Canadian Energy Research Institute

North American Natural Gas Market Dynamics: Coal-fired Generation in North America – A Review

Paul Kralovic

Study No. 123 – Section III

March 2011

Relevant • Independent • Objective

NORTH AMERICAN NATURAL GAS MARKET DYNAMICS: COAL-FIRED GENERATION IN NORTH AMERICA – A REVIEW

North American Natural Gas Market Dynamics: Coal-fired Generation in North America – A Review

Copyright © Canadian Energy Research Institute, 2011 Sections of this study may be reproduced in magazines and newspapers with acknowledgement to the Canadian Energy Research Institute

Study No. 123 – Section III ISBN 1-896091-97-0

Author: Paul Kralovic*

*Paul Kralovic is an external consultant and is the Director of Calgary-based Kralovic Economics Inc.

Acknowledgements: The author of this report would like to extend his thanks and gratitude to everyone involved in the production and editing of the material, including, but not limited to Megan Murphy and Peter Howard

CANADIAN ENERGY RESEARCH INSITTUTE 150, 3512 – 33 Street NW Calgary, Alberta T2L 2A6 Canada www.ceri.ca

March 2011 Printed in Canada

North American Natural Gas Market Dynamics: iii Coal-fired Generation in North America – A Review Table of Contents

LIST OF FIGURES ...... v LIST OF TABLES ...... vii COAL-FIRED GENERATION IN NORTH AMERICA – A REVIEW ...... 1 Objective of the Study ...... 1 Background...... 2 Coal-fired Power Generation in the US ...... 6 Coal-fired Power Generation in Canada ...... 18 APPENDIX A EXISTING GENERATING UNITS OVER 100 MW IN THE US BY STATE, COMPANY, PLANT NAME, CAPACITY AND AGE OF UNIT ...... 33 APPENDIX B COAL POWER STATIONS IN CANADA BY PROVINCE, STATION NAME FIRST UNIT COMMISSIONED DATE, AGE AND INSTALLED CAPACITY ...... 55

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March 2011 North American Natural Gas Market Dynamics: v Coal-fired Generation in North America – A Review List of Figures

Figure 1.1 Proven Recoverable Coal Reserves at end-2009 by Region ...... 4 Figure 1.2 Top 5 Producers of Coal in the World (1999-2009) ...... 5 Figure 1.3 Top 5 Consumers of Coal in the World (1999-2009) ...... 6 Figure 1.4 Total (All Sectors) Net Generation Share by Energy Source Year-to-Date through November 2009 ...... 7 Figure 1.5 Total Cost Power Electricity Generation between 2001 and 2010 ...... 9 Figure 1.6 Top 20 US States by Coal Power Electricity Generation in 2009 ...... 9 Figure 1.7 Top 20 US States by Number of Coal-fired Plants at end-2008 ...... 10 Figure 1.8 Top 20 US States by Coal Power Nameplate Capacity at end-2008 ...... 11 Figure 1.9 Cumulative Total Cost Power Capacity in the US ...... 12 Figure 1.10 Age and Size of Capacity of Coal-fired Power Units in the US ...... 14 Figure 1.11 Net Electricity Generation by Fuel, 2990-2035 ...... 15 Figure 1.12 Coal Plant Retirements, Cumulative Total by State (50-years Life) ...... 16 Figure 1.13 Planned Electric Generation Capacity Additions ...... 17 Figure 1.14 Number of Planned Generators ...... 18 Figure 1.15 Total Electricity Generation in Canada, 1990-2008 ...... 19 Figure 1.16 Electricity Generation by Energy Source, 2008 ...... 20 Figure 1.17 Electricity Generation by Energy Source, 1990-2008...... 20 Figure 1.18 Installed Generating Capacity by Energy Source in Canadian Provinces, 2006 ...... 21 Figure 1.19 Coal-fired Electricity Generation in Canada, 1990-2008 ...... 22 Figure 1.20 Share of Coal-fired Electricity Generation Capacity in Canada by Province ...... 23 Figure 1.21 Cumulative Total Coal Power Capacity in Canada...... 30 Figure 1.22 Coal Plant Retirements, Cumulative Total by Province (50-year Life) ...... 31

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North American Natural Gas Market Dynamics: vii Coal-fired Generation in North America – A Review List of Tables

Table 1.1 Top 10 Proven Recoverable Coal Reserves at end-2009 ...... 3 Table 1.2 Total Electric Power Industry Summary Statistics, Year-to-Date 2010 and 2009 ...... 8 Table 1.3 Top 10 Generating Units by State, Company and Plant, end-2008...... 12 Table 1.4 Top 10 Producers of Coal-fired Electricity in the US, 2005 ...... 13 Table 1.5 Top 5 Coal-fired Power Plants in Canada, 2011 ...... 29

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March 2011 North America Natural Gas Market Dynamics: Coal-fired Generation in North America – A Review 1

North American Natural Gas Market Dynamics: Coal-fired Generation in North America – A Review

Objective of the Study Coal power plants conjure up strong images for individuals and groups on both sides of a raging debate about the future of electricity generation and the environment.

In June 2004, Ontario’s Premier McGuinty unveiled a bold plan to restructure the province’s electricity system.1 In spite of facing a growing gap between future supply and demand, Ontario’s Long Term Energy Plan (LTEP) proposed phasing out its coal-fired generation. Over six years later, as part of the Open Ontario Plan, an update of the LTEP, the province is moving steadily to permanently shut down all coal-fired generation by 2014—the single largest source of greenhouse gas (GHG) emissions in Ontario.2 In October 2010, 2 units at Nanticoke and 2 units at Lambton were permanently shut down.3 Between the aforementioned and the shut-down of the 4-unit Lakeview in 2005, Ontario suggests that their coal use has decreased by 70 percent.4 Similar movements are occurring in other jurisdictions in North America—and other parts of the world. Whether they are changes in national legislation and regulation, or state/provincial programs and initiatives promoting reductions in GHGs or increasing the use of various renewables, many jurisdictions are trying to discover the balance between minimizing environmental impacts and maintaining a modern, reliable electricity system.

On the other side of the debate, the coal industry suggests that clean coal technology and the advent of other technologies make coal not only a cheap and reliable source of fuel, but a clean one as well. While coal-fired generation is mature and plays an important role, both in North America and globally, coal-fired technology is not stagnant. Technologies that offer cleaner coal options include: supercritical coal-fired generation, CO2/O2 5 6 combustion, CO2 capture and sequestration, beneficiation and Integrated Gasification Combined Cycle (IGCC).

This study focuses on North America and the current state of coal-fired generation in the United States and Canada. While not providing a synopsis of who is pulling and pushing in the debate to find a balance over energy production and the environment, this study reviews the role of coal-fired electricity generation now and what it may look like in the future.

1‘McGuinty Government Unveils Bold Plan to Restructure Electricity System’, News Release, Ontario Ministry of Energy, June 15, 2004. 2Government of Ontario, Newsroom, “Moving Ontario from Dirty Coal to a Clean Energy Future”, October 1, 2010, http://news.ontario.ca/mei/en/2010/10/moving-ontario-from-dirty-coal-to-a-clean-energy-future.html 3ibid 4“Ontario’s Long-term Energy Plan: Building Our Clean Energy Future”, Government of Ontario, 2010, pp. 3. 5Graham R. Campbell, “Clean Coal Developments in Canada Towards a Sustainable Energy Future”, NRCAN, presented at Nova Scotia’s Energy R&D Forum, May 24-25, 2006, pp. 10. 6“Coal-fired Power Generation: A Perspective” National Energy Board, July 2008, pp 3-4.

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This study is divided into three sections: Background, Coal-fired Power Generation in the US and Coal-fired Power Generation in Canada. Before examining the current state of coal-fired generation in North America, it is prudent to first set North America in a global setting. This section reviews global coal reserves, production and consumption. The current state of coal-fired power generation in North America explores various elements and information of the industry in the US and Canada.

Background The world’s thirst for energy is growing, as is the demand for energy in North America. In its World Energy Outlook 2008, the International Energy Agency (IEA) predicts that in the Reference Case, global demand for energy will increase 45 percent by 2030 and fossil fuels, such as coal, will provide 80 percent of our energy needs by 2030.7 The US Energy Information Administration (EIA) shares this sentiment, suggesting that fossil fuels will represent 80 percent of the world’s energy in 2030.8 The IEA predicts that coal share of global energy demand will increase from 26 to 29 percent.9

And why not? Coal, especially in the US, is both cheap and plentiful, with some industry pundits stating that the US is the Saudi Arabia of coal. The EIA estimates that there are 948 billion short tonnes of coal that are recoverable at end-2008.10 This is an astonishing number considering that it includes reserves that are known at this current time. The above is mirrored by BP, which estimated that there are 826 million tonnes of proven coal reserves worldwide at end-2009.11 This equates to a reserves-to-production ratio (R/P)—the reserves remaining at the end of the year divided by the production in that year—of 119 years.12 The IEA estimates that at end-2005 proven reserves were 847 million tonnes.13

Table 1.1 illustrates the top 10 proven recoverable coal reserves at end-2008.

7International Energy Agency (IEA), World Energy Outlook 2008, pp. 38. 8Energy Forecasts Agree on Global Fossil Fuel Domination, Institute for Energy Research, February 22, 2011, http://www.instituteforenergyresearch.org/2011/02/22/energy-forecasts-agree-on-global-fossil-fuel-domination/ 9International Energy Agency (IEA), World Energy Outlook 2008, pp. 78. 10International Energy Agency (IEA), International Energy Statistics, http://www.eia.doe.gov/cfapps/ipdbproject/ IEDIndex3.cfm?tid=1&pid=7&aid=6 11BP Statistical Review of World Energy”, June 2010, pp. 32, http://www.bp.com/sectiongenericarticle.do? categoryId=9023784&contentId=7044480 12ibid 13International Energy Agency (IEA), World Energy Outlook 2008, pp. 127.

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Table 1.1 Top 10 Proven Recoverable Coal Reserves at end-2009 (million tonnes) Sub- Share of Bituminous & Country bituminous Total World Total Anthracite & Lignite (%) United States 108,950 129,358 238,308 28.9 Russia 49,088 107,922 157,010 19.0 China 62,200 52,300 114,500 13.9 Australia 36,800 39,400 76,200 9.2 India 54,000 4,600 58,600 7.1 Ukraine 15,351 18,522 33,873 4.1 Kazakhstan 28,170 3,130 31,300 3.8 South Africa 30,408 0 30,408 3.7 Brazil 0 7,059 7,059 0.9 Poland 6,012 1,490 7,502 0.9 Source: BP14

It is important to note that the total recoverable coal reserves are divided into bituminous & anthracite and sub- bituminous & lignite. The shiny, black anthracite is the highest rank of coal and the oldest.15 Bituminous coal is also black, but is sometimes brownish in colour.16 Sub-bituminous coal has a lower rank than its bituminous counterpart. It is slightly lighter that bituminous coal as it is less mature.17 Lignite has the lowest rank of the discussed types of coal and is quite light in colour and is soft.18

According to BP’s World Statistical Review, Canada’s reserves rank them 11th in the world. Canada’s proven recoverable coal reserves are 6,578 million tonnes, of which 3,471 million tonnes is bituminous and anthracite and 3,107 million tonnes of sub-bituminous and lignite.

Figure 1.1 illustrates proven recoverable coal reserves at end-2009 by region.

14BP Statistical Review of World Energy”, June 2010, pp. 32, http://www.bp.com/sectiongenericarticle.do? categoryId=9023784&contentId=7044480 15Kentucky Geological Survey, “Classification and Rank of Coal”, http://www.uky.edu/KGS/coal/coalkinds.htm 16ibid 17ibid 18ibid

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Figure 1.1 Proven Recoverable Coal Reserves at end-2009 by Region (million tonnes)

31.4% 29.8%

1.8% 33.0% 4.0%

North America S. & Cent. America Europe & Eurasia Middle East & Africa Asia Pacific

Source: BP19

In terms of continental and regional divisions, Europe and Eurasia have the highest coal reserves at 272. 2 million tonnes followed by Asia Pacific at 259.3 million tonnes and North America at 246.1 million tonnes.20 It is interesting to note that of the fossil fuels, coal reserves are more geographically dispersed than oil and natural gas reserves, being produced in over 100 countries.

