# 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 subseque nt data entry/reduction detailed in this report was conducted at my direction, and I here by 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 performa nce, associated quality assurance activities, the resultant calculations, and the contents of this report, and certify that all project quality obj ectives have been met. Th is 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 authenti c 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, Ta mpa Electric Company’s En vironmental Services, Air Services Group, performed source emission tests at the Big B end Station, Boiler No. 1, emissions unit I.D.# -001. Testing was conducted according to procedures stipulated by t he 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 r uns (one soot blowing, tw o non soot blowing). The average of the three test runs wa s 0.02 lb/mmBtu. The FDEP permitted
emission rate under non-soot blowi ng conditions is 0.03 lb/mmBtu.

The Sulfur Dioxide (SO 2 

### ) emission rate was determined using data provided by the Continuous Emissions Monitoring Syst em’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 lb s/hr. The FDEP a llowable 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), duri ng both soot blowing and non-soot blowing testing. The 1-hour average opac ity under soot blowin g 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 circ ular stack 29.83 feet in diameter with four sample ports located 90 degrees apart on the stack circumference. These ports are located downstr eam 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 t he 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 electrostati c 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 so lid fuel matrix comprised of 88% coal and 12% petroleum coke.

Particulate sampling was perform ed according to USEPA Method 5B
"Determination of Nonsulfuric Acid Part iculate Matter from Stationary Sources"

Diluent gas sampling and analysis was performed according to USEPA Method 3 "Gas Analysis for Determination of Emissi on Rate Correction Factor, or Excess Air”. Gas analysis was performed on-site using an Orsat analyzer.

Sulfur Dioxide (SO 2 

### ) and Carbon Dioxide (CO 2 

### ) 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 a ssessed using the installed Continuous Opacity Monitor (COM), and the CEMS DAHS.

4

## 4.0 TABULATED RESULTS

5

### Environmental Services Air Services Group

Customer: T ampa Electric Company Facility: Big Bend Station Sampling Location: CS0W1 - Common Stack 1 - Wet Unit Under Test: Boiler #1 T est Date: Operating Conditions: Non-Soot Blowing and Soot Blowing

Run 1 Run 2 Run 1s T est Average

V m(std) 

### , scf 36.505 35.687 35.926 36.040

B ws 

### , ratio 0.151 0.156 0.154 0.154

M

d 

### , lb/lb - mole 30.2 30.2 30.2 30.2

M

s 

### , lb/lb - mole 28.4 28.3 28.3 28.3

Q s 

### , acf/min 746044.67 731976.76 729258.02 735759.8

Q s(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

E M 

### , lbs/hr 57.7 58.6 50.6 55.7

E R 

### , lbs/MMBtu 0.025 0.026 0.023 0.02 Wednesday, February 25, 2009



### 6

## BIG BEND STATION SULFUR DIOXIDE DATA FROM CEMs

T est Period Information Start Time 10:03:00 Eastern Standard Time (EST) Stop Time 14:27:00 Eastern Standard Time (EST) T otal Time 4:24:00 Correspondin g to the time frame for the PM test.

Sulfur Dioxide Data: RM - 19 SO 2 

### CO 2 

### SO 2 

### SO 2 

### ppmvw %, wet lb/mmBtu lbs/hr

49.7 12.2 0.1 487

Calculation Details SO 2 

### , lb/mmBtu = SO 2 

### , ppmvw x C f 

### x F c 

### x (100 / CO2 %, wet)
where: C f



### = 1.664E-07 (lb/scf)/ppm SO 2 

### F c



### = 1800 scf/mmBtu SO 2 

### , lbs/hr = SO 2 

### , 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 BOILE R

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 BOILE R NON-SOOTBLOWING CONDITIONS

9

## BIG BEND GENERATING STATION HEAT INPUT CALCULATIONS

Gross Heat Rate, Previous Mo nth (January): 10046 KMBtu/MWh 1.0046E+07 MMBtu/MWh

T est Time Information T estin g Start Time: 10:03

T estin g End Time: 14:27

T otal Test Time: 4.4 hours
Calculated Heat Input Avera g e 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 T ons of Fuel Consumed, Tons/hr = (mmBtu/h / Btu/lb) x 500: 168.8 T ons/hour Unit #1
February 25, 2009 WET-BOTTOM UTILTIY BOILE R

10

## 5.0 FIGURES

11FIGURE 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, D n : 0.298 inches Barometric Pressure, P b : 29.70 "Hg Nozzle Area, A n : 0.000484 ft 2 Stack Pressure, P s : 29.69 "Hg Average Orifice Meter, Δ H: 1.330 "H 2 O Effective Stack Area, A s : 452.389 ft 2 Sample Volume, V m : 38.205 ft 3 Pitot Coefficient, Cp: 0.84 dimensionless Average Meter Temp., T m : 80.4 o F Gas Analysis: 12.0 % CO 2 Average Stack Temp., T s : 127.6 o F 7.0 % O 2 Average √ Δ p: 0.458 "H 2 O 0.0 % CO Condensate Volume, V l c : 138.0 ml 81.0 % N 2 Meter Box Y: 0.982 dimensionless F-factor, F d , for fuel: 9780 dscf/MMBtu

