Appendix B: 

Point Source SO2 Emissions Reductions 
SCE&G Facility Reductions Analysis.................................................................................3 

SCE&G Press Release (May 30, 2012) .............................................................................11 

Duke Energy: Progress Energy Press Release (July 27, 2012)..........................................12 

Duke Energy: Progress Energy Robinson Retired Unit Exemption (October 18, 2012)...14 

Santee Cooper: Grainger & Jefferies Press Release (October 19, 2012)...........................22 

Santee Cooper Consent Decree (June 24, 2004)................................................................24 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 1
Since sulfates have been shown to be the predominant species of concern to visibility impairment 

at Cape Romain during the first round of regional haze planning, the Department of Health and 

Environmental Control (DHEC) conducted an analysis of the emissions at several of the large 

electric generating units (EGUs) in the State. This analysis of South Carolina Electric & Gas 

(SCE&G) facilities in the state indicate that SO2 emissions over the last decade have decreased 

significantly. Of the three sources that experienced slight increases in SO2 emissions (Canadys, 

McMeekin, and Urquhart), SCE&G recently announced as part of the annual Integrated 

Resource Plan filed with the Public Service Commission of South Carolina, its plans to retire up 

to six coal-fired generating units at three locations by the end of 2018. The retirement of these 

units will serve to further reduce SO2 emissions in the South Carolina, ensuring that the state will 

meet its reasonable progress goals in the future. A pronounced decline in economic activity and 

curtailment of natural gas lead to the replacement of coal as the primary source of fuel for many 

of the facilities within the last few years. The following figures and tables provide emission 

information on the SCE&G facilities in the state. 

Figure 1: SCE&G Network SO2 Emissions in Tons/Year

SCE&G Network of PC-Fired Facilities

0

20,000

40,000

60,000

80,000

100,000

120,000

19971998199920002001200220032004200520062007200820092010

Year

SO2 Tons

Canadys

Cope

McMeekin

Urquhart

Wateree

Williams

Network

Sum

Running

Average

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 2
Table 1: SCE&G Network SO2 Emissions in Tons/Year 

 

Year Canadys Cope McMeekin Urquhart Wateree Williams Sum Average

5-Year Rolling

Average

 

1997 12,810 2,275 15,453 11,518 35,550 25,399 103,005 103,005 

1998 17,345 2,496 16,839 11,961 36,387 18,598 103,626 103,316 

1999 11,877 2,347 14,894 13,251 39,501 24,937 106,807 104,479 

2000 18,667 2,012 14,155 13,990 31,184 24,205 104,213 104,413 

2001 22,038 1,464 12,773 12,878 34,925 22,789 106,867 104,904 104,904

2002 18,591 1,879 9,820 5,510 36,378 25,544 97,722 103,707 103,847

2003 19,890 2,215 12,010 6,370 33,069 20,008 93,562 102,257 101,834

2004 27,088 2,689 11,509 5,780 39,421 20,718 107,205 102,876 101,914

2005 19,558 2,293 14,427 5,961 37,774 28,063 108,076 103,454 102,686

2006 22,984 2,603 13,308 6,738 32,797 28,147 106,577 103,766 102,628

2007 17,881 2,334 10,647 7,172 30,939 22,494 91,467 102,648 101,377

2008 17,966 1,817 12,996 5,876 35,471 22,923 97,049 102,181 102,075

2009 9,629 1,595 6,585 4,422 27,992 16,920 67,143 99,486 94,062

20101 12,680 1,759 9,680 5,161 18,239 947 48,466 95,842 82,140

1 Scrubbers became operational at Wateree and Williams 

Source: USEPA Acid Rain 

Note: The “Average” field is an average of all available annual data from 1997 to date. The 

1998 Average includes annual data from 1997 and 1998 (2 years), while the 2010 Average 

includes data from 1997-2010 (14 years). The second Average column provides the 5-year 

rolling average for comparison. 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 3
Figure 2: SCE&G Canady’s SO2 Emissions in Tons/Year

SCE&G-Canadys Station (ORIS 3280)

0

5,000

10,000

15,000

20,000

25,000

30,000

1997

1998

1999

2000

2001

2002

2003

2004

2005

2006

2007

2008

2009

20

Year 10 SO2 Tons

ARP

Annual

Actuals

ARP

Annual

Average

Note: “ARP” means Acid Rain Program 

Table 2: SCE&G Canady’s SO2 Emissions in Tons/Year 

Year 

SO2

Tons Average 

 