Figure 1.2 shows the top 5 global producers of coal between 1999 and 2009, and their production in million tonnes.

China’s production of coal in 2009 accounts for a whopping 45.6 percent share of the total coal produced in the world. A distant second-ranked US accounts for 15.8 percent of production. Australia, India and Indonesia account for 6.7, 6.2 and 4.6 percent, respectively. India and Indonesia, however, are quickly increasing their coal production. Canada’s share of total coal production is 1.0 percent.

19BP Statistical Review of World Energy”, June 2010, pp. 32, http://www.bp.com/sectiongenericarticle.do? categoryId=9023784&contentId=7044480 20ibid

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Figure 1.2 Top 5 Producers of Coal in the World (1999-2009) 1800 1600 1400 1200 1000 800 600 400 200 0 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

US Australia China India Indonesia

Source: BP21

It is interesting to note the R/P ratio for several of these previously mentioned countries. The R/P ratio for China is 38 years, which is relatively small compared to other nations. The US, for example, has an R/P ratio of 245 years. Australia, India and Indonesia have R/P ratios of 186, 105 and 17 years, respectively. Russia leads the world with an R/P ratio of over 500 years, which is closely followed by the Ukraine at 460 years. All of the abovementioned R/P ratio’s are from BP’s World Statistical Review.22

In terms of production the US is certainly considered a major player, while Canada can be considered a mid-size player on the global stage. The top 5 largest producers of coal in the US are Wyoming, West Virginia, Kentucky, Pennsylvania and Montana.23 These states produce approximately 777,073 thousand short tonnes of coal; Wyoming produces an astonishing 431,107 thousand short tonnes of coal by itself.24 This accounts for 72 percent of total production in the US. It is, however, important to point out that there are 1,375 mines in the US spread out over 25 states—a diverse resource indeed.25 In Canada there are 22 coal mines, as of June 2010.26 The major coal producers are Alberta, British Columbia and Saskatchewan while Nova Scotia and New Brunswick are considered minor producers.27

21BP Statistical Review of World Energy”, June 2010, pp. 34, http://www.bp.com/sectiongenericarticle.do? categoryId=9023784 &contentId=7044480 22ibid 23EIA website, Coal Production and Number of Mines by State and Coal Rank, 2009, http://www.eia.doe.gov/ cneaf/coal/page/acr/table6.pdf 24ibid 25ibid 26Kevin Stone, Coal in Canada, NRCAN, presentation to the APEC Clean Fossil Energy Technical and Policy Seminar, October 2010, pp. 3. 27ibid

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Figure 1.3 illustrates the top 5 consumers of coal globally between 1999 and 2009. China’s consumption of coal in 2009 accounts for a whopping 46.9 percent share, slightly higher than their production. Second-ranked US accounts for 15.2 percent of production. India, Japan and South Africa have 7.5 percent, 3.3 percent and 3.0 percent, respectively. Canada’s share of total coal consumption is 0.8 percent.

Figure 1.3 Top 5 Consumers of Coal in the World (1999-2009) 1800 1600 1400 1200 1000 800 600 400 200 0 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

US South Africa China India Japan

Source: BP28

In terms of production and consumption of coal, Asia Pacific is the largest player of coal globally—and increasing their lead substantially. Much of this is attributed to ever-increasing Chinese consumption and production. China, however, is not the only country in the region to utilize coal. The top 5 importers of coal are all from the Asia Pacific region: Japan, China, South Korea, India and Taiwan.29

Coal undoubtedly plays an important role in meeting the growing energy needs of the planet. Coal accounted for 41.5 percent of the fuel used in electricity generation in 2007, up slightly from 38.3 percent in 1973.30 Natural gas is second with 20.9 percent.31 Hydro, nuclear, oil and other make up 15.6, 13.8, 5.6 percent and 2.6 percent, respectively.32 Other is comprised of geothermal, solar, wind, combustible renewable and waste, and heat.

Coal-fired Power Generation in the US Coal-fired power generation plays an important role in the US, primarily due to its abundance and relatively low cost. As mentioned in the previous section reviewing the global indicators of coal, the US is the global leader in coal reserves and second, only to China, in coal production and consumption. That being said, it is not surprising that coal is the most common fuel for generating electricity, accounting for 44.8 percent of total US electricity

28BP Statistical Review of World Energy”, June 2010., pp. 35, http://www.bp.com/sectiongenericarticle.do?categoryId= 9023784&contentId=7044480 29International Energy Agency, Key World Energy Statistics, 2009, http://www.iea.org/textbase/nppdf/free/ 2009/key_stats_2009.pdf, pp.15 30ibid, pp. 24 31ibid 32ibid

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generation across all sectors by source. This is illustrated in Figure 1.4, which shows total generation share by energy source, year-to-date through November 2010. This includes the electric power sector (electric utilities and independent power producers), commercial and industrial net generation.

Figure 1.4 Total (All Sectors) Net Generation Share by Energy Source, Year-to-Date through November 2010

6.2% 19.5% 4.5% 0.9% 44.8%

24.1%

Natural Gas Coal Hydroelectric Conventional Nuclear Other Petroleum

Source: EIA33

While coal is the primary fuel by source, it is interesting to note that coal’s share of total electricity generation across all sectors is, however, down from 48.5 percent in 2005 and from the record-high of 57 percent in 1979.34 This decrease is also evident in Figures 1.2 and 1.3, illustrating coal production and consumption in the US, respectively.

Table 1.2 provides total electric power industry summary statistics, year-to-date for 2010 and 2009 (the numbers are January through November for 2009 and 2010). While Figure 1.4 above illustrates net generation share by energy source of all sectors, Table 1.2 breaks up the total (all sectors) into the electric power sector, commercial and industrial net generation. Electric power sector is further divided into electric utilities and independent power producers.

33EIA website, Electric Power Monthly, February 2011 edition, http://www.eia.doe.gov/cneaf/electricity/epm/epm_sum.html 34ibid

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Table 1.2 Total Electric Power Industry Summary Statistics, Year-to-Date 2010 and 2009 Net Generation and Consumption of Fuels (thousand MWh) Electric Power Sector Independent Power Electric Utilities Producers Commercial Industrial 2010 2009 2010 2009 2010 2009 2010 2009 Coal 1,256,616 1,197,575 408,804 378,402 991 989 16,791 12,504 Petroleum Liquids 15,591 17,001 4,467 5,987 120 145 801 1,372 Petroleum Coke 8,086 6,716 2,999 3,921 6 4 1,324 1,369 Natural Gas 351,573 322,281 477,360 454,259 4,075 3,858 71,984 68,825 Other Gases 69 84 2,566 2,704 -- -- 7,620 6,913 Nuclear 386,121 380,173 347,164 347,972 ------Hydroelectric Conventional 212,671 224,848 19,691 22,110 81 64 1,498 1,693 Other Renewables 15,337 13,323 111,102 92,467 1,603 1,624 24,881 23,379 Wood & Wood-Derived Fuels 1,881 1,583 8,586 8,151 20 18 24,169 22,716 Other Biomass 1,152 1,212 13,495 13,355 1,581 1,606 709 663 Geothermal 1,021 1,081 13,233 12,560 ------Solar Thermal and PV 132 25 1,126 845 1 * 2 -- Wind 11,151 9,424 74,662 57,556 1 * -- -- Hydro Pumped Storage -3,045 -3,090 -516 -1,154 ------Other Energy Sources 303 448 6,079 5,620 746 777 3,226 4,069 All Energy Sources 2,243,322 2,159,359 1,379,716 1,312,289 7,621 7,461 128,125 120,124 Source: EIA35

For the total electric power sector, coal is the leading source of fuel, primarily because it is the source of fuel for electric utilities. For independent power producers, natural gas is the leading source of fuel for electricity generation. The same is true for the commercial and industrial sector where coal lags behind natural gas, other renewable and other biomass. Other biomass includes biogenic municipal solid waste, landfill gas, sludge waste, agriculture by-products, and other biomass.

Figure 1.5 illustrates the total coal power electricity generation between 2001 and 2010. It is important to note that 2010 data is from January through November. While coal-fired generation increased—albeit slightly—from 2001 to 2005, it remained virtually flat until 2009. Coal-fired power generation decreased over 10 percent.

35EIA website, Total Electric Power Industry Summary Statistics, February 2011 edition, http://www.eia.doe.gov/cneaf/ electricity/epm/tablees1b.html

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Figure 1.5 Total Coal Power Electricity Generation between 2001 and 2010* (thousand MWh) 2500000

2000000

1500000

1000000

500000

0 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010

Source: EIA36 *2010 total is January through November

Figure 1.6 illustrates the top 20 coal power generating states in the US in 2009.

Figure 1.6 Top 20 US States by Coal Power Electricity Generation in 2009 (thousand MWh) 160000

140000

120000

100000

80000

60000

40000

20000

0

IL

IA

FL

IN

SC

AL

TX KY

AZ

PA

MI

UT

TN

WI

NC

GA

OH

WY

WV MO

Source: EIA37

36EIA website, Electric Power Monthly 2009 – Monthly Data Tables, http://www.eia.doe.gov/cneaf/electricity/epa/epa_ sprdshts_monthly.html 37EIA website, Electric Power Monthly 2009 – Monthly Data Tables, http://www.eia.doe.gov/cneaf/electricity/epa/epa_ sprdshts_monthly.html

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The top five US states by coal power generation are Texas, Ohio, Indiana, Pennsylvania and Illinois. These states account for 31.6 percent of the total power utilized by coal while the top 20 states account for 77.3 percent of total coal used as a fuel in generating electricity.

Figure 1.7 illustrates the top 20 US states by the number of coal-fired plants at end-2008. The top five are Pennsylvania, Ohio, Michigan, Indiana and Illinois. These states account for 28.1 percent of the total number of coal-fired power plants. The top 20 states account for 75.9 percent of the total number of coal-fired power plants. There are four states that have greater than 30 coal power plants: Pennsylvania leads the way with 39.

It is also interesting to point out that while ranking first in the US for power production at end-2008, Texas ranked 13th in the nation with number of plants. The Texan mantra of ‘go big or go home’ certainly applies in this case.

Figure 1.7 Top 20 US States by Number of Coal-fired Plants at end-2008 45

40

35

30

25

20

15

10

5

0 PA OH MI IN IL WI IA MO KY MN NC VA WV TX FL SC CO GA NY AL TN

Source: EIA38

Figure 1.8 illustrates the top 20 US states by the nameplate capacity of coal-fired plants at end-2008.

The top five are Ohio, Indiana, Texas, Pennsylvania and Illinois. The top 5 US states account for 30.8 percent of the total nameplate capacity of coal-fired plants while the top 20 states account for 78.6 percent of the total nameplate capacity of coal-fired plants. It is interesting to note that in 2005 the top five states in power production remain the same.39

38EIA website, Existing Units end-2008, http://www.eia.gov/cneaf/electricity/page/capacity/existingunitsbs2008.xls 39Source Watch, “Existing US Coal Plants”, http://www.sourcewatch.org/index.php?title=Existing_U.S._Coal_Plants#cite_note- BW-9

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Figure 1.8 Top 20 US States by Coal Power Nameplate Capacity at end-2008 (thousand MWh) 25000

20000

15000

10000

5000

0 OH IN TX PA IL KY WV GA NC MI AL MO FL TN SC WI IA AZ WY VA

Source: EIA40

Total capacity of the top 5 US states, however, decreased from 104,652 MW in 2005 to 102,853 MW. In 2005 the US had 1,522 coal-fired units with a production capacity of 335,831 MW.41 In 2010, the US had 1,382 coal-fired units with a nameplate capacity of 334,263 MW.42

Figure 1.9 demonstrates the cumulative total coal power capacity. This figure illustrates the relationship between time and total capacity of coal-fired plants in the US. It is interesting to note the buildup of coal plants that peaked in 1980, where new power plant builds flatted out. The steepness of the line indicates the rate of new capacity being added.

It is also interesting to point out that there are a several power plants that were built, and are still active, before the late 1940s. The oldest plant was constructed in 1924, and is operated by Butler Ohio by Smart Papers LLC.