Data Calculated from Source Measurements: V w ( std ) = 4.707E-02 x V l c 6.496 scf V m ( std ) = 17.647 x V m x Y x (P b + ( Δ H / 13.6)) / (T m +460) 36.505 dscf B ws = V w ( std ) / (V m ( std ) + V w ( std ) ) 0.151 % FDA = 1.0 - B ws 0.849 % M d = (0.44 x %CO 2 ) + (0.32 x %O 2 ) + (0.28 x (%N 2 + % CO)) 30.20 lb./lb. mole M s = (M d x FDA) + (18.0 x B ws ) 28.36 lb./lb. mole

v s = 85.49 x C p x ( √Δ p) x ( √ (T s + 460) / (M s x P s )) 27.49 ft/second Q s = v s x A s x 60 746044.7 acf/minute Q s ( std ) = Q s x FDA x (528 / (T s + 460)) x (P s / 29.92)) 564799.9 dscf/minute I = (T s + 460) x ((2.67E-03 x V lc ) + (V m(std) / 17.647)) x 100 / ( θ x P s x A n x v s x 60) 100.6 %

Data from Laboratory Analysis: Total Particulate Weight From Laboratory Analysis: 0.028200 grams

Calculated Concentration and Emission Rate Data:

c s = (15.432 x grams) / V m ( std ) 0.012 grains/dscf grains/acf = c s x 17.647 x P s x (FDA / (T s + 460) 0.009 grains/acf C = c s / 7000 1.703E-06 lbs/dscf E M = C x Q s ( std ) x 60 57.7 lbs/hr E R = C x F d x (20.9 /(20.9 - %O 2 ) 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, D n : 0.298 inches Barometric Pressure, P b : 29.81 "Hg Nozzle Area, A n : 0.000484 ft 2 Stack Pressure, P s : 29.80 "Hg Average Orifice Meter, Δ H: 1.287 "H 2 O Effective Stack Area, A s : 452.389 ft 2 Sample Volume, V m : 37.347 ft 3 Pitot Coefficient, Cp: 0.84 dimensionless Average Meter Temp., T m : 82.3 o F Gas Analysis: 12.0 % CO 2 Average Stack Temp., T s : 127.4 o F 7.0 % O 2 Average √ Δ p: 0.450 "H 2 O 0.0 % CO Condensate Volume, V l c : 140.1 ml 81.0 % N 2 Meter Box Y: 0.982 dimensionless F-factor, F d , for fuel: 9780 dscf/MMBtu

Data Calculated from Source Measurements: V w ( std ) = 4.707E-02 x V l c 6.595 scf V m ( std ) = 17.647 x V m x Y x (P b + ( Δ H / 13.6)) / (T m +460) 35.687 dscf B ws = V w ( std ) / (V m ( std ) + V w ( std ) ) 0.156 % FDA = 1.0 - B ws 0.844 % M d = (0.44 x %CO 2 ) + (0.32 x %O 2 ) + (0.28 x (%N 2 + % CO)) 30.20 lb./lb. mole M s = (M d x FDA) + (18.0 x B ws ) 28.30 lb./lb. mole

v s = 85.49 x C p x ( √Δ p) x ( √ (T s + 460) / (M s x P s )) 26.97 ft/second Q s = v s x A s x 60 731976.8 acf/minute Q s ( std ) = Q s x FDA x (528 / (T s + 460)) x (P s / 29.92)) 553143.6 dscf/minute I = (T s + 460) x ((2.67E-03 x V lc ) + (V m(std) / 17.647)) x 100 / ( θ x P s x A n x v s x 60) 100.4 %

Data from Laboratory Analysis: Total Particulate Weight From Laboratory Analysis: 0.028600 grams

Calculated Concentration and Emission Rate Data:

c s = (15.432 x grams) / V m ( std ) 0.012 grains/dscf grains/acf = c s x 17.647 x P s x (FDA / (T s + 460) 0.009 grains/acf C = c s / 7000 1.767E-06 lbs/dscf E M = C x Q s ( std ) x 60 58.6 lbs/hr E R = C x F d x (20.9 /(20.9 - %O 2 ) 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, D n : 0.298 inches Barometric Pressure, P b : 29.80 "Hg Nozzle Area, A n : 0.000484 ft 2 Stack Pressure, P s : 29.79 "Hg Average Orifice Meter, Δ H: 1.280 "H 2 O Effective Stack Area, A s : 452.389 ft 2 Sample Volume, V m : 37.738 ft 3 Pitot Coefficient, Cp: 0.84 dimensionless Average Meter Temp., T m : 84.2 o F Gas Analysis: 12.0 % CO 2 Average Stack Temp., T s : 128.0 o F 7.0 % O 2 Average √ Δ p: 0.448 "H 2 O 0.0 % CO Condensate Volume, V lc : 139.4 ml 81.0 % N 2 Meter Box Y: 0.982 dimensionless F-factor, F d , for fuel: 9780 dscf/MMBtu

