1 

### 1.0 INTRODUCTION
On June 3, 2009, the Envir onmental, Health, & Safety Air Services Group of Tampa Electric Company, performed parti culate matter (PM) and ammonia slip tests at the Big Bend Station (Facility ID No.: 0570039), Boiler No. 3, (E.U. ID No.: -003). Particulate Matter (PM) te sting was conducted according to procedures stipulated by t he Florida Department of En vironmental Protection (FDEP) for fossil fuel steam generators, and requirements in Title V Permit # 0570039-028-AV, Compliance determination procedures and methods , §B.26 through §B.27. Ammonia Slip testi ng was conducted in accordance with FDEP Air Construction (AC) Permit 0570039- 022-AC (as modified in permit 0570039- 035-AC), COMPLIANCE DETERMINATION , §A.19. Compliance with the Nitrogen Oxides (NOx) emi ssion limitation was perform ed using the facilities installed Continuous Emissions Monitori ng system (CEMS). The Sulfur Dioxide emission rate was also assessed using t he installed CEMs. Visible emissions were assessed using the facilities insta lled Continuous Opacity Monitor (COM).2 

### 2.0 DISCUSSION OF RESULTS Executive Summary Tampa Electric Company Big Bend Station Wet-Bottom Utility Boiler

Emission Unit ID -003
Coal/Petroleum Coke/Polk Residual Compliance Parameter Test Result FDEP Permit Limit June 3, 2009 Particulate, lb/mmBtu 0.01 0.03 Ammonia, ppmv ≤ 0.5 10 NO X , lb/mmBtu 0.09 0.12 1 NO X , lbs/hr 343 433 2,5 SO 2 , lbs/hr 668 3374 1 VE, % opacity (soot blowing) 8 20 3 VE, % opacity (non-soot blowing) 8 20 3 Heat Input, mmBtu/hr 3908 4115 4 Unit Load (% of permit) 95% 90 – 100% 1 Based on a heat input weighted 30-day rolling average. 2 Based on a 30-day rolling average. 3 6-minute average. 4 Permitting Note: The heat input has been placed in the permit to identify the capacity of the unit for purposes of confirming that emissions testing is conducted within the 90 – 100% of the unit’s rated capacity (or to limit future operat ion to 110% of the test load), to establish appropriate emission limits and to aid in determining future rule applicability. 5 This limit is based on a heat input of 4115 mmBtu/hr. The particulate matter emission rate was derived from three United States Environmental Protection Agency (USEPA) Reference Method 5-B test runs. The average of the three test runs wa s 0.01 lb/mmBtu. The FDEP allowable emission rate under is 0.3 lb/mmBtu, as listed in condition A.7.

The average ammonia slip concentration was derived from three 1-hour USEPA reference method 320 test runs. The av erage concentration was calculated as
≤ 0.5 ppmv. The FDEP AC permitted c oncentration is 10 ppmv (§ A.17.).

The nitrogen oxide emission rate was determined using data provided by the Continuous Emissions Monitoring Syst em’s (CEMS), Data Acquisition and3 Handling System (DAHS). The average em ission rate for the test period was determined to be 0.09 lbs/mmBtu and 343 lb s/hr. The FDEP Air Construction permit (0570039-035-AC) allowable emission rates are 0.12 lb/mmBtu and 494 lbs/hr, as listed in condition A.16.

The sulfur dioxide emission rate wa s determined using data provided by the Continuous Emissions Monitoring Syst em’s (CEMS), Data Acquisition and Handling System (DAHS). The average em ission rate for the test period was determined to be 668 lbs/hr. The FDEP a llowable emission rate is 3374 lbs/hr, based on scenario 3 as listed in condition A.9.e.

Visible emissions were evaluated usi ng a Teledyne Instruments/Monitor Labs, LightHawk 560 transmissometer system (S/N 5600448), during both sootblowing and non-sootblowing testing. The 1- hour average opacity under sootblowing conditions was 8%. The 1-hour average opacity under non-sootblowing conditions was 8%. The FDEP allowable emission rate is 20%, as listed in condition A.6.

During the tests performed on June 3, 2009, Boiler No. 3 was operated at an average heat input rate of 3908 mmB tu/hr and an average load of 400 megawatts. The average quantity of f uel burned was 168.9 tons per hour.4 

### 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. T he Unit #3 (BB03) source sampling location consists of a circular stack 28.83 feet in diameter with four sample ports located 90 degrees apart on the stack circumference. Upstream and downstream gas flow disturbances were determined to be 8.51 and 2.99 stack diameters from the test ports, respective ly. Using these criteria, a total of 24 sampling points were chosen for particula te sampling, as stipulated in USEPA Method 1 – “Sample and Velocity Traverse s for Stationary Sour ces”. A diagram of the stack sampling location is incl uded in Figure 1 along with other pertinent information on the test site.