40EIA website, Existing Units end-2008, http://www.eia.gov/cneaf/electricity/page/capacity/existingunitsbs2008.xls 41Source Watch, “Existing US Coal Plants”, http://www.sourcewatch.org/index.php?title=Existing_U.S._Coal_Plants#cite_note- BW-9 42EIA website, Existing Units end-2008, http://www.eia.gov/cneaf/electricity/page/capacity/existingunitsbs2008.xls

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Figure 1.9 Cumulative Total Coal Power Capacity in the US (MW) 400000

350000

300000

250000

200000

150000

100000

50000

0

1947 1956 1924 1934 1938 1941 1944 1950 1953 1959 1962 1965 1968 1971 1974 1977 1980 1983 1986 1989 1992 1995 1999 2002 2005 2008

Source: EIA43

Table 1.3 illustrates the top 10 largest generating units in the US, by state, company and plant, at end-2008. All generating units on the list are privately-owned corporations, with the exception of Tennessee Valley Authority.

Table 1.3 Top 10 Generating Units by State, Company and Plant, end-2008 Nameplate Year of Plant Name Company Name Capacity County and State Operation (MW) W H Zimmer Duke Energy Ohio Inc 1425.6 1991 Clermont, Ohio Rockport Indiana Michigan Power 1300 1984 Spencer, Indiana Rockport Indiana Michigan Power 1300 1989 Spencer, Indiana General James M Gavin Ohio Power Co 1300 1975 Gallia, Ohio General James M Gavin Ohio Power Co 1300 1974 Gallia, Ohio Cumberland Tennessee Valley Authority 1300 1973 Stewart, Tennessee Cumberland Tennessee Valley Authority 1300 1973 Stewart, Tennessee John E Amos Appalachian Power Co 1300 1973 Putnam, West Virginia Mountaineer Appalachian Power Co 1300 1980 Mason, West Virginia Paradise Tennessee Valley Authority 1150.2 1970 Muhlenberg, Kentucky Source: EIA44

With W.H. Zimmer and the two units at the General James M Gavin facility, 3 of the 5 largest coal-fired units are located in Ohio. The other two units, at Rockport, are located in Indiana. It is also prudent to note that 7 of the largest units were built in 1980 or earlier.

43EIA website, Existing Units end-2008, http://www.eia.gov/cneaf/electricity/page/capacity/existingunitsbs2008.xls 44ibid

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Table 1.4 illustrates the top 10 producers of coal-fired electricity in the US in 2005. The following lists the companies, number of coal plants and their total coal capacity.

Table 1.4 Top 10 Producers of Coal-fired Electricity in the US, 2005 Nameplate Number of Company Name Capacity (MW) Plants American Electric Power 27,636 23 Southern Company 26,610 22 Duke Energy 18,585 20 Tennessee Valley Authority 17,647 12 Ameren 10,719 11 MidAmerican Energy 10,282 12 Edison International 10,253 11 Dominion 9,031 15 Xcel Energy 8,961 8 NRG Energy 8,657 16 Source: SourceWatch45

The top producer of coal-fired electricity in the US in 2005 was American Electric Power (AEP). The Columbus Ohio- based company is divided into 7 companies: AEP Ohio, Appalachian Power Company, Indiana Michigan Power, Kentucky Power, Public Service Company of Oklahoma, Southwestern Electric Company and AEP Texas Central Company.46 AEP operates 23 power plants in the US and has a nameplate capacity of 27,636 MW. Southern Company trails AEP by a single power plant and by a capacity of 1,026 MW.

The top 3 companies account for a nameplate capacity of 72,831 MW and 65 power plants.

Figure 1.10 illustrates the age and size of the coal-fired power plants capacity by year. As mentioned previously the oldest coal power plant was constructed in 1924. The figure illustrates that the top three years for adding coal- fired capacity were 1973, 1980 and 1978. In those three years, capacity added was 16,585 MWh, 15,885 MWh and 12,958 MWh. Coal-fired power plant builds, as illustrated by capacity, decreased notably during the 1980s and 1990s.

45Source Watch, “Existing US Coal Plants”, http://www.sourcewatch.org/index.php?title=Existing_U.S._Coal_Plants#cite_note- BW-9 46Source Watch, “American Electric Power Companies”, http://www.sourcewatch.org/index.php?title=American_Electric_ Power

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Figure 1.10 Age and Size of Capacity of Coal-fired Power Units in the US (MW) 18000 16000 14000 12000 10000 8000 6000 4000 2000

0

2002 2005 1924 1934 1938 1941 1944 1947 1950 1953 1956 1959 1962 1965 1968 1971 1974 1977 1980 1983 1986 1989 1992 1995 1999 2008

Source: EIA47

According to the EIA data,48 the average coal power generation unit—1,382 units in total—was built in 1968. The average unit is a whopping 42 years old. At end-2008, there are 28 units that are on standby backup, 34 units are out-of-service and a single unit is temporarily out-of-service.

The average age of the standby backup units is 1953. Of the total 28 units, 24 were built before 1980 and 19 were built before 1960. The nameplate capacity of the standby backup units is only 245 MWs. Of the 34 units that were retired, the average age of initial operation is 1954 and their nameplate capacity was 2,784 MWs. At end-2008, the single unit that was temporarily out of service was a 7.9 MW plant located in Lancaster County, Nevada. The plant began operations in 1988. The aforementioned numbers are from the EIA website and data tables of existing generating units in the US.

As mentioned previously, there are several coal power plants that were constructed in the 1920s and 1930s that are still operating. The decision on whether to make a refurbishment, or to build a new plant, is a question of relative economics and investment risk. The economics, through various environmental legislation and regulations, is unquestionably altering the decision whether to retrofit power plants with carbon dioxide capture technologies and other technologies that minimize emissions.

With that being said, the EIA’s Annual Energy Outlook (AEO) 2011 estimates that total electricity consumption will grow from 3,745 billion kWh in 2009 to 4,880 billion kWh by 2035.49 In that outlook, the organization predicts that 21 gigawatts (GW) of coal-fired generating capacity are added between 2009 and 2035 to satisfy the increase in energy demand.50 While coal’s dominance is diminished slightly, it is still expected to be the primary electricity

47EIA website, Existing Units end-2008, http://www.eia.gov/cneaf/electricity/page/capacity/existingunitsbs2008.xls 48ibid 49EIA website, AEO2011 Early Release Overview: Electricity Generation, http://www.eia.gov/forecasts/aeo/early_elecgen.cfm 50ibid

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generating fuel with 43 percent in 2035.51 Natural gas, in the AEO2011 Reference Case, increases from 23 percent in 2009 to 25 percent in 2035.52 Renewables are expected to increase 4 percent while nuclear is expected to decrease 3 percent, over the same time period.53

Figure 1.11 illustrates the EIA’s outlook on electricity generation by fuel.

Figure 1.11 Net Electricity Generation by Fuel, 1990-2035 (trillion kWh per year)

Source: EIA54

While several jurisdictions are either contemplating or creating plans to phase out coal-fired electricity generation, coal will clearly continue to play an important role in generating electricity in the US. In spite of issues regarding emissions, the US relies heavily on coal power plants to meet their energy needs—at least for the foreseeable future. With this heavy reliance on coal power, the age of the coal-fired power plants will quickly become an issue. This is illustrated below.

Figure 1.12 illustrates a scenario if no additional coal-fired plants are built, under the assumptions that coal retirements begin in 2016 and that they have a 50-year plant life. This figure is similar to Figure 1.9 in that it illustrates cumulative total coal power capacity in the US. The data is also by state.

If no new coal plants are built, the following illustrates the rapid decline of coal-fired generation in the US. This lost electricity generation needs to be replaced by another fuel. In addition, other fuels need to replace the future reliance of coal power in the upcoming decades—recall the AEO2011 estimate.

51ibid 52ibid 53ibid 54ibid

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It is important to note that the cumulative total declines more rapidly assuming a shorter lifespan, and becomes less steep when assuming a longer lifespan.

Figure 1.12 Coal Plant Retirements, Cumulative Total by State (50-year Life)

400000 AK AL AR AZ CA CO CT DE FL GA HI IA ID IL IN KS KY LA MA MD ME MI MN MO MS MT NC ND NE NH NJ NM NV NY OH OK OR PA SC SD TN TX UT VA WA WI WV WY 350000

300000

250000

200000

150000

100000

50000

0

1933 2013 1921 1925 1929 1937 1941 1945 1949 1953 1957 1961 1965 1969 1973 1977 1981 1985 1989 1993 1997 2001 2005 2009 2017 2021 2025 2029 2033 2037

Source: EIA55 and CERI

As such new generating capacity additions are crucial. Figure 1.13 shows the planned electric generation capacity additions in the US. The figure shows planned coal, natural gas as well as a category showing all energy sources (total planned electric generation capacity, including coal and natural gas). Natural gas and coal are shown because they are the two major fuels used in generating electricity. Other sources, or fuels, include petroleum, nuclear, hydroelectric conventional, wind, solar thermal and photovoltaic, geothermal, other biomass, wood and wood derived fuels, pumped storage, other gases and other.

55EIA website, EIA website, Existing Units end-2008, http://www.eia.gov/cneaf/electricity/page/capacity/existingunitsbs 2008.xls

March 2011 North America Natural Gas Market Dynamics: Coal-fired Generation in North America – A Review 17

Figure 1.13 Planned Electric Generation Capacity Additions (MW) 30000

25000 Coal Natural Gas All Energy Sources Combined 20000

15000

10000

5000

0 2009 2010 2011 2012 2013 2014

Source: EIA56

Natural gas is the choice of fuel for planned generating capacity additions between 2010 and 2014. As of end-2010, natural gas accounts for 55 percent of all planned generating capacity additions over the next 5 years, peaking in 2013 with 66.7 percent. Lower gas prices and lower GHG emissions make gas-fired generation an attractive option. Coal, however, ranks second as the choice of fuel for planned generating capacity additions, accounting for 19 percent. Planned coal capacity peaks in 2012 at 31 percent. Wind ranks third. It is also cheaper and quicker to build than its fossil-fuel counterparts.

Figure 1.14 shows the planned number of generators in the US. Similar to the previous figure, Figure 1.14 shows planned coal, natural gas as well as a category showing all energy sources (total planned electric generation capacity, including coal and natural gas). Natural gas and coal are shown because they are the two major fuels used in generating electricity.

As natural gas is the choice of fuel for planned generating capacity additions between 2010 and 2014, it is not surprising that natural gas leads in the number of generators planned. As of end-2010, natural gas accounts for 41 percent of all planned generators over the next 5 years, peaking in 2014 with 56 percent. Of the total 448 generators planned, 184 are natural gas-fired. Coal ranks second with 22. In fact, coal accounts for only 5 percent of the number of planned generators in the US between 2010 and 2014.

56EIA website, Electric Power Monthly, February 2011 edition, http://www.eia.doe.gov/cneaf/electricity/epm/epm_sum.html

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Figure 1.14 Number of Planned Generators 450

400

350

300

250

200

150

100

50

0 2009 2010 2011 2012 2013 2014 Coal Natural Gas All Energy Sources Combined

Source: EIA57

Coal-fired Power Generation in Canada Recall that Canada ranks 11th in the world in proven reserves of coal, and accounts for 0.8 percent of global consumption and 1.0 percent of global production. While Canada is not a major global coal player, it is a mid-size player that warrants attention from industry pundits.

Figure 1.15 illustrates total electricity output in Canada between 1990 and 2008. Canada’s total electricity output in 2008 is 618,803 GWh, up from 615,317 in 2007 and from 592,623 in 2006.58 While it is not a steady increase, the trend is certainly increasing and it is the third time in the past 4 years that total electricity output has exceeded the 600,000 GWh-level. Canada’s total electricity output in 1990 was 467,596 GWh, accounting for a total growth of 32.3 percent over the 1990-2008 time period.59

Canadian electricity output makes up approximately 3 percent of the world’s total electricity output and approximately 5.6 percent of the OECD’s electricity output.60

57EIA website, Electric Power Monthly, February 2011 edition, http://www.eia.doe.gov/cneaf/electricity/epm/epm_sum.html 58NRCAN, Office of Energy Efficiency, “Electricity Generation Energy Use and Generation by Energy Source”, http://www.oee.nrcan.gc.ca/corporate/statistics/neud/dpa/tableshandbook2/egen_00_1_e_4.cfm?attr=0 59ibid 60IEA, Key World Energy Statistics, 2009, pp.50.