Data Calculated from Source Measurements: V w ( std ) = 4.707E-02 x V lc 6.562 scf V m ( std ) = 17.647 x V m x Y x (P b + ( Δ H / 13.6)) / (T m +460) 35.926 dscf B ws = V w ( std ) / (V m ( std ) + V w ( std ) ) 0.154 % FDA = 1.0 - B ws 0.846 % M d = (0.44 x %CO 2 ) + (0.32 x %O 2 ) + (0.28 x (%N 2 + % CO)) 30.20 lb./lb. mole M s = (M d x FDA) + (18.0 x B ws ) 28.32 lb./lb. mole

v s = 85.49 x C p x ( √Δ p) x ( √ (T s + 460) / (M s x P s )) 26.87 ft/second Q s = v s x A s x 60 729258.0 acf/minute Q s ( std ) = Q s x FDA x (528 / (T s + 460)) x (P s / 29.92)) 551308.6 dscf/minute I = (T s + 460) x ((2.67E-03 x V lc ) + (V m(std) / 17.647)) x 100 / ( θ x P s x A n x v s x 60) 101.5 %

Data from Laboratory Analysis: Total Particulate Weight From Laboratory Analysis: 0.024950 grams

Calculated Concentration and Emission Rate Data:

c s = (15.432 x grams) / V m ( std ) 0.011 grains/dscf grains/acf = c s x 17.647 x P s x (FDA / (T s + 460) 0.008 grains/acf C = c s / 7000 1.531E-06 lbs/dscf E M = C x Q s ( std ) x 60 50.6 lbs/hr E R = C x F d x (20.9 /(20.9 - %O 2 ) 0.023 lbs/MMBtu

## APPENDIX B

PARTICULATE MATTER LABORATORY ANALYTICAL DATACustomer Air Services Plant Big Bend Unit 1Method EPA 5B Stack Test Completion Date 02/25/2009Analyst Sam Soth/Peggy Penner/Rory LaceySample NumberACETONE BEAKER1st 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 3SAcetone Container IDAIR3A AIR9A AIRII AIR 6AAcetone Rinse Vol.(Va), mls 200.0000 200 200 Enter Container ID 200 Enter Container ID Enter Container ID1st Gross Wt., grams 106.8757 104.6739 111.7003 106.36992nd Gross Wt., grams 106.8759 104.6728 111.6994 106.36923rd Gross Wt., grams 104.6735 111.6994 106.36934th Gross Wt., grams 104.6731Avg. 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 106.36255Acetone Blank Wt.,mg0.85 0.85 0.85 0.85Acetone Particulate Wt.,mg8.85 11.40 5.85Acetone Residue, mg/g0.0054Acetone Blank CriteriaFILTER1st weighingDate 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 % RHFilter/Thimble ID 203145 203139 203144 2031431st Gross Wt., grams 0.2508 0.2683 0.2675 0.26922nd Gross Wt., grams 0.2507 0.2675 0.2671 0.26933rd Gross Wt., grams 0.26714th Gross Wt., gramsAvg. 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 0.25015Filter Particulate Wt.,mg19.35 17.20 19.10Difference, milligrams0.4Total Sample Particulate Wt.,mg28.20 28.60 24.95OK to subtract acetone blankStart 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 A verages: 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
FRANK WADE Description: 

### Location Code: 03/31/2009 Report Date:

Big Bend 1 Compliance 

### TE_BB_1_COMP_COAL

Project Account Code: 03/04/2009 Date of Sample Receipt: Sample Collection Method: 

### Laboratory Results 02/25/2009 3:45:00 PM

Result PARAMETER Qualifier Code Test Method Analyst Units Upper Limit MDL 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 0 3/18/2009 10:39:00 A M
Ash, Dry Basis % 0.01 ASTM D-3174 KAPXJ 8.98 0 3/18/2009 10:39:00 A M
BTU in Coal, as Determined BTU/Lb. 1 ASTM D-5865 KAPXJ 12866 0 3/18/2009 10:08:00 A M
BTU, as Received BTU/Lb 100 ASTM D-5865 KAPXJ 11849 0 3/18/2009 12:56:00 P M BTU, Dry Basis BTU/Lb. 100 ASTM D-5865 KAPXJ 13334 0 3/18/2009 12:56:00 P M
BTU, Moisture-Ash Free BTU/Lb. 100 ASTM D-5865 KAPXJ 14650 0 3/18/2009 12:56:00 P M
Calculated Heat Input, mmBtu/hr mmBtu/hr KARAM 4001 0 3/24/2009 10:09:00 A M PM non-sootblowing, lbs/mmBt u lb/mmBtu EPA RM-5/17 KARAM 0.02 0 3/24/2009 10:09:00 A M PM sootblowing, lbs/mmBtu lb/mmBtu EPA RM-5/17 KARAM 0.02 0 3/24/2009 10:09:00 A M