Boiler No. 3 is serviced by an electrostatic precipitator for the control of flyash emissions, low NO X burners and a Selective Catalytic Reduction (SCR) system for control of nitrogen oxide emissions , and a flue gas desulfurization (FGD) system for control of sulfur dioxide emissions.

During the test the unit com busted a solid fuel matrix comprised of 87% coal and 13% petroleum coke.

Particulate matter sampling was perfo rmed according to USEPA Method 5B "Determination of Nonsulfuric Acid Partic ulate Matter from Stationary Sources". Particulate matter was collected on a high purity, borosilicate mi crofiber filter measuring 82mm in diameter. This data is included as Appendix A, and summarized on page 7 of this report. Run one was a soot blowing run, subsequent runs were conducted under non-soot blowing conditions.

Diluent gas sampling and analysis was performed according to USEPA Method 3 "Gas Analysis for Determination of Emi ssion Rate Correction Factor, or Excess Air”. Gas analysis was performed on-site using an Orsat analyzer.5 Sulfur Dioxide (SO 2 ), Nitrogen Oxides (NO X ), and Carbon Dioxide (CO 2 ) data were provided by the Continuous Emissi ons Monitoring System (CEMS), Data Acquisition and Handling System (DAHS). Averages were derived from the time frame of 9:52 through 14:58 EST, corres ponding to the time frame of the particulate matter test. This data is included as Appendix B, and summarized on page 9 of this report.

Visible emissions were assessed using t he installed Continuous Opacity Monitor (COM) system. This data is summariz ed on pages 10 (soot blowing conditions), and 11 (non-soot blowing conditions).6 

### 4.0 TEST RESULTS

### BIG BEND STATION PARTICULATE MATTER DATA SUMMARY

Run 1S Run 2 Run 3 V m(std) , scf 36.897 37.231 38.786

B ws , ratio 0.156 0.154 0.149

O 2 , % volume 5.00 5.00 5.00

M d , lb/lb - mole 30.44 30.44 30.44

M s , lb/lb - mole 28.50 28.53 28.58
Q s , acf/min 1.23E+06 1.23E+06 1.28E+06
Q s(std) , dscf/min 9.27E+05 9.34E+05 9.76E+05
I, % 100.6 100.8 100.4
C, lbs/dscf 1.30E-06 1.06E-06 9.49E-07

E r , lb/mmBtu 0.02 0.01 0.01
Emission rate (E r ), lb/mmBtu, calculated as: C x 9780 dscf/mmBtu x (20.9/(20.9-%O 2 )) Run 1 was a soot blowing run 5.00

30.44 Boiler # 3 WET-BOTTOM UTILITY BOILE R June 3, 2009

T est Summary

1.103E-06

0.01 28.54

1.25E+06

9.46E+05

100.6 37.638

0.153

7

### BIG BEND STATIO N AMMONIA SLIP TEST DAT A

Calculated Data Run NH 3 Water SF 6 Cell Temp Pressure Number Start Stop ppmvw % ppm °C ATM 1 11:26 12:26 0.524 16.42 -0.02 150 1.0086 2 13:14 14:14 0.477 16.20 -0.02 150 1.0074 3 14:18 15:18 0.312 16.14 -0.02 150 1.0070 Average: Notation to Data: Because the measured NH3 for run 2 and 3 was below the Minimum Detection Limit of 0.5 ppm, the data was recalculated substituting 0.5 ppm for the measured data.
Calculated Data Run R un Time NH 3 Water SF 6 Cell Temp Pressure Number Start Stop ppmvw % ppm °C ATM 1 11:26 12:26 0.524 16.42 -0.02 150 1.0086 2 13:14 14:14 0.5 16.20 -0.02 150 1.0074 3 14:18 15:18 0.5 16.14 -0.02 150 0.8859 Average: ≤ 0.5

≤ NH 3 1 , ppmvw is corrected for FTIR bias factor from annual QA/QC checks. This value is: 1.0602 BOILER #3 WET-BOTTOM UTILITY BOILE R June 3, 2009

FTIR Recorded Data

ppmvw 0.51 0.33

0

FTIR Recorded Data NH 3 1 40 CFR 63 Reference Method 320 Summarized Data

Run Time NH 3 1 ppmvw

0.56

≤ 0.5 0.6 0.5 0.5

8

### BIG BEND STATION SULFUR DIOXIDE and NITROGEN OXIDES DATA from CEMs

T est Period Information Start Time 9:52:00 Eastern Standard Time (EST) Stop Time 14:58:00 Eastern Standard Time (EST) T otal Time 5:06:00 Correspondin g to the time frame for the PM test.