1997 12,810 12,810 

1998 17,345 15,078 

1999 11,877 14,011 

2000 18,667 15,175 

2001 22,038 16,547 

2002 18,591 16,888 

2003 19,890 17,317 

2004 27,088 18,538 

2005 19,558 18,652 

2006 22,984 19,085 

2007 17,881 18,975 

2008 17,966 18,891 

2009 9,629 18,179 

2010 12,680 17,786 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 4
Figure 3: SCE&G Cope’s SO2 Emissions in Tons/Year

SCE&G-Cope Station (ORIS 7210)

0

500

1,000

1,500

2,000

2,500

3,000

19971998199920002001200220032004200520062007200820092010

Year SO2 Tons

ARP

Annual

Actuals

ARP

Annual

Average

Note: “ARP” means Acid Rain Program 

Table 3: SCE&G Cope’s SO2 Emissions in Tons/Year 

Year 

SO2

Tons Average 

 

1997 2,275 2,275 

1998 2,496 2,386 

1999 2,347 2,373 

2000 2,012 2,283 

2001 1,464 2,119 

2002 1,879 2,079 

2003 2,215 2,098 

2004 2,689 2,172 

2005 2,293 2,186 

2006 2,603 2,227 

2007 2,334 2,237 

2008 1,817 2,202 

2009 1,595 2,155 

2010 1,759 2,127 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 5
Figure 4: SCE&G McMeekin’s SO2 Emissions in Tons/Year

SCE&G-McMeekin Station (ORIS 3287)

0

2,000

4,000

6,000

8,000

10,000

12,000

14,000

16,000

18,000

19971998199920002001200220032004200520062007200820092010

Year

SO2 Tons

ARP

Annual

Actuals

ARP

Annual

Average

Note: “ARP” means Acid Rain Program 

Table 4: SCE&G McMeekin’s SO2 Emissions in Tons/Year 

Year 

SO2

Tons Average 

 

1997 15,453 15,453 

1998 16,839 16,146 

1999 14,894 15,729 

2000 14,155 15,335 

2001 12,773 14,823 

2002 9,820 13,989 

2003 12,010 13,706 

2004 11,509 13,432 

2005 14,427 13,542 

2006 13,308 13,519 

2007 10,647 13,258 

2008 12,996 13,236 

2009 6,585 12,724 

2010 9,680 12,507 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 6
Figure 5: SCE&G Urguhart’s SO2 Emissions in Tons/Year

SCE&G-Urquhart Station (ORIS 3295)

0

2,000

4,000

6,000

8,000

10,000

12,000

14,000

16,000

19971998199920002001200220032004200520062007200820092010

Year

SO2 Tons

ARP

Annual

Actuals

ARP

Annual

Average

Note: “ARP” means Acid Rain Program 

Table 5: SCE&G Urguhart’s SO2 Emissions in Tons/Year 

Year 

SO2

Tons Average 

 

1997 11,518 11,518 

1998 11,961 11,740 

1999 13,251 12,243 

2000 13,990 12,680 

2001 12,878 12,720 

2002 5,510 11,518 

2003 6,370 10,783 

2004 5,780 10,157 

2005 5,961 9,691 

2006 6,738 9,396 

2007 7,172 9,194 

2008 5,876 8,917 

2009 4,422 8,571 

2010 5,161 8,328 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 7
Figure 6: SCE&G Wateree’s SO2 Emissions in Tons/Year

SCE&G-Wateree Station (ORIS 3297)

0

5,000

10,000

15,000

20,000

25,000

30,000

35,000

40,000

45,000

19971998199920002001200220032004200520062007200820092010

Year

SO2 Tons

ARP

Annual

Actuals

ARP

Annual

Average

Note: “ARP” means Acid Rain Program 

Table 6: SCE&G Wateree’s SO2 Emissions in Tons/Year 

Year 

SO2

Tons Average 

 

1997 35,550 35,550 

1998 36,387 35,969 

1999 39,501 37,146 

2000 31,184 35,656 

2001 34,925 35,509 

2002 36,378 35,654 

2003 33,069 35,285 

2004 39,421 35,802 

2005 37,774 36,021 

2006 32,797 35,699 

2007 30,939 35,266 

2008 35,471 35,283 

2009 27,992 34,722 

2010 18,239 33,545 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 8
Figure 7: SCE&G William’s SO2 Emissions in Tons/Year

SCGenCo-Williams Station (ORIS 3298)