Pounds SO2 / Million BTU Lbs. SO2/MMBTU Calculated KAPXJ 4.92 0 3/18/2009 12:56:00 P M

SO2 emission rate, lbs/hr lbs/hr EPA - RM6C KARAM 487 0 3/24/2009 10:09:00 A M
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 0 3/18/2009 10:39:00 A M
Sulfur, Dry Basis % 0.08 ASTM D-4239 KAPXJ 3.45 0 3/18/2009 10:39:00 A M

Total Moisture % 0.1 ASTM D-3173 KAPXJ 11.14 0 3/18/2009 10:39:00 A M 

### Comments

Ray McDarby,

Manager, Laboratory Services All results calculated on a wet to wet basis, unless otherwise indicated. Should there be any questions regar ding 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 r eport pertain to results for sample AA99889

## APPENDIX F

FIELD DATA SHEETS

## APPENDIX G

SAMPLING EQUIPMENT CALIBRATIONS

## SUMMARY OF E Q UIPMENT CALIBRATION S

EQUIPMENT CAL DATE METHOD RESULTS
CONSOLE (MB 06) INITIA L 02/11/2009 USEPA RM 5 0.982 POST TEST 02/27/2009 (ORIFICE) 0.997
NOZZLE (SN10) INITIA L 02/23/2009 CALIPER 0.298 POST TEST 02/27/2009 MEASUREMENTS 0.297
PYROMETER (PY 10) 10/24/2008 ASTM THERMOMETER + 2 o 

### F
PITOT TUBE (PT 11) 10/24/2008 USEPA RM 2 C p 

### = 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 Δ H Time Volume Volume Volume Inlet Outlet Inlet Outlet "H 2 

### O Minutes ft 3 

### ft 3 

### ft 3 

### 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' A ctual 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 Δ H α Corrected Corrected Nominal Value QA/QC Value QA/QC Vm (std) , ft 3 Vcr (std) , ft 3 Vcr (std) , ft 3 

### (ratio) + 0.02 "H 2 

### O + 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 Δ H α , 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: A ssociated Test: Team: RED

Initial Final Total Δ H Time Volume Volume Volume Inlet Outlet Inlet Outlet "H 2 

### O Minutes ft 3 

### ft 3 

### ft 3 

### 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' A ctual 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 Δ H α Corrected Corrected Nominal Value QA/QC Value QA/QC Vm (std) , ft 3 Vcr (std) , ft 3 Vcr (std) , ft 3 

### (ratio) + 0.02 "H 2 

### O + 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 Final Tempertures Initial Temperatures

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 Δ H α , 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. D 1 

### D 2 

### D 3 Difference, " 

### D n 

### , 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, D n 

### (cm) QUARTERLY NOZZLE CALIBRATIONS

STEEL NOZZLE SET

02/23/2009 SEG

### Environmental Service s A ir Services Grou p

Shared Resource Calibration Date: Calibration Personnel: Test Designation:

Maximum 

### Average D 1 

### D 2 

### D 3 Difference, " 

### D n 

### , 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, D n 

### (in) 02/27/2009 SEG BB-UNIT 1-CSOO1W



### SN10

### Environmental Services A ir Services Group

Red Team Pyrometer Under Tes t Pyrometer Number: ^PY10 Labworks Sample # Calibration Date: 10/24/2008

Calibrator Information Calibrator Type/Manufacturer: Hart Scientific Calibrator Serial Number: A OA024 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-08Pitot 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 β 1 < 5 degrees (alongside top impact openings) Gamma, Theta, Α
, Ζ
, and W Determination s β 2 < 5 degrees (alongside bottom impact openings)

ψ 0.2 degrees Ζ < 0.32 cm ( Α sin ψ )
Α 2.37 cm W < 0.08 cm (Asin ο )
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:

Q uality 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 ( α 1 measured across top impact openings) Pass ( α 2 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 T ime "H g 9:00 0.02 10:05 0.03 11:05 0.03

Avera g e Difference: 0.026667

Note: Barometric readin g s must a g ree within ± 0.1 "H g

. Current Reference is National Weather Service, TIA.
Comments (Note any ad j ustments):

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 Readin g Reference Readin g 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 En gineer – 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 En gineer – Big Bend Station