Sulfur Dioxide Data: RM - 19 SO 2 NO X CO 2 SO 2 SO 2 NO X ppmvw lb/mmBtu %, wet lb/mmBtu lbs/hr lbs/hr

71.1 0.088 12.44 0.171 667.67 342.99

Calculation Details SO 2 , lb/mmBtu = SO 2 , ppmvw x C f x F c x (100 / CO2 %, wet) where: C f

= 1.660E-07 (lb/scf)/ppm SO 2 , RM - 19 Table 19-1 F c = 1800 scf/mmBtu, RM - 19 Table 19-2 SO 2 , lbs/hr = SO 2 , lb/mmBtu x Heat Input, mmBtu/hr NO X , lbs/hr = NO X , lb/mmBtu x Heat Input, mmBtu/hr where: Heat Input = 3908 mmBtu/hr, fr om Heat Input Calculation CEM DATA Calculated Boiler #3 WET-BOTTOM UTILITY BOILER June 3, 2009

9

### BIG BEND STATION VISIBLE EMISSIONS DATA FROM OPACITY MONITOR

Record# DATE TIME OPACITY3 Record# DATE TIME OPACITY3 1 06/03/09 9:55 7.070 31 06/03/09 10:25 8.540 2 06/03/09 9:56 7.240 32 06/03/09 10:26 7.550 3 06/03/09 9:57 7.220 33 06/03/09 10:27 7.110 4 06/03/09 9:58 6.950 34 06/03/09 10:28 7.110 5 06/03/09 9:59 7.330 35 06/03/09 10:29 7.120 6 06/03/09 10:00 7.360 36 06/03/09 10:30 7.220 7 06/03/09 10:01 7.290 37 06/03/09 10:31 7.840 8 06/03/09 10:02 7.220 38 06/03/09 10:32 7.290 9 06/03/09 10:03 7.620 39 06/03/09 10:33 7.630 10 06/03/09 10:04 7.900 40 06/03/09 10:34 7.290 11 06/03/09 10:05 7.030 41 06/03/09 10:35 6.300 12 06/03/09 10:06 7.220 42 06/03/09 10:36 6.570 13 06/03/09 10:07 6.720 43 06/03/09 10:37 6.510 14 06/03/09 10:08 7.140 44 06/03/09 10:38 6.700 15 06/03/09 10:09 7.730 45 06/03/09 10:39 6.800 16 06/03/09 10:10 6.680 46 06/03/09 10:40 6.790 17 06/03/09 10:11 7.450 47 06/03/09 10:41 9.030 18 06/03/09 10:12 7.710 48 06/03/09 10:42 6.870 19 06/03/09 10:13 7.320 49 06/03/09 10:43 6.610 20 06/03/09 10:14 7.330 50 06/03/09 10:44 8.050 21 06/03/09 10:15 7.760 51 06/03/09 10:45 8.200 22 06/03/09 10:16 6.900 52 06/03/09 10:46 8.450 23 06/03/09 10:17 6.990 53 06/03/09 10:47 6.840 24 06/03/09 10:18 8.210 54 06/03/09 10:48 7.140 25 06/03/09 10:19 9.260 55 06/03/09 10:49 6.980 26 06/03/09 10:20 8.500 56 06/03/09 10:50 6.530 27 06/03/09 10:21 8.450 57 06/03/09 10:51 7.640 28 06/03/09 10:22 7.210 58 06/03/09 10:52 7.210 29 06/03/09 10:23 6.920 59 06/03/09 10:53 6.550 30 06/03/09 10:24 7.060 60 06/03/09 10:54 6.240 Test Average: 7.325 % Minimum One Minute Average: 6.240 % Maximum One Minute Average: 9.260 %