0

5,000

10,000

15,000

20,000

25,000

30,000

1997

1998

1999

2000

2001

2002

2003

2004

2005

2006

2007

2008

2009

2010

Year SO2 Tons

ARP

Annual

Actuals

ARP

Annual

Average

Note: “ARP” means Acid Rain Program 

Table 7: SCE&G William’s SO2 Emissions in Tons/Year 

Year 

SO2

Tons Average 

 

1997 25,399 25,399 

1998 18,598 21,999 

1999 24,937 22,978 

2000 24,205 23,285 

2001 22,789 23,186 

2002 25,544 23,579 

2003 20,008 23,069 

2004 20,718 22,775 

2005 28,063 23,362 

2006 28,147 23,841 

2007 22,494 23,718 

2008 22,923 23,652 

2009 16,920 23,134 

2010 947 21,549 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 9
SCANA Public Affairs  Cayce, S.C. 29033  T (800) 562.9308  F (803) 217.8825  www.scana.com

For Immediate Release 

Contact: Public Affairs: 1-800-562-9308

SCE&G announces plans to retire 

a portion of its coal-fired generation 

CAYCE, S.C. (May 30, 2012) – As part of its annual Integrated Resource Plan filed today with the Public 

Service Commission of South Carolina, South Carolina Electric & Gas (SCE&G) announced plans to 

retire up to six coal-fired generating units at three locations by the end of 2018. The units range in age 

from 45 to 57 years and are SCE&G’s oldest and smallest coal-fired units. 

The Environmental Protection Agency in recent years has issued a series of increasingly stringent 

regulations targeting coal-fired electric generating plants. Since 2008, SCE&G has installed more than 

$600 million in environmental equipment at its largest coal-fired power plants, significantly reducing 

emissions of sulfur dioxide, nitrogen oxides and mercury. However, the company determined that adding 

costly environmental control equipment to these older plants to ensure compliance with the new 

regulations would not at this time be a good business decision. 

“Since announcing our new nuclear project in 2008, we’ve said that the addition of the two new nuclear 

units would give us flexibility to look at reducing our reliance on coal and allow us to achieve better fuel 

diversity in our electric generation portfolio,” said Kevin Marsh, Chairman and CEO of SCE&G’s parent 

company, SCANA Corp. “With the planned retirement of these coal units and the addition of our two new 

nuclear units, we anticipate that by the end of 2018 roughly one-third of our electric generation will be 

fueled by nuclear power, one-third by natural gas, and one-third by scrubbed coal-fired plants. These 

changes will help us meet the increasingly stringent environmental regulations facing our industry and 

should position SCE&G to be a leader in non-emitting generation well into the future.” 

Near term steps SCE&G outlined in its IRP include: 

• Retirement of Unit 1 at the Canadys Plant near Walterboro by the end of 2012 

• Switching Unit 3 at the Urquhart Plant near Aiken from coal to entirely natural gas by the end of 

2012 

Additional planned steps include: 

• Planned switching of Units 1 and 2 at the McMeekin Plant near Irmo and Units 2 and 3 at the 

Canadys Plant from coal to entirely natural gas by 2015 

• Planned retirement of the remaining two units (Units 2 and 3) at Canadys by the end of 2017 

• Planned retirement of both Units 1 and 2 at the McMeekin Plant by the end of 2018 

• Planned retirement of Unit 3 at Urquhart by the end of 2018 

SCE&G employs a total of about 170 people at these three plants. The retirement of Unit 1 at Canadys 

and the switching of Urquhart Unit 3 to natural gas are expected to impact 20 positions. The company will 

assist affected employees in looking for other positions within the company. “These units and their 

employees have served our customers well for decades, and we appreciate their service,” said Marsh. 

SCE&G is a regulated utility engaged in the generation, transmission, distribution and sale of electricity to 

approximately 668,000 customers in South Carolina. The company also provides natural gas service to 

approximately 319,000 customers throughout the state. More information about SCE&G is available at 

www.sceg.com. 

### 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 10
RALEIGH, N.C. -

Progress Energy Carolinas Announces Accelerated Coal Plant

Closings

July 27, 2012

Progress Energy Carolinas, a subsidiary of Duke Energy, will accelerate the retirement of one North Carolina

coal-fired power plant previously slated for closing in 2013, and will retire the utility’s only coal-fired unit in South Carolina.

The company announced today that the 316-megawatt (MW) Cape Fear coal-fired plant, located near Moncure, N.C., and the 177-

MW H.B. Robinson Unit 1 coal-fired plant, located near Hartsville, S.C., will be retired Oct. 1, 2012. Both will remain online

through the summer season to help meet heightened electricity demand.

