1 

1.0 INTRODUCTION

On June 3, 2009, the Environmental, Health, & Safety Air Services Group of 

Tampa Electric Company, performed particulate 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) 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, Compliance determination procedures and methods, §B.26 

through §B.27. Ammonia Slip testing 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) emission limitation was performed using the facilities 

installed Continuous Emissions Monitoring system (CEMS). The Sulfur Dioxide 

emission rate was also assessed using the installed CEMs. Visible emissions 

were assessed using the facilities installed 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 

NOX, lb/mmBtu 0.09 0.121

NOX, lbs/hr 343 4332,5

SO2, lbs/hr 668 33741

VE, % opacity(soot blowing) 8 203

VE, % opacity(non-soot blowing) 8 203

Heat Input, mmBtu/hr 3908 41154

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 operation 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 was 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 average concentration was calculated as 

≤0.5 ppmv. The FDEP AC permitted concentration is 10 ppmv (§ A.17.). 

The nitrogen oxide emission rate was determined using data provided by the 

Continuous Emissions Monitoring System’s (CEMS), Data Acquisition and 
3 

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

determined to be 0.09 lbs/mmBtu and 343 lbs/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 was determined using data provided by the 

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

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

determined to be 668 lbs/hr. The FDEP allowable emission rate is 3374 lbs/hr, 

based on scenario 3 as listed in condition A.9.e. 

Visible emissions were evaluated using 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 mmBtu/hr and an average load of 400 

megawatts. The average quantity of fuel 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. The 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, respectively. Using these criteria, a total of 24 

sampling points were chosen for particulate sampling, as stipulated in USEPA 

Method 1 – “Sample and Velocity Traverses for Stationary Sources”. A diagram 

of the stack sampling location is included 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 NOX 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 combusted a solid fuel matrix comprised of 87% coal and 

13% petroleum coke. 

Particulate matter sampling was performed according to USEPA Method 5B 

"Determination of Nonsulfuric Acid Particulate Matter from Stationary Sources". 

Particulate matter was collected on a high purity, borosilicate microfiber 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 Emission Rate Correction Factor, or Excess 

Air”. Gas analysis was performed on-site using an Orsat analyzer. 
5 

Sulfur Dioxide (SO2), Nitrogen Oxides (NOX), and Carbon Dioxide (CO2) data 

were provided by the Continuous Emissions Monitoring System (CEMS), Data 

Acquisition and Handling System (DAHS). Averages were derived from the time 

frame of 9:52 through 14:58 EST, corresponding 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 the installed Continuous Opacity Monitor 

(COM) system. This data is summarized 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

Vm(std), scf 36.897 37.231 38.786

Bws, ratio 0.156 0.154 0.149

O2, % volume 5.00 5.00 5.00

Md, lb/lb - mole 30.44 30.44 30.44

Ms, lb/lb - mole 28.50 28.53 28.58

Qs, acf/min 1.23E+06 1.23E+06 1.28E+06

Qs(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

Er, lb/mmBtu 0.02 0.01 0.01

Emission rate (Er), lb/mmBtu, calculated as: C x 9780 dscf/mmBtu x (20.9/(20.9-%O2))

Run 1 was a soot blowing run

5.00

30.44

Boiler # 3

WET-BOTTOM UTILITY BOILER

June 3, 2009

Test Summary

1.103E-06

0.01

28.54

1.25E+06

9.46E+05

100.6

37.638

0.153

7 
BIG BEND STATION

AMMONIA SLIP TEST DATA

Calculated Data

Run NH3 Water SF6 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 Run Time NH3 Water SF6 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

≤

NH3

1

, ppmvw is corrected for FTIR bias factor from annual QA/QC checks.

This value is: 1.0602

BOILER #3

WET-BOTTOM UTILITY BOILER

June 3, 2009

FTIR Recorded Data

ppmvw

0.51

0.33

0

FTIR Recorded Data

NH3

1

40 CFR 63 Reference Method 320

Summarized Data

Run Time NH3

1

ppmvw

0.56

≤0.5

0.6

0.5

0.5

8 
BIG BEND STATION

SULFUR DIOXIDE and NITROGEN OXIDES DATA from CEMs

Test Period Information

Start Time 9:52:00 Eastern Standard Time (EST)

Stop Time 14:58:00 Eastern Standard Time (EST)

Total Time 5:06:00

Corresponding to the time frame for the PM test.

Sulfur Dioxide Data:

RM - 19

SO2 NOX CO2 SO2 SO2 NOX

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

71.1 0.088 12.44 0.171 667.67 342.99

Calculation Details

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

where:

Cf = 1.660E-07 (lb/scf)/ppm SO2, RM - 19 Table 19-1

Fc = 1800 scf/mmBtu, RM - 19 Table 19-2

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

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

where:

Heat Input = 3908 mmBtu/hr, from 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 BOILER

SOOTBLOWING CONDITIONS

10 
BIG BEND STATION

VISIBLE EMISSIONS DATA FROM OPACITY MONITOR

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 BOILER

NON-SOOTBLOWING CONDITIONS

11 
BIG BEND GENERATING STATION

HEAT INPUT CALCULATIONS

Gross Heat Rate, Previous Month (May): 9770 KMBtu/MWh

9.7700E+06 MMBtu/MWh

Testing Start Time: 9:52

Testing End Time: 14:58

Total Test Time: 5.1 hours

Average Unit Load, MWe: 400 MW

Heat Input, MMBtu/h = MMBtu/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 Tons/hour

Test Time Information

Calculated Heat Input

Fuel Consumption Calculation

Unit # 3

WET BOTTOM UTILITY BOILER

June 3, 2009

12 
13 

5.0 FIGURES
FIGURE 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