# Appendix J

Analysis of Emissions from the Tampa

Electric Big Bend and Gulf Power Crist

Power Plants

### Purpose

The purpose of this appendix is to address a specific question that the U.S. EPA,

Region 4 reviewers had regarding the actual emissions changes occurring at the Tampa

Electric Company’s (TECO) Big Bend facility with regard to its consent decree.

Similarly, the same question is asked of the Gulf Power Crist plant and their voluntary

emissions reductions. Both the consent decree and the voluntary agreement were

considered in the 2018 projections for assessing future visibility.

The consent decree for TECO Big Bend essentially requires that all four units at this

facility are scrubbed for SO2 reduction and have selective catalytic reduction (SCR) for

NOx reduction. All of these controls have been installed except for the final SCR on unit

1. The following tables show the actual emissions of SO2 and NOx from all four Big

Bend unit from 1998 to 2008.

TECO Big Bend

- SO2 (tons per year)

Year Unit 1 Unit 2 Unit 3 Unit 4 Total

1998 46622 44168 12173 4371 107,334

1999 39454 41158 10798 4112 95,522

2000 24546 6782 12808 3962 48,098

2001 2,372 2,700 3,955 4,413 13,439

2002 2,789 2,021 2,621 4,170 11,601

2003 3,193 3,068 3,091 3,834 13,186

2004 2,803 2,937 2,697 3,477 11,913

2005 2,717 2,784 2,355 3,511 11,368

2006 2,225 3,222 3,658 4,872 13,977

2007 2,842 2,874 1,882 2,305 9,903

2008 2,062 1,951 1,080 4,521 9,615



### TECO Big Bend

- NOx (tons per year)

Year Unit 1 Unit 2 Unit 3 Unit 4 Total

1998 11314 10934 7003 6826 

### 36,077

1999 8768 8969 5950 6543 

### 30,230

2000 9019 10243 7238 7674 

### 34,174

2001 4,723 6,123 6,050 7,532 

### 24,428

2002 9,142 6,625 5,929 7,116 

### 28,813

2003 8,824 8,480 6,820 5,340 

### 29,464

2004 8,666 9,082 6,506 3,516 

### 27,769

2005 7,122 7,297 5,232 3,081 

### 22,733

2006 7,616 11,028 6,339 4,800 

### 29,783

2007 9,831 9,941 3,607 1,183 

### 24,561

2008 7,845 7,421 849 1,083 

### 17,198

### The emissions of SO2 and NOx used in the SIP modeling for the base year 2002 and

the projected year 2018 are shown below.

TECO Big Bend

- SO2 (tpy)

Unit 2002 2018

Unit 1 2,789 3,919



### Unit 2 2,021 3,780



### Unit 3 2,621 4,875



### Unit 4 4,170 4,923



### Total 11,601 17,496

TECO Big Bend

- NOx (tpy)

Unit 2002 2018

Unit 1 9,142 941



### Unit 2 6,625 937



### Unit 3 5,929 944



### Unit 4 7,116 953



### Total 28,813 3,774



### Current (2008) emissions of SO2 at the Big Bend facility are well below (nearly half) the

projected 2018 emissions used in the modeling. The SIP modeling assumed that

emissions would grow from the base year to reflect the generation need as population

grows. Actual growth is currently much less than assumed in the SIP modeling, and

generation growth, to the extent it’s needed, is likely to come from newer, cleaner

natural gas fired units elsewhere in the state. The result is that the SIP modeling for

2018 probably over-estimates visibility impacts.

Current (2008) NOx emissi ons at the Big Bend facility are still greater than emissions

projected for the 2018 SIP modeling. However, the schedule for installation of the SCR

units has these units coming on in 2007, 2008, 2009, and 2010 for units 4, 3, 2, and 1,

respectively. Thus, the 2008 emissions reflect the full use of only one SCR. As these

SCR units come on-line, NOx emissions are expected to reduce in-line with the 2018

SIP projections.

The voluntary NOx reductions at the Gulf Power Crist facility involved the installation of

an SCR unit on unit 7 and an SNCR unit on unit 6. The actual NOx and SO2 emissions

at the Crist facility are seen below.

### Gulf Power Crist

- NOx (tons per year)

Year Unit 4 Unit 5 Unit 6 Unit 7 Total

1998 825 1,370 4,364 7,557 

### 14,116

1999 893 782 4,715 8,308 

### 14,697

2000 860 1,146 3,986 6,915 

### 12,907

2001 830 748 3,906 4,971 

### 10,455

2002 840 854 3,518 6,355 

### 11,567

2003 1,073 1,088 4,965 7,873 

### 14,999

2004 1,122 1,106 4,382 4,563 

### 11,173

2005 1,084 991 4,286 1,032 

### 7,393

2006 996 925 2,871 1,619 

### 6,411

2007 1,021 920 2,620 1,394 

### 5,956

2008 677 826 1,823 1,344 

### 4,669

Gulf Power Crist

- SO2 (tons per year)

Year Unit 4 Unit 5 Unit 6 Unit 7 Total

1998 2,940 3,684 14,342 23,667 

### 44,634

1999 2,918 2,227 13,102 22,829 

### 41,075

2000 3,547 4,839 14,135 24,470 

### 46,991

2001 3,454 3,247 13,020 17,462 

### 37,183

2002 3,691 3,576 11,085 20,600 

### 38,953

2003 2,986 2,961 11,467 17,447 

### 34,862

2004 3,554 3,647 10,399 15,089 

### 32,688

2005 3,130 2,941 10,744 11,416 

### 28,231

2006 3,066 2,968 9,612 17,847 

### 33,493

2007 3,553 3,449 12,768 19,737 

### 39,507

2008 2,472 3,047 10,023 21,091 

### 36,633



### The emissions of NOx and SO2 used in the SIP modeling for the base year 2002 and

the projected year 2018 are shown in the tables below.

Gulf Power Crist

- NOx (tpy)

Unit 2002 2018

Unit 4 840 729



### Unit 5 854 1,106



### Unit 6 3,793 6,024



### Unit 7 8,164 1,116



### Total 13,650 8,975

### Gulf Power Crist

- SO2 (tpy)

Unit 2002 2018

Unit 4 3,691 304



### Unit 5 3,576 277



### Unit 6 11,236 1,242



### Unit 7 24,184 4,648



### Total 42,687 6,470



### Current (2008) emissions of NOx are much less (nearly half) the projected 2018

emissions. In addition, the SIP projections for 2018 assumed no NOx controls on units

4 and 5, SNCR on unit 6 and SCR on unit 7. The actual configuration now is for SNCR

on units 4 and 5, and SCR on both 6 and 7. As a result, the SIP modeling is overestimating the impacts on visibility from NOx emissions at Crist.

Current (2008) emissions of SO2 are much greater than the projected 2018 emissions

used in the SIP modeling. However, a scrubber servicing all four units will be on-line by

the end of 2009. This will make the SO2 emissions in-line with the 2018 projections

used in the SIP modeling.