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Figure 1.15 Total Electricity Generation in Canada, 1990-2008 (GWh) 700,000

600,000

500,000

400,000

300,000

200,000

100,000

0 1990 1992 1994 1996 1998 2000 2002 2004 2006 2008

Source: NRCAN61

Coal-fired power generation plays an important role in Canada, but not nearly to the same extent as its southern neighbour. Recall that in the US in 2009, coal generates 44.6 percent share of electricity generation. This is followed by natural gas, nuclear power and conventional hydro which account for 23.2 percent, 20.2 percent and 6.9 percent, respectively.62 In Canada, large-scale hydro dominates the share of electricity generation, accounting for 61.9 percent.63 This is followed by coal, nuclear and natural gas at 17.2 percent, 13.5 percent and 5.1 percent, respectively.64 Petroleum and Other account for 0.4 percent and 2.1 percent, respectively.65 Petroleum is comprised of petroleum coke, still gas, coke and coke oven gas. Other is made up of diesel fuel oil, light fuel, kerosene, heavy fuel oil, wood and other. According to NRCAN, in 2007, large-scale hydro accounts for 59.9 percent. This is followed by coal, nuclear and natural gas at 17.7, 13.5 and 6.7 percent, respectively.

Figure 1.16 illustrates the total electricity generation in Canada by energy source, in 2008.

61NRCAN, Office of Energy Efficiency, “Electricity Generation Energy Use and Generation by Energy Source”, http://www.oee.nrcan.gc.ca/corporate/statistics/neud/dpa/tableshandbook2/egen_00_1_e_4.cfm?attr=0 62EIA website, Electric Power Monthly, February 2011 edition, http://www.eia.doe.gov/cneaf/electricity/epm/epm_sum.html 63ibid 64ibid 65ibid

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Figure 1.16 Electricity Generation by Energy Source, 2008

0.4% 2.1% 13.5% 5.1%

17.2% 61.9%

Natural Gas Coal Hydroelectric Conventional Nuclear Petroleum Other

Source: NRCAN66

Figure 1.17 illustrates electricity generation by energy source in Canada between 1990 and 2008.

Figure 1.17 Electricity Generation by Energy Source, 1990-2008 (GWh) 700,000

600,000

500,000

400,000

300,000

200,000

100,000

0 1990 1992 1994 1996 1998 2000 2002 2004 2006 2008

Hydro Coal Nuclear Natural Gas Other

Source: NRCAN67

66ibid 67ibid

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Hydro is the most important source of energy in producing electricity. Not surprisingly, Canada is the second largest producer of hydroelectricity in the world, only surpassed by China in the past few years.68 This is most likely due to the building of the massive Three Gorges Dam in Hubei Province, China.

It is important to note that hydro is led by the provinces of British Columbia, Québec, Manitoba, and Newfoundland and Labrador. In each of these provinces, large-scale hydro is the leading source of energy in producing electricity. Figure 1.18 shows the energy mix in each of Canada’s provinces.

Figure 1.18 Installed Generating Capacity by Energy Source in Canadian Provinces, 2006

Source: NEB69

While hydro is the most significant player in electricity generation in Canada, coal still plays a key role—especially in some provinces where hydro is not possible. Coal plays an important role in the energy mix for Alberta, Saskatchewan, Ontario, New Brunswick and Nova Scotia. Similar to the US, it is primarily due to its abundance and relatively low cost. In fact, for Alberta, Saskatchewan and Nova Scotia, coal provides over 50 percent of their energy mix.70 It is important to note that due to Canada’s abundant hydro, Canada’s GHG emission intensity for electricity generation is very low relative to the US and the rest of the world.71

Figure 1.19 illustrates coal-fired electricity generation in Canada between 1990 and 2008. While the increase is not steady, the trend between 1990 and 2001 certainly is. Coal-fired generating increased from 76,794 GWh to a high

68EIA website, Country Analysis Brief: Canada, http://www.eia.doe.gov/cabs/Canada/Electricity.html 69NEB, “Coal-Fired Power Generation: A Perspective”, Energy Briefing Note, July 2008, pp. 5. 70Graham R. Campbell, “Clean Coal Developments in Canada Towards a Sustainable Energy Future”, NRCAN, presented at Nova Scotia’s Energy R&D Forum, May 24-25, 2006, pp. 5. 71ibid, pp. 6.

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of 110,197 GWh.72 However, after 2002 coal-fired generation decreases to 100,828 GWh in 2006.73 In spite of its fluctuations, coal-fired generation does not dip below the 100,000 GWh level.

Figure 1.19 Coal-fired Electricity Generation in Canada, 1990-2008 (GWh) 120,000

100,000

80,000

60,000

40,000

20,000

0 1990 1992 1994 1996 1998 2000 2002 2004 2006 2008

Source: NRCAN74

Figure 1.20 illustrates coal-fired electricity generation in Canada by province. These numbers include the closure of 4 units in Ontario and the shutdown of Sundance 1 & 2 in Alberta. It is also important to note that Keephills 3 (K3) and Keephill-Uprate are included as they are to be on-steam in March 2011 and end-2011, respectively. Units 3 and 4 at Nanticoke and units 1 and 2 at Lambton had a combined capacity of approximately 1,960 MW while Sundance Units 1 & 2 (Sundance A) had a combined capacity of 560 MW.75 76

It is important to note that data collected on various coal-fired power plants in Canada was compiled from the National Energy Board’s (NEB) “Clean Coal: A Compendium of Canada’s Participation”, and was updated and verified through the various companies that own and operate the coal-fired power plants.

72NRCAN, Office of Energy Efficiency, “Electricity Generation Energy Use and Generation by Energy Source”, http://www.oee.nrcan.gc.ca/corporate/statistics/neud/dpa/tableshandbook2/egen_00_1_e_4.cfm?attr=0 73ibid 74ibid 75Ontario Power Generation (OPG), “Four OPG coal-fired generating units removed from service”, October 1, 2010. 76TransAlta website, Sundance Facility, http://www.transalta.com/facilities/plants-operation/sundance

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Figure 1.20 Share of Coal-fired Electricity Generation Capacity in Canada by Province

12.4%

42.7%

31.4%

9.3% 3.4%

0.8%

Alberta Manitoba New Brunswick Nova Scotia Ontario Saskatchewan

Source: NRCAN77 and various company websites

With the addition of TransAlta’s K3 in March 2011 and the permanent shutdown of the 4 units in Ontario, Alberta surpassed Ontario in coal-fired generating capacity. Alberta’s capacity is 5,715 MW compared to Ontario’s 4,197 MW. Saskatchewan, Nova Scotia, New Brunswick and Manitoba have capacities of 1,665, 1,252, 450 and 105 MW, respectively. Total coal-fired electricity generating capacity is 13,383 MW, down from 15,903 MW in Canada from a year ago.

Alberta accounts for 42.7 percent of total coal-fired electricity generation in Canada, followed closely by Ontario at 31.4 percent. Saskatchewan and Manitoba account for 12.4 and 7.9 percent of Canada’s total coal-fired electricity generation, respectively. New Brunswick and Manitoba account for 3.4 and 0.8 percent, respectively.

Prior to including the recent permanent shutdowns, Alberta accounted for 39.5 percent of total coal-fired electricity generation in Canada, followed very closely by Ontario at 38.7 percent. Saskatchewan and Manitoba accounted for 10.5 and 9.3 percent of Canada’s total coal-fired electricity generation, respectively.

Regardless, Alberta is Canada’s leader in using coal-fired power units to generate electricity, and with Ontario’s Open Ontario Plan of moving to permanently shut down all coal-fired generation by 2014, the lead is expected to grow. Coal-fired generating capacity accounts for 50 percent of Alberta’s installed capacity, while natural gas-fired

77“Clean Coal: A compendium of Canada’s Participation”, NRCAN, 2007, http://www.nrcan.gc.ca/com/resoress/publications/ carbone/coalcarbon-eng.pdf?PHPSESSID=c3eac71055856ac30ae7c43ba69e01a4

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capacity accounts for 38 percent.78 It is interesting to note that, while half of the province’s capacity is made up from coal-fired power plants, these plants generated 73.9 percent of total utility generation in 2007.79

Of Canada’s 45 coal-fired power generation units, 15 are located in Alberta, 11 are in Ontario and 9 are in Saskatchewan.80 Nova Scotia has 8 coal-fired power generating units while New Brunswick and Manitoba have a single unit. Alberta also leads Canada with 6 coal-fired power plants or facilities. It is interesting to note that even with the shutdowns of 4 units, Ontario is still ranked second in number of units.81

It is prudent to review Canada’s power stations and information regarding their generating units.

As mentioned above, Alberta has 6 coal-fired power plants: Battle River (Forestburg), Genesee (Genesee), H.R. Milner (Grande Cache), Keephills (Wabamun), Sheerness (Hanna) and Sundance (Wabamun). Battle River Generating Station has 3 units and is owned by ATCO.82 Units 3 & 4 have an installed capacity of 150 MW each and came into service in 1969 and 1975, respectively.83 Unit 5 has a capacity of 405 MW and came into service in 1981.84 Located 200 kilometres east of Edmonton, Battle River has a total capacity of 670 MW.85 Units 1 & 2 were retired in 2000.86

The Genesee Generating Station also has 3 units: Genesee 1, Genesee 2 and Genesee 3. The latter is often referred to as G3. Genesee 1 & 2 is owned by Capital Power Corporation (formerly EPCOR) and has an installed capacity of 410 MW each.87 Both use sub-bituminous coal and were constructed in 1989 and 1994, respectively. G3 is owned by Capital Power (50 percent) and TransAlta (50 percent) and has an installed capacity of 450 MW.88 G3 was constructed in 2005 and uses supercritical combustion technology.89 The only other facility in Canada that utilizes this technology is the new Keephills 3 (K3). Both facilities are regarded as the new generation of coal-fired power plants.

H.R. Milner is located in Grande Cache. The single unit power plant is owned now by Milner Power.90 The plant was constructed in 1972 by Canadian Utilities and was subsequently owned by ATCO between 2000 and 2004.91 The single unit has an installed capacity of 144 MW.92

78Government of Alberta: Energy, Electricity in Alberta, http://www.energy.alberta.ca/Electricity/1586.asp 79Statistics Canada (April 2009), Electric Power Generation, Transmission and Distribution (catalog number: 57-202-X), Ottawa: Statistics Canada 80“Clean Coal: A compendium of Canada’s Participation”, NRCAN, 2007, http://www.nrcan.gc.ca/com/resoress/publications/ carbone/coalcarbon-eng.pdf?PHPSESSID=c3eac71055856ac30ae7c43ba69e01a4 81ibid 82ATCO Power website, Battle River Facility, http://www.atcopower.com/Our%20Facilities/North%20America/ Battle%20River%20(AB)/ 83ibid 84ibid 85ibid 86ibid 87Capital Power Corporation website, Genesee 1 and 2, http://www.capitalpower.com/OurOperations/inoperation/Genesee/ Pages/Genesee1and2.aspx 88ibid 89Capital Power Corporation website, Genesee 3, http://www.capitalpower.com/OurOperations/inoperation/Genesee/ Pages/Genesee3.aspx 90H.R. Milner website, http://www.milnerpower.ca/ 91ibid

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The Keephills Generating Station is located near Wabamun and consists of 3 units.93 Keephills 1 & 2 is owned by Capital Power (50 percent) and TransAlta (50 percent) and has an installed capacity of 766 MW.94 Keephills 1 came into service in 1983 while Keephills 2 followed one year later.95 It is important to note that a test of mercury control technology was performed at the Keephills 2 facility, and results to reduce mercury emissions are considered promising.96 K3 is a state-of-the-art facility and is coming online in mid-March 2011.97 The 450 MW 98 generating unit uses supercritical boiler technology, reducing carbon dioxide (CO2) emissions per MW. With the new K3 coming online in March 2011, the last of the old Wabamun units was decommissioned by TransAlta in 2010.99 The Wabamun Generating Station is comprised of 4 units, dating back to 1959.100 According to TransAlta, the new K3 will emit approximately 60 to 80 percent less sulphur dioxide (SO2), nitrogen oxides (NOX), mercury 101 (Hg) and 24 percent less CO2 as the 4-unit Wabamun Generating Station. It is important to note that the uprate is at the Keephills facility and is scheduled for 2011-12.102

The Sheerness Generating Station is located in Hanna and consists of 2 units. The facility is owned by ATCO (50 percent) and TransAlta (50 percent).103 Sheerness 1 & 2 each has an installed capacity of 380 MW and were commissioned in 1986 and 1990, respectively.104