“These plants, and especially the men and women who have operated and maintained them, have played a vital role in meeting

customer energy needs reliably and affordably for decades,” said Jeff Lyash, executive vice president of Energy Supply for Duke

Energy. “As we continue modernizing our generation system, we salute those who have been instrumental in fueling our region’s

economic growth so dependably.”

The Cape Fear Plant is the utility’s first coal-fired facility and was scheduled to retire June 2013 as part of the company’s fleetmodernization plan, announced in 2009. Three oil-fired combustion turbines will continue to operate at the site after the coal

plant’s retirement.

The Robinson coal plant in South Carolina began operation in 1960 and is located on the same site as the 724-MW Robinson

nuclear plant. The decision to take the 52-year-old Robinson coal plant offline was made due to pending changes in environmental

regulations and other rising costs for smaller, older technology plants. The cost of adding state-of-the-art emission controls on the

small unit would be hundreds of millions of dollars. And the potential for additional emission regulations in the future would

increase operating costs even further.

Other factors leading to the decision to retire the Cape Fear Plant and Robinson Unit 1 in October 2012 include the anticipated

early 2013 commercial operation of new natural gas-fired generation at the H.F. Lee Plant near Goldsboro, N.C., continued low

natural-gas prices and the success of the newly merged company’s joint-dispatch process that utilizes generation across both Duke

Energy Carolinas and Progress Energy Carolinas to more efficiently meet customer needs.

Currently, Duke Energy Carolinas and Progress Energy Carolinas are moving about 1,000 MWs between them through the jointdispatch agreement related to the July 2012 merger of Duke Energy and Progress Energy. Each megawatt-hour that flows between

these systems represents savings for the company’s customers and progress toward meeting the company’s $650 million mergerrelated savings commitment.

The Robinson coal plant retirement does not affect the Robinson nuclear plant, which is licensed for continued operation through

2030. Nor does it affect the company’s other major generation in South Carolina, the 790-MW Darlington County Plant, which is

located near the Robinson plant and includes 13 combustion-turbine units fueled by natural gas and oil.

Fleet modernization plan

On Oct. 1, 2011, the company retired the coal-fired W.H. Weatherspoon Power Plant near Lumberton, N.C., the first retirement

under the fleet-modernization plan. Other plants slated for retirement include the H.F. Lee Plant near Goldsboro, N.C., in

September 2012 and the L.V. Sutton Plant near Wilmington, N.C., in late 2013. Including the Robinson and Cape Fear plants, the

retirements represent more than 1,600 MW, or approximately one-third of Progress Energy Carolinas’ coal-generating fleet.

Progress Energy Carolinas has two projects under way to replace the retiring coal-fueled generating capacity with plants fueled by

natural gas. A new 920-MW natural gas-fueled combined-cycle facility is under construction at the H.F. Lee Plant site near

Goldsboro. That project, including a gas pipeline extension, is expected to begin commercial operation in January 2013.

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 11
At the Sutton Plant site near Wilmington, Progress Energy Carolinas is building a gas-fueled combined-cycle plant with a

generating capacity of 625 MW. That addition, with a corresponding natural gas pipeline extension into southeastern North

Carolina, is expected to be online at the end of 2013.

In June 2011, the company completed the addition of 600 MW of natural gas-fueled generation at the Sherwood H. Smith Jr.

Energy Complex near Hamlet, N.C. (formerly called the Richmond County Energy Complex).

Progress Energy Carolinas has worked to minimize job losses associated with the fleet-modernization plan through employee

retirements, the company’s voluntary severance plan and by assisting employees with retraining and transfers to other parts of the

company.

In addition, as part of the fleet-modernization plan, the utility has invested more than $1 billion in environmental technology to

reduce emissions dramatically at Progress Energy Carolinas’ remaining coal-fired plants – the Roxboro and Mayo plants in Person

County and the Asheville Plant in Buncombe County. Progress Energy Carolinas will continue to operate those three coal-fired

facilities after the others are retired.

About Progress Energy Carolinas:

Progress Energy Carolinas, a subsidiary of Duke Energy, provides electricity and related services to nearly 1.5 million customers in

North Carolina and South Carolina. The company is headquartered in Raleigh, N.C., and maintains a diverse generation fleet of

more than 12,200 megawatts in owned capacity. PEC serves a territory encompassing more than 34,000 square miles, including

the cities of Raleigh, Wilmington and Asheville in North Carolina and Florence and Sumter in South Carolina.

