0.416 0.001 0.164

^SN16 0.505 0.504 0.505 0.000 0.199

^SN19 0.712 0.712 0.714 0.001 0.281

^SN22 0.937 0.937 0.941 0.002 0.369

^SN30 0.796 0.796 0.795 0.000 0.313

^SN36 0.475 0.476 0.477 0.001 0.187

^SN37 0.525 0.524 0.525 0.000 0.207

^SN38 0.632 0.637 0.638 0.002 0.250

^SN46 0.486 0.484 0.481 0.002 0.190

^SN47 0.514 0.513 0.515 0.001 0.202

^SN48 0.642 0.643 0.638 0.002 0.252

^SN50 0.794 0.791 0.790 0.002 0.312

^SN58 0.613 0.616 0.617 0.002 0.242

^SN68 0.624 0.626 0.629 0.002 0.247

^SN69 0.952 0.953 0.953 0.000 0.375

^SN70 1.563 1.565 1.564 0.001 0.616

^SN71 1.555 1.559 1.557 0.002 0.613

^SN72 0.958 0.958 0.956 0.001 0.377

^SN73 1.281 1.284 1.285 0.002 0.505

^SN74 1.230 1.229 1.226 0.002 0.484

^SN75 0.536 0.536 0.536 0.000 0.211

^SN76 0.630 0.630 0.630 0.000 0.248

Data Notations: All micometer readings are converted from cm to inches by multiplying by

0.393700787. Maximum Difference must be < 0.004".

QA/QC Review by: 24-Feb-09

Nozzle Diameter, Dn (cm)

QUARTERLY NOZZLE CALIBRATIONS

STEEL NOZZLE SET

02/23/2009 SEG
Environmental Services

Air Services Group

Shared Resource

Calibration Date:

Calibration Personnel:

Test Designation:

Maximum Average

D1 D2 D3 Difference, " Dn, inches

0.298 0.298 0.296 0.002 0.297

Data Notations: 

Maximum Difference must be < 0.004".

Quarterly (pre-test) value for nozzle ID SN10 was 0.298

Difference (Pre-test/Post-test) is: 0.001 PASS

QA/QC Review by:

2-Mar-09

POST TEST NOZZLE CALIBRATION 

Nozzle

Identifier

Nozzle Diameter, Dn (in)

02/27/2009

SEG

BB-UNIT 1-CSOO1W

SN10
Environmental Services

Air Services Group

Red Team

Pyrometer Under Test

Pyrometer Number: ^PY10

Labworks Sample #

Calibration Date: 10/24/2008

Calibrator Information

Calibrator Type/Manufacturer: Hart Scientific

Calibrator Serial Number: AOA024

Date of Last Calibration: 04/28/2008

Calibration Personnel (Typed and Signature):

Calibration Data

Calibration Reference Pyrometer

Point Temperature Indication Difference

1 400 401 -1

2 212 212 0

3 32 33 -1

Reference temperatures must encompass the expected range of measurement. These three points

should be ~ 32 degrees, ~212 degrees, and ~ 400 degrees Farenheit.

Difference is calculated as follows:

(reference temperature ) – (pyrometer indication )

Qaulity Control Data

Calibration

Point Difference

1 Pass

2 Pass

3 Pass

Reviewer:

N/A

Jorge A. Varino

Pyrometer Calibration

29-Oct-08
Pitot Tube ID #

Calibration Date Operating Quarter/Year: 4-08

Openings Damaged? ___ Y ___N Repaired? ____Y ___ N ___ N/A

Labworks #:

Alpha and Beta Angle Determinations Acceptable Limits:

α 1 1.4 degrees Dt 0.48 < Dt > 0.95 cm

α 2 1.5 degrees α < 10 degrees

β 1 0.7 degrees

β 2 0.4 degrees

β1 < 5 degrees (alongside top impact openings)

Gamma, Theta, Α, Ζ, and W Determinationsβ2 < 5 degrees (alongside bottom impact openings)

ψ 0.2 degrees Ζ < 0.32 cm (Αsinψ)

Α 2.37 cm W < 0.08 cm (Asinο)

Ζ 0.008 cm Α distance between tips

ο angle of plane on side of pitots

ο 1.7 degrees ψ angle between tips

W 0.070 cm

Comments:

Calibrated by:

Quality Assurance Review / Approval: 29-Oct-08

details are found in EPA/600/4-77/027b, "Quality Assurance Handbook for Air Pollution Measurement Systems:

Stationary Source Specific Methods", sub-section 3.1.1, Procuement of Apparatus and Supplies.

REMOVABLE

Pass

NOTES

All measurements are taken in accordance with the requirements of 40 CFR 60, Appendix A - Test Methods, 

Method 2, "Determination of stack gas velocity and volumetric flow rate (Type S pitot tube)". Measurement

Pass

Pass (α1 measured across top impact openings)

Pass (α2 measured across bottom impact openings)

Shared Resource

0

Pass

Pass

PITOT TUBE CALIBRATION

DATA SHEET

PT11

10/24/2008
Environmental Services

Air Services Group

Blue Team

Instrument Number:

Calibration Date:

Calibration Personnel:

Labworks #:

Difference

Time "Hg

9:00 0.02

10:05 0.03

11:05 0.03

Average Difference: 0.026667

Note: Barometric readings must agree within ± 0.1 "Hg.

Current Reference is National Weather Service, TIA.

Comments (Note any adjustments):

QA/QC Review by: Date: 24-Feb-08

Current Conditions at Tampa International Airport

30.40 30.37

30.37 30.35

30.41 30.38

Barometer Reading Reference Reading

Inches Mercury Inches Mercury

BAROMETER CALIBRATION

^BR07

02/23/2009

SEG
APPENDIX H

CHAIN OF CUSTODY 

APPENDIX I

TEST PARTICIPANTS 
TEST PARTICIPANTS

ENVIRONMENTAL SERVICES 

AIR SERVICES GROUP

Test Team

Scott Given Environmental Technician, Test Team Lead 

Jorge Varino Environmental Technician 

Ryan Newell Associate Technician 

Process Data

Adam Ballans Associate Engineer – Big Bend Station 

Sample Analysis

Samraing Soth Environmental Technician 

Patrece Jackson Environmental Technician 

Ellen Demers Environmental Technician 

Project Quality Objectives & Reporting

Ray McDarby Senior Environmental Technician 

BIG BEND STATION

Test Coordination

Karen Zwolak Senior Environmental Consultant – Big Bend Station 

David A. Smith Coordinator – Air Services Group 

Adam Ballans Associate Engineer – Big Bend Station