Sundance Power Station is also located in Wabamun. It currently has 4 units and, in spite of shutting down 2 units, it remains western Canada’s largest coal-fired electrical generating facility. Sundance A (Units 1 & 2) were decommissioned in late 2010 and TransAlta issued a notice of termination under terms of the Sundance A Power Purchase Agreement (PPA) on February 8, 2011.105 With the permanent shutdown of Sundance A, total installed capacity dropped from 2,126 MW to 1,564 MW. Sundance B (3 & 4) has an installed capacity of 353 MW and 406 MW, respectively.106 The units came into service in 1976 and 1977.107 Units 5 & 6 have an installed capacity of 406 MW and 399 MW, respectively.108 The units came into service in 1978 and 1980. It is important to note that

92 “Clean Coal: A compendium of Canada’s Participation”, NRCAN, 2007, http://www.nrcan.gc.ca/com/resoress/publications/ carbone/coalcarbon-eng.pdf?PHPSESSID=c3eac71055856ac30ae7c43ba69e01a4 93TransAlta website, Keephills Facility http://www.transalta.com/facilities/plants-operation/keephills 94ibid 95ibid 96ibid 97Capital Power & TransAlta, Keephills 3 Construction Bulletin, March 2011 98TransAlta website, Keephills 3 Facility, http://www.transalta.com/facilities/facilities-development/keephills-3?page=2 99TransAlta website, “TransAlta fully retires all units in ins Wabamun power plant” April 1, 2010, http://www.transalta.com/ newsroom/news-releases/2010-04-01/transalta-fully-retires-all-units-its-wabamun-power-plant 100ibid 101ibid 102TransAlta website, Keephill-Uprate, http://www.transalta.com/facilities/facilities-development/keephills-uprate 103ATCO website, Sheerness Facility, http://www.atcopower.com/Our+Facilities/North+America/Sheemess+(AB)/ 104ibid 105TransAlta website, Sundance Facility, http://www.transalta.com/facilities/plants-operation/sundance 106http://www.nrcan.gc.ca/com/resoress/publications/carbone/coalcarbon-eng.pdf?PHPSESSID=c3eac71055856ac30ae7c43 ba69e01a4 107ibid 108ibid

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TransAlta announced an uprate to Unit 3.109 Thus far, 3 of the 6 units have been uprated, and Unit 5 was the site of a mercury control test.110

The NEB suggests that older plants totaling 2,500 MW will be retired in Alberta over the next 15 years.111 Many of these will be replaced by coal and oil sands cogeneration facilities, and will be fueled by either natural gas or bitumen.112

According to IESO, as of mid-February 2011, coal accounts for 4,484 MW or 13 percent of Ontario’s installed generation capacity.113 Nuclear and natural gas account for 33 percent and 27 percent of installed capacity, respectively.114 Ontario has 4 coal-fired facilities: Lambton (Lambton), Nanticoke (Haldimand County), Thunder Bay (Thunder Bay) and Atikokan (Atikokan). It is important to note that all coal power plants are owned and operated by Ontario Power Generation (OPG). Lambton Power Station was commissioned in 1969 and now has 2 units (3 & 4).115 Recall that Lambton Units 1 & 2 were shut-down permanently (October 1, 2010) as part of the Open Ontario Plan. Located on the St. Clair River near Corunna, the remaining units each have an installed capacity of 494 MW and went into service in 1970.116 Unit 1 went into service in 1969 while Unit 2 also went into service in 1970. According to OPG, the 4 units could supply enough electricity for approximately 1 million homes in southern Ontario for a year.117 Lambton also utilizes flue gas desulpherization (FGD) and selective catalytic reduction (SCR) technology.118 It is possible that the remaining generators may be converted to natural gas-fired or biomass.119

Nanticoke is located in Haldimand County and was once the largest coal-fired generating plant in North America (installed capacity of 3,640 MW).120 This is enough electricity to power 2 million homes for a year.121 At one time, Nanticoke was Canada’s leading GHG emitter and top polluter.122 Like Lambton, 2 units were shut-down permanently (Units 3&4). The remaining 6 units are capable of producing approximately 2,760 MW. Like Lambton, Nanticoke is scheduled to be phased out by 2014.123 The possibilities of converting the generators to natural gas or biomass are currently being discussed.124

109TransAlta website, Sundance Facility, http://www.transalta.com/facilities/plants-operation/sundance 110ibid 111Coal-fired Power Generation – An Overview”, NEB Energy Brief, September 2008, http://www.neb-one.gc.ca/clf- nsi/rnrgynfmtn/nrgyrprt/lctrcty/clfrdpwrgnrtn2008/clfrdpwrgnrtnnrgybrf-eng.html 112ibid 113IESO website, Supply Overview, http://www.ieso.ca/imoweb/media/md_supply.asp 114ibid 115OPG website, Lambton Generating Station, http://www.opg.com/power/thermal/lambton.asp 116ibid 117ibid 118ibid 119The Star, “OPG testing biomass in coal-fired power plants”, Tyler Hamilton, November 24, 2008, http://www.thestar.com/ Business/article/542152 120OPG website, Nanticoke Generating Station, http://www.opg.com/power/thermal/nanticoke.asp 121ibid 122CTV News, “Ontario coal-fired power plant Canada's biggest polluter”, April 18, 2001, http://www.ctv.ca/servlet/ArticleNews/print/CTVNews/1027384052424_22793252?hub=CTVNewsAt11&subhub=PrintStory 123OPG website, Nanticoke Generating Station, http://www.opg.com/power/thermal/nanticoke.asp 124ibid

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Thunder Bay Generating Station has 2 units, each with an installed capacity of 153 MW.125 Unit 2 went into service in 1981 while Unit 3 followed a year later. Both units will stop burning coal and will be converted to natural gas before 2014.126

Atikokan Generating Station is a single unit plant that has an installed capacity of 211 MW.127 The facility went into service in 1985 and will be converted to biomass as a part of the Open Ontario Plan. The Atikokan GS Biomass Repowering Project will convert the facility from coal to biomass, or more specifically, wood pellets.128 While still in the approval phase, the move is scheduled for 2013.129

With regard to Ontario’s phasing out of coal-fired generation, it is important to mention the Lakeview Generating Station. While 4 units were retired in 1993 the remaining 4 units were taken offline in April 2005, 43-years after being commissioned. The facility had 8 units, each of which had an installed capacity of 300 MW and was thought to be the largest thermal power plant in the world and certainly the largest in Canada until the completion of Nanticoke.130

Saskatchewan has 3 coal power plants: Boundary Dam (near Estevan), Poplar River (near Coronach) and Shand (also near Estevan). All facilities are operated by SaskPower. Boundary Dam Power Station, located near Estevan, is the largest coal-fired power station in Saskatchewan. The plant has 6 units, including 2 X 66 MW units dating back to 1959.131 Units 3 & 4 were commissioned in 1970 and have a capacity of 139 MW.132 Unit 5 has an installed capacity of 139 MW and was commissioned in 1973.133 Unit 6 went into service in 1978 and is the largest of the units at an installed capacity of 273 MW.134 It is important to note that Unit 3 will be undergoing a C$1.2 billion investment from a joint government-industry partnership that includes SaskPower, the Government of Canada and the Government of Saskatchewan.135 The Integrated Carbon Capture and Storage Demonstration Project will modernize the 40-year old unit, which had been scheduled to shut-down in the next few years.136 The project is the first of its kind in the world.137 Poplar River Power Station is located near Coronach. The facility has 2 units. Unit 1 has an installed capacity of 291 MW and was commissioned in 1981.138 Unit 2 is slightly smaller at 281 MW and went into service in 1983.139 Shand Power Station began operation in 1992 and is home to a single 300 MW

125OPG website, Thunder Bay Generating Station, http://www.opg.com/power/thermal/thunderbay.asp 126Government of Ontario website, “Thunder Bay coal plant to convert to cleaner power”, November 23, 2010, http://www.news.ontario.ca/mei/en/2010/11/thunder-bay-coal-plant-to-convert-to-cleaner-power.html 127OPG website, Atikokan Generating Station, http://www.opg.com/power/thermal/atikokan.asp 128ibid 129ibid 130Power Plants Around the World website, coal-fired Plants in Canada, http://www.industcards.com/st-coal-canada.htm 131SaskPower website, Baseload Thermal Stations, http://www.saskpower.com/aboutus/corpinfo/power_generation_facilities/ baseload_thermal_stations/ 132ibid 133ibid 134ibid 135SaskPower website, Carbon Capture Storage, http://www.saskpower.com/sustainable_growth/projects/carbon_capture_ storage.shtml 136ibid 137ibid 138Power Plants Around the World website, coal-fired Plants in Canada, http://www.industcards.com/st-coal-canada.htm 139ibid

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unit.140 Shand utilizes Lime Injection into the Furnace and Activation of Calcium Oxide (LIFAC) and Low NOX burners.141

Nova Scotia has 4 coal power plants, all operated by Nova Scotia Power. The power company, however, is privately owned by Emera. They are Lingan (Cape Breton Island), Trenton, (Trenton), Point Tupper (Point Tupper) and Point Aconi (Point Aconi). Lingan Generating Station has 4 units and a total of 614 MW of installed capacity. The capacities of the individual units average at 153 MW each, and range between 148 MW at Lingan 2 to 157 MW at Lingan 4.142 The 4 units began operations between 1979 and 1984. Low NOX combustion systems were installed on the largest coal power plant in the province.143 The facility is located on Cape Breton Island.144 Trenton Generating Station is a 2-unit facility. The Trenton 5 went into service in 1969 and has an installed capacity of 152 MW. 145 Trenton 6 is a much newer facility than its counterpart, being built in 1991. It is also slightly larger and is able to generate 158 MW. Trenton Generating Station is able to produce 310 MW of electricity.146 Trenton 5 is upgrading its turbine while Trenton 6 was modified with a low NOX combustion system, similar to the Lingan units.147 Point Tupper Generating Station has a single unit. Being commissioned in 1987 the Point Tupper 2 has an installed capacity of 151 MW.148 It is important to note that Point Tupper was converted from an oil-fired facility to a coal burning one in the 1980s.149 Point Tupper is also located on Cape Breton Island. Point Aconi also has a single unit. The facility, however, is the largest producing unit in Nova Scotia and is also the province’s newest. The facility is able to produce 176 MW and went into service in 1994.150 It is important to note that the facility, unlike the vast majority of Canadian coal-fired power plants uses Circulating Fluidized Bed (CFB) to reduce emissions.151

Manitoba’s single power plant is the Brandon Unit 5, located in Brandon. Brandon Generating Station, owned by Manitoba Hydro, also has 2 natural gas-fired Alstom units that were installed in 2002.152 Each natural gas-fired unit is 120 MW while the coal-fired unit has a capacity of 105 MW.153 The unit went online in 1969.154

New Brunswick’s single power plant is the Belledune, located in Belledune. The plant has a single unit—450 MW.155 The plant, which began operations in 1993, is owned by the New Brunswick Power Generation Corporation. It is

140ibid 141ibid 142Email query to NS Power on September 18, 2010. 143Nova Scotia Power website, NS Power Thermal Generating Facilities, http://www.nspower.ca/en/home/environment/ emissions/archivedemissionslevels/nspower_thermalgeneratingfacilities.aspx 144ibid 145Email query to NS Power on September 18, 2010. 146ibid 147ibid 148ibid 149Nova Scotia Power website, NS Power Thermal Generating Facilities, http://www.nspower.ca/en/home/environment/ emissions/archivedemissionslevels/nspower_thermalgeneratingfacilities.aspx 150Email query to NS Power on September 18, 2010. 151Nova Scotia Power website, NS Power Thermal Generating Facilities, http://www.nspower.ca/en/home/environment/ emissions/archivedemissionslevels/nspower_thermalgeneratingfacilities.aspx 152Power Plants Around the World website, coal-fired Plants in Canada, http://www.industcards.com/st-coal-canada.htm 153ibid 154ibid 155ibid

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important to note that Grand Lake Power Station was retired 3-months earlier than planned when a fire broke out at the plant.156 The plant, which had been operating since 1952, was scheduled to be shut-down in June 2010.157

Table 1.5 illustrates the top 5 coal-fired power plants in Canada. In spite of Nanticoke shutting 2 units permanently, the facility in Ontario is still the largest coal-fired power plant. This is not surprising in the sense that in its heyday the facility was regarded as one of the largest coal-fired power plants in the world. Its capacity was 3,960 MW, as previously mentioned, enough to power 2 million homes for a year.158 The Lambton Generating Station ranks fifth on the top 5 list. Prior to the shut-down of 2 units of the facility, Lambton ranked third behind its Ontario counterpart and Alberta’s Sundance. With the Open Ontario Plan both facilities will stop burning coal before the scheduled 2014 deadline. Sandwiched in between Ontario are 3 power plants from Alberta: Sundance, Genesee and Keephills. Prior to shutting down 2 units, at 2,124 MW, Sundance was the second largest coal-fired power plant in Canada. Unlike the others on this list, Genesee and Keephills expanded their installed capacity with the completions of G3 and K3.