More information is available at www.progress-energy.com (http://www.progress-energy.com) .

CONTACT:

24-hour media line: 800-559-DUKE (3853)

Follow Progress Energy Carolinas on Twitter: www.twitter.com/ProgEnergyNC_SC

(http://www.twitter.com/ProgEnergyNC_SC)

Follow Progress Energy Carolinas on Facebook: www.facebook.com/ProgressEnergyCarolinas

(http://www.facebook.com/ProgressEnergyCarolinas)

Back to News Releases (/news/default.asp)

©Duke Energy Corporation All Rights Reserved

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 12
Corporate Communications & Media Relations • 1 Riverwood Dr. • Moncks Corner SC • 29461 • Fax 843-761-7060 

 Oct. 19, 2012 

Media Contact: Mollie Gore 

 Corporate Communications 

 843-761-7093 

mollie.gore@santeecooper.com

 

Santee Cooper board authorizes retirements of 

Jefferies and Grainger generating units 

MONCKS CORNER, S.C. – The Santee Cooper Board of Directors voted today to authorize 

retirement of six electric generating units at its two oldest stations, after considering Santee Cooper’s 

generation resource needs and the cost of complying with new environmental regulations. The board 

directed its president and CEO to take charge of developing and executing plans for an orderly 

retirement of the four coal and two oil units. 

The vote marks Santee Cooper’s first unit retirements since the state-owned utility first generated 

power 70 years ago. Santee Cooper was established in 1934, first generated electricity in 1942 and 

today has 165,000 direct-serve customers and hundreds of thousands more who receive Santee 

Cooper electricity through the state’s 20 electric cooperatives, in all 46 counties of South Carolina. 

“As we evaluated the anticipated costs of complying with new regulations and the generation 

resources we anticipate needing, it became clear that the best action for our customers and the state is 

to authorize the retirement of these units at Jefferies and Grainger,” Board Chairman O.L. 

Thompson said. “It is not a decision we make lightly. However, it is the most cost-effective move we 

can make.” 

Santee Cooper expects to relocate affected employees to other positions made available through 

attrition, and so layoffs are not anticipated. There is no timetable yet for the unit retirements, 

although Grainger’s units were idled in the spring. 

“Santee Cooper’s primary responsibility is to provide South Carolina with affordable, reliable and 

environmentally protective electricity, and today’s board vote supports that responsibility,” said 

President and CEO Lonnie Carter. “Even so, this was a difficult recommendation for management to 

make, given the important legacies of these two generating stations to our utility, our state and to the 

communities around them.” 

Jefferies Generating Station, located in Moncks Corner, has four units slated to be retired: two are 

coal-fired and two use oil. The oldest two units date to 1954, units 3 and 4 came online in 1970, and 

SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 13
Corporate Communications & Media Relations • 1 Riverwood Dr. • Moncks Corner SC • 29461 • Fax 843-761-7060 

the four have a combined capacity of 398 megawatts. The decision does not affect Jefferies 

Hydroelectric Generating Station. 

Grainger Generating Station, located in Conway, came online in 1966 and has a capacity of 170 

megawatts. The station has been idle since earlier this year as Santee Cooper continued evaluating 

potential impacts of the U.S. Environmental Protection Agency’s new Mercury and Air Toxics 

Standard (MATS) for air emissions, issued last December. 

Santee Cooper continues its evaluation of MATS requirements affecting its other, newer fossil fueled 

generating units. The utility has an excellent record of environmental stewardship and was the first in 

South Carolina to install scrubbers on generating units, among other achievements. 

“Our priority now will be to evaluate next steps and establish a timetable for retiring the units,” 

Carter said. “I recognize that these will be important decisions potentially impacting many people, 

and we will be inclusive and transparent as we go forward. These stations are neighbors to thousands 

of our customers, after all, and we fully intend to remain involved in these communities.” 

Santee Cooper is South Carolina’s state-owned electric and water utility, and the state’s largest power 

producer. The ultimate source of electricity for 2 million South Carolinians, Santee Cooper is 

dedicated to being the state’s leading resource for improving the quality of life for the people of South 

Carolina. For more information, visit www.santeecooper.com.

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SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 104
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 105
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 106
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 107
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 108
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 109
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 110
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 111
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 112
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 113
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 114
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 115
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 116
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 117
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 118
SC SIPR: Regional Haze Periodic Update Appendix B December 2012 - 119