Maximum Six Minute Average: 8.103 % Boiler #3 WET BOTTOM UTILITY BOILE R

SOOTBLOWING CONDITIONS

10

### BIG BEND STATION VISIBLE EMISSIONS DATA FROM OPACITY MONITO R

Record# DATE TIME OPACITY3 Record# DATE TIME OPACITY3 1 06/03/09 11:35 6.720 31 06/03/09 12:05 6.740 2 06/03/09 11:36 6.570 32 06/03/09 12:06 6.070 3 06/03/09 11:37 6.360 33 06/03/09 12:07 6.380 4 06/03/09 11:38 6.440 34 06/03/09 12:08 6.620 5 06/03/09 11:39 6.520 35 06/03/09 12:09 6.820 6 06/03/09 11:40 6.520 36 06/03/09 12:10 8.240 7 06/03/09 11:41 6.710 37 06/03/09 12:11 8.160 8 06/03/09 11:42 7.040 38 06/03/09 12:12 8.230 9 06/03/09 11:43 6.230 39 06/03/09 12:13 6.630 10 06/03/09 11:44 6.490 40 06/03/09 12:14 7.020 11 06/03/09 11:45 6.590 41 06/03/09 12:15 6.430 12 06/03/09 11:46 6.620 42 06/03/09 12:16 6.380 13 06/03/09 11:47 7.360 43 06/03/09 12:17 6.650 14 06/03/09 11:48 6.490 44 06/03/09 12:18 7.280 15 06/03/09 11:49 7.410 45 06/03/09 12:19 7.150 16 06/03/09 11:50 6.480 46 06/03/09 12:20 6.910 17 06/03/09 11:51 6.890 47 06/03/09 12:21 6.850 18 06/03/09 11:52 7.840 48 06/03/09 12:22 7.760 19 06/03/09 11:53 6.720 49 06/03/09 12:23 7.230 20 06/03/09 11:54 6.700 50 06/03/09 12:24 6.560 21 06/03/09 11:55 7.050 51 06/03/09 12:25 6.810 22 06/03/09 11:56 6.860 52 06/03/09 12:26 6.390 23 06/03/09 11:57 6.490 53 06/03/09 12:27 6.420 24 06/03/09 11:58 6.540 54 06/03/09 12:28 6.520 25 06/03/09 11:59 6.520 55 06/03/09 12:29 6.420 26 06/03/09 12:00 6.340 56 06/03/09 12:30 7.490 27 06/03/09 12:01 6.660 57 06/03/09 12:31 8.090 28 06/03/09 12:02 9.930 58 06/03/09 12:32 7.190 29 06/03/09 12:03 6.920 59 06/03/09 12:33 7.180 30 06/03/09 12:04 6.490 60 06/03/09 12:34 7.280 Test Average: 6.907 % Minimum One Minute Average: 6.070 % Maximum One Minute Average: 9.930 %

Maximum Six Minute Average: 7.517 % Boiler #3 WET BOTTOM UTILITY BOILE R NON-SOOTBLOWING CONDITIONS

11

### BIG BEND GENERATING STATIO N HEAT INPUT CALCULATION S

Gross Heat Rate, Previous Month (May): 9770 KMBtu/MWh 9.7700E+06 MMBtu/MWh

Testing Start Time: 9:52

Testing End Time: 14:58

T otal Test Time: 5.1 hours

Average Unit Load, MWe: 400 MW Heat Input, MMBtu/h = MMB tu/MWh x MWe: 3908 mmBtu/hr

Laboratory Sample ID: AB01275 Btu as received: 11571 Btu/lb Tons of Fuel Consumed, Tons/hr = (mmBtu/h / Btu/lb) x 500: 168.9 T ons/hour Test Time Information

Calculated Heat Input

Fuel Consumption Calculation Unit # 3 WET BOTTOM UTILITY BOILE R June 3, 2009

1213 

### 5.0 FIGURESFIGURE 1 EXHAUST STACK 245 FT. BIG BEND STATION

PARTICULATE TRAVERSE POINTS

OUTLET 

## N A

B C D

PORT LOCATION

REVISED 12-31-96 BOILER NO. 3 TEST LOCATION

STACK DIAMETERS DOWNSTREAM FROM DISTURBANCE = 3.0

STACK DIAMETERS UPSTREAM FROM DISTURBANCE = 8.5

STACK DIAMETER = 28.8333 FT. STACK AREA = 652.948 SQ.

PORT LENGTH’S = 14 IN. TRAVERSE POINT

1

2

3

4

5

6 % OF STACK DIAMETER IN. FROM STACK WALL
2.1%

6.7%

11.8%

17.7%

25.0%

35.6% 7.27 IN.

23.18 IN.

40.83 IN.

61.24 IN.

86.50 IN.

123.18 IN. 499 FT.

254 FT.

168 FT. 86 FT.

FGD

PRESSURIZED ANNULUS

14