Table 1.5 Top 5 Coal-fired Power Plants in Canada, 2011 Province Station Age in 2011 MW ON Nanticoke Generating Station 39 2,660 AB Sundance Power Station 41 1,564 AB Genesee Generating Station 22 1,315 AB Keephills Generating Station 28 1,262 ON Lambton Generating Station 42 988

Source: OPG, TransAlta and Capital Power Corporation

Figure 1.21 demonstrates the cumulative total coal power capacity in Canada. This figure illustrates the relationship between time and total capacity of coal-fired plants in Canada. The steepness of the line indicates the rate of new capacity being added. It is interesting to note the buildup of coal plants in the 1970s, while new power plant builds flatted out in the 1990s. The decrease in cumulative total in 2010 is the shut-down of the 6 units (4 in Ontario and 2 in Alberta). The totals include the K3 facility. The number is expected to remain fairly flat in the next few years, as there are no new builds; only uprates and refurbishments. It is also interesting to point out that the oldest plant was constructed in 1959—Unit 1 at Boundary Dam, Saskatchewan.

156CBC News website, “Grand Lake Station 3 months early”, March 10, 2010, http://www.cbc.ca/news/canada/new- brunswick/story/2010/03/10/nb-minto-grand-lake-closed-early-fire-437.html 157ibid 158OPG website, Nanticoke Generating Station, http://www.opg.com/power/thermal/nanticoke.asp

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Figure 1.21 Cumulative Total Coal Power Capacity in Canada (MW) 18000

16000

14000

12000

10000

8000

6000

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0 1959 1964 1969 1974 1979 1984 1989 1994 1999 2004 2009

Source: NRCAN,159 various company websites & CERI

Figure 1.22 illustrates a scenario if no additional coal-fired plants are built, under the assumptions that coal retirements begin in 2016 and that they have a 50-year plant life. It is important to point out that the average age of coal-fired generators being commissioned is 1981, or 30 years. This figure is similar to Figure 1.11 that examines coal plant retirements, cumulative total by state. Coal retirements begin in 2016, except in Ontario. Recall, the McGuinty government plans to retire all remaining coal power generating facilities by 2014.

If no new coal plants are built, the following illustrates the rapid decline of coal-fired generation in Canada. This lost electricity generation needs to be replaced by another fuel. In addition, other fuels need to replace the future reliance of coal power in the coming decades.

It is important to note that the cumulative total declines more rapidly assuming a shorter lifespan, and becomes less steep when assuming a longer lifespan.

159“Clean Coal: A compendium of Canada’s Participation”, NRCAN, 2007, http://www.nrcan.gc.ca/com/resoress/publications/ carbone/coalcarbon-eng.pdf?PHPSESSID=c3eac71055856ac30ae7c43ba69e01a4

March 2011 North America Natural Gas Market Dynamics: Coal-fired Generation in North America – A Review 31

Figure 1.22 Coal Plant Retirements, Cumulative Total by Province (50-year Life)

18000 Saskatchewan Ontario Nova Scotia New Brunswick Manitoba Alberta 16000

14000

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10000

8000

6000

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0

1962 2007 1965 1968 1971 1974 1977 1980 1983 1986 1989 1992 1995 1998 2001 2004 2010 2013 2016 2019 2022 2025 2028 2031 2034 2037 2040 1959 Source: NRCAN,160 various company websites & CERI

The role of coal in Ontario’s energy mix is bleak. But for Alberta, Saskatchewan and Nova Scotia, coal plays an important role in meeting growing energy demands. While Ontario is shutting down coal—an exercise that has not been without controversy and considerable planning—it seems that the aforementioned provinces are determined to examine and implement low-emission clean coal technologies. Older coal-fired units will be retired in the next 10 to 15 years, and while some will be refurbished with new technology, others will be replaced by state-of-the-art facilities that have greatly reduced emissions. This certainly seems to be the case with Alberta’s G3 and K3 generating units, as well as the massive and innovative Integrated Carbon Capture and Storage Demonstration Project which will modernize the 40-year old Unit 3 at Boundary Dam.161

In addition to exploring other technologies, such as IGCC, CO2/O2 combustion, CO2 capture and sequestration and beneficiation162, Canada has several other major clean coal technology initiatives. These include initiatives such as

160“Clean Coal: A compendium of Canada’s Participation”, NRCAN, 2007, http://www.nrcan.gc.ca/com/resoress/publications/ carbone/coalcarbon-eng.pdf?PHPSESSID=c3eac71055856ac30ae7c43ba69e01a4 161SaskPower website, Carbon Capture Storage, http://www.saskpower.com/sustainable_growth/projects/carbon_capture_ storage.shtml 162Graham R. Campbell, “Clean Coal Developments in Canada Towards a Sustainable Energy Future”, NRCAN, presented at Nova Scotia’s Energy R&D Forum, May 24-25, 2006, pp. 10.

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the Canadian Clean Power Coalition, the Clean Coal Technology Roadmap, the CO2 Capture and Storage Technology Roadmap, Network Initiatives and EnergyINet.163

In its 2007 Energy Futures Report, the NEB suggested that coal-fired generation in Canada would drop from 16,000 MW in 2005 to 10,000 MW in 2030.164 Much of that decrease is Ontario’s phasing out of coal. That being said, coal will continue to play an important role in Canada, predominantly in provinces that utilize coal.165 While conventional coal is in decline, the decline in Ontario will be partially offset by provinces building and utilizing new technologies.

163ibid 164NEB, “Coal-Fired Power Generation: A Perspective”, Energy Briefing Note, July 2008, pp. 6. 165Kevin Stone, Coal in Canada, NRCAN, presentation to the APEC Clean Fossil Energy Technical and Policy Seminar, October 2010, pp. 15.

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Appendix A: Existing Generating Units Over 100 MW in the US by State, Company, Plant Name, Capacity and Age of Unit, 2008166

Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation AL Alabama Power Co James H Miller Jr 705.5 1991 AL Alabama Power Co James H Miller Jr 705.5 1989 AL Alabama Power Co James H Miller Jr 705.5 1985 AL PowerSouth Energy Cooperative Charles R Lowman 236 1980 AL Alabama Power Co James H Miller Jr 705.5 1978 AL PowerSouth Energy Cooperative Charles R Lowman 236 1978 AL Alabama Power Co E C Gaston 952 1974 AL Alabama Power Co Gorgas 788.8 1972 AL Alabama Power Co Barry 788.8 1971 AL Alabama Power Co Barry 403.7 1969 AL Alabama Power Co Greene County 269.2 1966 AL Alabama Power Co Greene County 299.2 1965 AL Tennessee Valley Authority Colbert 550 1965 AL Tennessee Valley Authority Widows Creek 550 1965 AL Alabama Power Co E C Gaston 244.8 1962 AL Alabama Power Co E C Gaston 272 1961 AL Tennessee Valley Authority Widows Creek 575 1961 AL Alabama Power Co E C Gaston 272 1960 AL Alabama Power Co E C Gaston 272 1960 AL Alabama Power Co Barry 272 1959 AL Alabama Power Co Gorgas 190.4 1958 AL Alabama Power Co Gorgas 187.5 1956 AL Tennessee Valley Authority Colbert 200 1955 AL Tennessee Valley Authority Colbert 200 1955 AL Tennessee Valley Authority Colbert 200 1955 AL Tennessee Valley Authority Colbert 200 1955 AL Alabama Power Co Barry 153.1 1954 AL Alabama Power Co Barry 153.1 1954 AL Tennessee Valley Authority Widows Creek 140.6 1954 AL Tennessee Valley Authority Widows Creek 140.6 1954 AL Tennessee Valley Authority Widows Creek 140.6 1953

166EIA website, Existing Units end-2008, http://www.eia.gov/cneaf/electricity/page/capacity/existingunitsbs2008.xls

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation AL Alabama Power Co Gorgas 125 1952 AL Tennessee Valley Authority Widows Creek 140.6 1952 AL Tennessee Valley Authority Widows Creek 140.6 1952 AL Tennessee Valley Authority Widows Creek 140.6 1952 AL Alabama Power Co Gorgas 125 1951 AR Entergy Arkansas Inc Independence 850 1984 AR Entergy Arkansas Inc Independence 850 1983 AR Entergy Arkansas Inc White Bluff 850 1981 AR Entergy Arkansas Inc White Bluff 850 1980 AR Southwestern Electric Power Co Flint Creek 558 1978 AZ Tucson Electric Power Co Springerville 450 2006 AZ Tucson Electric Power Co Springerville 424.8 1990 AZ Tucson Electric Power Co Springerville 424.8 1985 AZ Arizona Public Service Co Cholla 414 1981 AZ Arizona Public Service Co Cholla 312.3 1980 AZ Salt River Project Coronado 410.9 1980 AZ Arizona Electric Pwr Coop Inc Apache Station 204 1979 AZ Arizona Electric Pwr Coop Inc Apache Station 204 1979 AZ Salt River Project Coronado 410.9 1979 AZ Arizona Public Service Co Cholla 288.9 1978 AZ Salt River Project Navajo 803.1 1976 AZ Salt River Project Navajo 803.1 1975 AZ Salt River Project Navajo 803.1 1974 AZ Tucson Electric Power Co H Wilson Sundt Generating Station 173.3 1967 AZ Arizona Public Service Co Cholla 113.6 1962 CA ACE Cogeneration Co ACE Cogeneration Facility 108 1990 CO Platte River Power Authority Rawhide 293.6 1984 CO Tri-State G & T Assn, Inc Craig 446.4 1984 CO Public Service Co of Colorado Pawnee 552.3 1981 CO Colorado Springs City of Ray D Nixon 207 1980 CO Tri-State G & T Assn, Inc Craig 446.4 1980 CO Tri-State G & T Assn, Inc Craig 446.4 1979 CO Public Service Co of Colorado Hayden 275.4 1976 CO Public Service Co of Colorado Comanche 396 1975 CO Colorado Springs City of Martin Drake 132 1974 CO Public Service Co of Colorado Comanche 382.5 1973 CO Public Service Co of Colorado Cherokee 380.8 1968 CO Public Service Co of Colorado Hayden 190 1965 CO Public Service Co of Colorado Valmont 191.7 1964 CO Public Service Co of Colorado Cherokee 170.5 1962 CO Public Service Co of Colorado Cherokee 125 1959

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation CO Public Service Co of Colorado Cherokee 125 1957 CO Public Service Co of Colorado Arapahoe 112 1955 CT AES Thames LLC AES Thames 213.9 1989 CT PSEG Power Connecticut LLC Bridgeport Station 400 1968 DE Indian River Operations Inc Indian River Generating Station 442.4 1980 DE Indian River Operations Inc Indian River Generating Station 176.8 1970 DE Conectiv Delmarva Gen Inc Edge Moor 176.8 1966 FL Orlando Utilities Comm Stanton Energy Center 464.5 1996 FL Tampa Electric Co Polk 192.9 1996 FL Tampa Electric Co Polk 133.4 1996 FL US Operating Services Company Indiantown Cogeneration LP 395.4 1995 FL US Operating Services Company Cedar Bay Generating Company LP 291.6 1994 FL Central Power & Lime Inc Central Power & Lime 125 1988 FL JEA St Johns River Power Park 679 1988 FL JEA St Johns River Power Park 679 1987 FL Orlando Utilities Comm Stanton Energy Center 464.5 1987 FL Seminole Electric Cooperative Inc Seminole 714.6 1985 FL Tampa Electric Co Big Bend 486 1985 FL Progress Energy Florida Inc Crystal River 739.2 1984 FL Seminole Electric Cooperative Inc Seminole 714.6 1984 FL City of Lakeland C D McIntosh Jr 363.8 1982 FL Progress Energy Florida Inc Crystal River 739.2 1982 FL Gainesville Regional Utilities Deerhaven Generating Station 250.7 1981 FL Tampa Electric Co Big Bend 445.5 1976 FL Gulf Power Co Crist 578 1973 FL Tampa Electric Co Big Bend 445.5 1973 FL Gulf Power Co Crist 369.7 1970 FL Tampa Electric Co Big Bend 445.5 1970 FL Progress Energy Florida Inc Crystal River 523.8 1969 FL Gulf Power Co Lansing Smith 190.4 1967 FL Progress Energy Florida Inc Crystal River 440.5 1966 FL Gulf Power Co Lansing Smith 149.6 1965 GA Georgia Power Co Scherer 891 1989 GA Georgia Power Co Scherer 891 1987 GA Georgia Power Co Scherer 891 1984 GA Georgia Power Co Scherer 891 1982 GA International Paper Co International Paper Savanna Mill 71.2 1981 GA Georgia Power Co McIntosh 177.6 1979 GA Georgia Power Co Wansley 952 1978 GA Georgia Power Co Wansley 952 1976

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation GA Georgia Power Co Bowen 952 1975 GA Georgia Power Co Bowen 952 1974 GA Georgia Power Co Yates 403.7 1974 GA Georgia Power Co Yates 403.7 1974 GA Georgia Power Co Bowen 788.8 1972 GA Georgia Power Co Bowen 805.8 1971 GA Georgia Power Co Hammond 578 1970 GA Georgia Power Co Harllee Branch 544 1969 GA Georgia Power Co Harllee Branch 544 1968 GA Georgia Power Co Harllee Branch 359 1967 GA Georgia Power Co Harllee Branch 299.2 1965 GA Georgia Power Co Kraft 103.5 1965 GA Georgia Power Co Jack McDonough 299.2 1964 GA Georgia Power Co Mitchell 163.2 1964 GA Georgia Power Co Jack McDonough 299.2 1963 GA Georgia Power Co Yates 156.2 1958 GA Georgia Power Co Yates 156.2 1957 GA Georgia Power Co Hammond 125 1955 GA Georgia Power Co Hammond 125 1954 GA Georgia Power Co Hammond 125 1954 GA Georgia Power Co Yates 122.5 1952 GA Georgia Power Co Yates 122.5 1950 GA Georgia Power Co Yates 122.5 1950 HI AES Hawaii Inc AES Hawaii 203 1992 IA MidAmerican Energy Co Walter Scott Jr Energy Center 922.5 2007 IA Archer Daniels Midland Co Archer Daniels Midland Cedar Rapids 101.1 2000 Board of Water Electric & IA Communications Muscatine Plant #1 175.5 1983 IA MidAmerican Energy Co Louisa 811.9 1983 IA Interstate Power and Light Co Ottumwa 726 1981 IA MidAmerican Energy Co George Neal South 640 1979 IA MidAmerican Energy Co Walter Scott Jr Energy Center 725.8 1978 IA Interstate Power and Light Co Lansing 274.5 1977 IA MidAmerican Energy Co George Neal North 549.8 1975 IA MidAmerican Energy Co George Neal North 349.2 1972 IA Interstate Power and Light Co Burlington 212 1968 IA Interstate Power and Light Co Milton L Kapp 218.4 1967 IA Interstate Power and Light Co Prairie Creek 148.7 1967 IA MidAmerican Energy Co George Neal North 147 1964 IA MidAmerican Energy Co Riverside 136 1961 IL Archer Daniels Midland Co Archer Daniels Midland Decatur 105 2005

March 2011 North America Natural Gas Market Dynamics: Coal-fired Generation in North America – A Review 37

Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation IL Ameren Energy Generating Co Newton 617.4 1982 IL City of Springfield Dallman 207.3 1978 IL Dynegy Midwest Generation Inc Havana 488 1978 IL Southern Illinois Power Coop Marion 173 1978 IL Ameren Energy Generating Co Newton 617.4 1977 Ameren Energy Resources IL Generating Co. Duck Creek 441 1976 IL Dynegy Midwest Generation Inc Baldwin Energy Complex 634.5 1975 IL Midwest Generations EME LLC Powerton 892.8 1975 IL Dynegy Midwest Generation Inc Baldwin Energy Complex 634.5 1973 IL Ameren Energy Generating Co Coffeen 616.5 1972 Ameren Energy Resources IL Generating Co. E D Edwards 363.8 1972 IL Midwest Generations EME LLC Powerton 892.8 1972 IL Dynegy Midwest Generation Inc Baldwin Energy Complex 625.1 1970 Ameren Energy Resources IL Generating Co. E D Edwards 280.5 1968 IL Dominion Energy Services Co Kincaid Generation LLC 659.5 1968 IL Midwest Generations EME LLC Fisk Street 374 1968 IL Dominion Energy Services Co Kincaid Generation LLC 659.5 1967 IL Midwest Generations EME LLC Joliet 29 660 1966 IL Ameren Energy Generating Co Coffeen 388.9 1965 IL Midwest Generations EME LLC Joliet 29 660 1965 IL Dynegy Midwest Generation Inc Wood River 387.6 1964 IL Midwest Generations EME LLC Will County 598.4 1963 IL Midwest Generations EME LLC Waukegan 355.3 1962 IL Midwest Generations EME LLC Crawford 358.1 1961 IL Ameren Energy Generating Co Meredosia 239.3 1960 Ameren Energy Resources IL Generating Co. E D Edwards 136 1960 IL Dynegy Midwest Generation Inc Hennepin Power Station 231.3 1959 IL Midwest Generations EME LLC Joliet 9 360.4 1959 IL Midwest Generations EME LLC Crawford 239.3 1958 IL Midwest Generations EME LLC Waukegan 326.4 1958 IL Midwest Generations EME LLC Will County 299.2 1957 IL Dynegy Midwest Generation Inc Vermilion 108.8 1956 IL Electric Energy Inc Joppa Steam 183.3 1955 IL Electric Energy Inc Joppa Steam 183.3 1955 IL Midwest Generations EME LLC Will County 183.7 1955 IL Midwest Generations EME LLC Will County 187.5 1955 IL Dynegy Midwest Generation Inc Wood River 112.5 1954 IL Electric Energy Inc Joppa Steam 183.3 1954

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation IL Electric Energy Inc Joppa Steam 183.3 1954 IL Electric Energy Inc Joppa Steam 183.3 1953 IL Electric Energy Inc Joppa Steam 183.3 1953 IN Duke Energy Indiana Inc Wabash River 192 1995 IN Indiana Michigan Power Co Rockport 1300 1989 IN Indianapolis Power & Light Co AES Petersburg 574.2 1986 IN Northern Indiana Pub Serv Co R M Schahfer 423.5 1986 IN Southern Indiana Gas & Elec Co A B Brown 265.2 1986 IN Indiana Michigan Power Co Rockport 1300 1984 IN Hoosier Energy R E C, Inc Merom 540 1983 IN Northern Indiana Pub Serv Co R M Schahfer 423.5 1983 IN Duke Energy Indiana Inc Gibson 667.9 1982 IN Hoosier Energy R E C, Inc Merom 540 1982 IN Duke Energy Indiana Inc Gibson 667.9 1979 IN Northern Indiana Pub Serv Co R M Schahfer 556.4 1979 IN Southern Indiana Gas & Elec Co A B Brown 265.2 1979 IN Duke Energy Indiana Inc Gibson 667.9 1978 IN Indianapolis Power & Light Co AES Petersburg 574.3 1977 IN Duke Energy Indiana Inc Gibson 667.9 1976 IN Northern Indiana Pub Serv Co R M Schahfer 540 1976 IN Duke Energy Indiana Inc Gibson 667.9 1975 IN Northern Indiana Pub Serv Co Michigan City 540 1974 IN City of Richmond Whitewater Valley 60.9 1973 IN Indianapolis Power & Light Co Harding Street 470.9 1973 IN Southern Indiana Gas & Elec Co F B Culley 265.2 1973 IN Duke Energy Indiana Inc Cayuga 531 1972 IN AGC Division of APG Inc Warrick 323 1970 IN Duke Energy Indiana Inc Cayuga 531 1970 IN Hoosier Energy R E C, Inc Frank E Ratts 116.6 1970 IN Hoosier Energy R E C, Inc Frank E Ratts 116.6 1970 IN Indianapolis Power & Light Co AES Petersburg 471 1969 IN Duke Energy Indiana Inc Wabash River 387 1968 IN Northern Indiana Pub Serv Co Bailly 413.1 1968 IN Indianapolis Power & Light Co AES Petersburg 253.4 1967 IN Southern Indiana Gas & Elec Co F B Culley 103.7 1966 IN AGC Division of APG Inc Warrick 144 1965 IN AGC Division of APG Inc Warrick 144 1964 IN Indiana Michigan Power Co Tanners Creek 579.7 1964 IN Northern Indiana Pub Serv Co Bailly 190.4 1962 IN State Line Energy LLC State Line Energy 179.5 1962 IN State Line Energy LLC State Line Energy 209.4 1962

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation IN Duke Energy Indiana Inc R Gallagher 150 1961 IN Indianapolis Power & Light Co Harding Street 113.6 1961 IN AGC Division of APG Inc Warrick 166.6 1960 IN Duke Energy Indiana Inc R Gallagher 150 1960 IN Duke Energy Indiana Inc R Gallagher 150 1959 IN City of Logansport Logansport 18 1958 IN Duke Energy Indiana Inc R Gallagher 150 1958 IN Indianapolis Power & Light Co Harding Street 113.5 1958 IN Duke Energy Indiana Inc Wabash River 125 1956 IN Indiana-Kentucky Electric Corp Clifty Creek 217.2 1956 IN Indianapolis Power & Light Co Eagle Valley 113.6 1956 IN Duke Energy Indiana Inc Wabash River 112.5 1955 IN Indiana-Kentucky Electric Corp Clifty Creek 217.2 1955 IN Indiana-Kentucky Electric Corp Clifty Creek 217.2 1955 IN Indiana-Kentucky Electric Corp Clifty Creek 217.2 1955 IN Indiana-Kentucky Electric Corp Clifty Creek 217.2 1955 IN Indiana-Kentucky Electric Corp Clifty Creek 217.2 1955 IN State Line Energy LLC State Line Energy 100 1955 IN State Line Energy LLC State Line Energy 124.9 1955 IN Duke Energy Indiana Inc Wabash River 123.2 1954 IN Indiana Michigan Power Co Tanners Creek 215.4 1954 IN Duke Energy Indiana Inc Wabash River 112.5 1953 IN Duke Energy Indiana Inc Wabash River 112.5 1953 IN Indiana Michigan Power Co Tanners Creek 152.5 1952 IN Indiana Michigan Power Co Tanners Creek 152.5 1951 KS Sunflower Electric Power Corp Holcomb 348.7 1983 KS Westar Energy Inc Jeffrey Energy Center 720 1983 KS Kansas City City of Nearman Creek 261 1981 KS Westar Energy Inc Jeffrey Energy Center 720 1980 KS Westar Energy Inc Jeffrey Energy Center 720 1978 KS Kansas City Power & Light Co La Cygne 685 1977 KS Kansas City Power & Light Co La Cygne 893 1973 KS Kansas City City of Quindaro 157.5 1971 KS Westar Energy Inc Lawrence Energy Center 403 1971 KS Westar Energy Inc Tecumseh Energy Center 150 1962 KS Westar Energy Inc Lawrence Energy Center 114 1960 KY East Kentucky Power Coop, Inc H L Spurlock 329.4 2005 KY Louisville Gas & Electric Co Trimble County 566.1 1990 KY Kentucky Utilities Co Ghent 556.2 1984 KY Western Kentucky Energy Corp D B Wilson 566.1 1984

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation KY Louisville Gas & Electric Co Mill Creek 543.6 1982 KY Duke Energy Kentucky Inc East Bend 669.3 1981 KY East Kentucky Power Coop, Inc H L Spurlock 592.1 1981 KY Kentucky Utilities Co Ghent 556.5 1981 KY Western Kentucky Energy Corp R D Green 293 1981 KY Western Kentucky Energy Corp R D Green 293 1979 KY Louisville Gas & Electric Co Mill Creek 462.6 1978 KY East Kentucky Power Coop, Inc H L Spurlock 357.6 1977 KY Kentucky Utilities Co Ghent 556.3 1977 KY City of Owensboro Elmer Smith 282.1 1974 KY Kentucky Utilities Co Ghent 556.9 1974 KY Louisville Gas & Electric Co Mill Creek 355.5 1974 KY Western Kentucky Energy Corp HMP&L Station Two Henderson 205 1974 KY Western Kentucky Energy Corp HMP&L Station Two Henderson 200 1973 KY Louisville Gas & Electric Co Mill Creek 355.5 1972 KY Kentucky Utilities Co E W Brown 446.3 1971 KY Western Kentucky Energy Corp Kenneth C Coleman 192 1971 KY Tennessee Valley Authority Paradise 1150.2 1970 KY Western Kentucky Energy Corp Kenneth C Coleman 205 1970 KY East Kentucky Power Coop, Inc Cooper 230.4 1969 KY Kentucky Power Co Big Sandy 816.3 1969 KY Louisville Gas & Electric Co Cane Run 272 1969 KY Western Kentucky Energy Corp Kenneth C Coleman 205 1969 KY Louisville Gas & Electric Co Cane Run 209.4 1966 KY East Kentucky Power Coop, Inc Cooper 113.6 1965 KY City of Owensboro Elmer Smith 163.2 1964 KY Kentucky Power Co Big Sandy 280.5 1963 KY Kentucky Utilities Co E W Brown 179.5 1963 KY Tennessee Valley Authority Paradise 704 1963 KY Tennessee Valley Authority Paradise 704 1963 KY Louisville Gas & Electric Co Cane Run 163.2 1962 KY Kentucky Utilities Co Green River 113.6 1959 KY Kentucky Utilities Co E W Brown 113.6 1957 KY Tennessee Valley Authority Shawnee 175 1956 KY Tennessee Valley Authority Shawnee 175 1955 KY Tennessee Valley Authority Shawnee 175 1955 KY Tennessee Valley Authority Shawnee 175 1954 KY Tennessee Valley Authority Shawnee 175 1954 KY Tennessee Valley Authority Shawnee 175 1954 KY Tennessee Valley Authority Shawnee 175 1954 KY Tennessee Valley Authority Shawnee 175 1953

March 2011 North America Natural Gas Market Dynamics: Coal-fired Generation in North America – A Review 41

Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation KY Tennessee Valley Authority Shawnee 175 1953 KY Tennessee Valley Authority Shawnee 175 1953 LA Cleco Power LLC Dolet Hills 720.7 1986 LA Louisiana Generating LLC Big Cajun 2 619 1983 LA Cleco Power LLC Rodemacher 558 1982 LA Entergy Gulf States Louisiana LLC R S Nelson 614.6 1982 LA Louisiana Generating LLC Big Cajun 2 626 1982 LA Louisiana Generating LLC Big Cajun 2 626 1981 MA Dominion Energy New England Brayton Point 241 1964 MA Dominion Energy New England Brayton Point 241 1963 FirstLight Power Resources MA Services LLC Mount Tom 136 1960 MA Somerset Power LLC Somerset Station 100 1959 MA Dominion Energy New England Brayton Point 642.6 1958 MA Dominion Energy New England Salem Harbor 165.7 1958 MD AES WR Ltd Partnership AES Warrior Run Cogeneration Facility 229 1999 MD Constellation Power Source Gen Brandon Shores 685 1991 MD Constellation Power Source Gen Brandon Shores 685 1984 MD Mirant Mid-Atlantic LLC Morgantown Generating Plant 626 1971 MD Mirant Mid-Atlantic LLC Morgantown Generating Plant 626 1970 MD Constellation Power Source Gen Herbert A Wagner 359 1966 MD Mirant Chalk Point LLC Chalk Point LLC 364 1965 MD Mirant Chalk Point LLC Chalk Point LLC 364 1964 MD Constellation Power Source Gen C P Crane 209.4 1963 MD Mirant Mid-Atlantic LLC Dickerson 196 1962 MD Constellation Power Source Gen C P Crane 190.4 1961 MD Mirant Mid-Atlantic LLC Dickerson 196 1960 MD Constellation Power Source Gen Herbert A Wagner 136 1959 MD Mirant Mid-Atlantic LLC Dickerson 196 1959 ME NewPage Corporation Rumford Cogeneration 102.6 1990 MI Detroit Edison Co Belle River 697.5 1985 MI Detroit Edison Co Belle River 697.5 1984 MI Consumers Energy Co J H Campbell 916.8 1980 MI Detroit Edison Co Monroe 817.2 1974 MI Detroit Edison Co Monroe 822.6 1973 MI Detroit Edison Co Monroe 822.6 1973 MI Lansing Board of Water and Light Erickson Station 154.7 1973 MI Detroit Edison Co Monroe 817.2 1971 MI Detroit Edison Co St Clair 544.5 1969 MI Detroit Edison Co Harbor Beach 121 1968

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation MI Detroit Edison Co Trenton Channel 535.5 1968 MI Consumers Energy Co J H Campbell 403.9 1967 MI Consumers Energy Co J H Campbell 265.2 1962 MI Detroit Edison Co St Clair 352.7 1961 MI Consumers Energy Co Dan E Karn 136 1959 MI Consumers Energy Co Dan E Karn 136 1959 MI Consumers Energy Co J C Weadock 156.3 1958 MI Detroit Edison Co River Rouge 358.1 1958 MI Consumers Energy Co B C Cobb 156.3 1957 MI Detroit Edison Co River Rouge 292.5 1957 MI Consumers Energy Co B C Cobb 156.3 1956 MI Consumers Energy Co J C Weadock 156.3 1955 MI Detroit Edison Co St Clair 168.7 1954 MI Detroit Edison Co St Clair 156.2 1954 MI Consumers Energy Co J R Whiting 132.8 1953 MI Detroit Edison Co St Clair 156.2 1953 MI Detroit Edison Co St Clair 168.7 1953 MI Consumers Energy Co J R Whiting 106.3 1952 MI Consumers Energy Co J R Whiting 106.3 1952 MI Detroit Edison Co Trenton Channel 120 1950 MI Detroit Edison Co Trenton Channel 120 1949 MN Northern States Power Co Riverside 165 1987 MN Northern States Power Co Sherburne County 900 1987 MN Minnesota Power Inc Clay Boswell 558 1980 MN Northern States Power Co Sherburne County 765.3 1977 MN Northern States Power Co Sherburne County 765.3 1976 MN Minnesota Power Inc Clay Boswell 364.5 1973 MN Northern States Power Co Riverside 238.8 1964 MN Northern States Power Co Black Dog 179.5 1960 MN Northern States Power Co Allen S King 598.4 1958 MO Associated Electric Coop, Inc Thomas Hill 670 1982 MO City of Sikeston Sikeston Power Station 261 1981 MO Kansas City Power & Light Co Iatan 726 1980 MO Associated Electric Coop, Inc New Madrid 600 1977 MO Union Electric Co Rush Island 621 1977 MO City Utilities of Springfield Southwest Power Station 194 1976 MO Union Electric Co Rush Island 621 1976 MO Union Electric Co Labadie 621 1973 MO Associated Electric Coop, Inc New Madrid 600 1972 MO Union Electric Co Labadie 621 1972 MO Union Electric Co Labadie 573.7 1971

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation MO City Utilities of Springfield James River Power Station 105 1970 MO Empire District Electric Co Asbury 212.8 1970 MO Union Electric Co Labadie 573.7 1970 MO Associated Electric Coop, Inc Thomas Hill 285 1969 MO Kansas City Power & Light Co Hawthorn 594.3 1969 KCP&L Greater Missouri MO Operations Co Sibley 419 1969 MO Union Electric Co Sioux 549.7 1968 MO Union Electric Co Sioux 549.7 1967 MO Associated Electric Coop, Inc Thomas Hill 180 1966 MO Kansas City Power & Light Co Montrose 188 1964 MO Union Electric Co Meramec 359 1961 MO Kansas City Power & Light Co Montrose 188 1960 MO Union Electric Co Meramec 289 1959 MO Kansas City Power & Light Co Montrose 188 1958 MO Union Electric Co Meramec 137.5 1954 MO Union Electric Co Meramec 137.5 1953 MS Choctaw Generating LP Red Hills Generating Facility 513.7 2001 MS Mississippi Power Co Victor J Daniel Jr 548.3 1981 MS South Mississippi El Pwr Assn R D Morrow 200 1978 MS South Mississippi El Pwr Assn R D Morrow 200 1978 MS Mississippi Power Co Victor J Daniel Jr 548.3 1977 MS Mississippi Power Co Jack Watson 578 1973 MS Mississippi Power Co Jack Watson 299.2 1968 MT Rocky Mountain Power Inc Hardin Generator Project 115.7 2006 MT PPL Montana LLC Colstrip 778 1986 MT PPL Montana LLC Colstrip 778 1984 MT PPL Montana LLC Colstrip 358 1976 MT PPL Montana LLC Colstrip 358 1975 MT PPL Montana LLC J E Corette Plant 172.8 1968 NC Westmoreland Partners Roanoke Valley Energy Facility I 182.3 1994 NC Progress Energy Carolinas Inc Mayo 735.8 1983 NC Progress Energy Carolinas Inc Roxboro 745.2 1980 NC Duke Energy Carolinas, LLC Belews Creek 1080.1 1975 NC Duke Energy Carolinas, LLC Belews Creek 1080.1 1974 NC Progress Energy Carolinas Inc Roxboro 745.2 1973 NC Duke Energy Carolinas, LLC Cliffside 570.9 1972 NC Progress Energy Carolinas Inc L V Sutton 446.6 1972 NC Progress Energy Carolinas Inc Asheville 207 1971 NC Duke Energy Carolinas, LLC Marshall 648 1970

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation NC Duke Energy Carolinas, LLC Marshall 648 1969 NC Progress Energy Carolinas Inc Roxboro 657 1968 NC Duke Energy Carolinas, LLC Marshall 350 1966 NC Progress Energy Carolinas Inc Roxboro 410.8 1966 NC Duke Energy Carolinas, LLC Marshall 350 1965 NC Progress Energy Carolinas Inc Asheville 206.6 1964 NC Progress Energy Carolinas Inc Lee 252.4 1962 NC Duke Energy Carolinas, LLC G G Allen 275 1961 NC Duke Energy Carolinas, LLC G G Allen 275 1960 NC Duke Energy Carolinas, LLC G G Allen 275 1959 NC Progress Energy Carolinas Inc Cape Fear 187.9 1958 NC Duke Energy Carolinas, LLC G G Allen 165 1957 NC Duke Energy Carolinas, LLC G G Allen 165 1957 NC Progress Energy Carolinas Inc Cape Fear 140.6 1956 NC Duke Energy Carolinas, LLC Dan River 150 1955 NC Progress Energy Carolinas Inc L V Sutton 112.5 1955 NC Duke Energy Carolinas, LLC Riverbend 133 1954 NC Duke Energy Carolinas, LLC Riverbend 133 1954 NC Progress Energy Carolinas Inc L V Sutton 112.5 1954 NC Duke Energy Carolinas, LLC Buck 125 1953 NC Duke Energy Carolinas, LLC Buck 125 1953 NC Duke Energy Carolinas, LLC Riverbend 100 1952 NC Duke Energy Carolinas, LLC Riverbend 100 1952 ND Basin Electric Power Coop Antelope Valley 434.9 1986 ND Basin Electric Power Coop Antelope Valley 434.9 1984 ND Otter Tail Power Co Coyote 450 1981 ND Great River Energy Coal Creek 605 1980 ND Great River Energy Coal Creek 605 1979 ND Minnkota Power Coop, Inc Milton R Young 477 1977 ND Basin Electric Power Coop Leland Olds 440 1975 ND Minnkota Power Coop, Inc Milton R Young 257 1970 ND Great River Energy Stanton 190.2 1967 ND Basin Electric Power Coop Leland Olds 216 1966 NE Grand Island City of Platte 109.8 1982 NE Nebraska Public Power District Gerald Gentleman 681.3 1982 NE Nebraska Public Power District Gerald Gentleman 681.3 1979 NE Omaha Public Power District Nebraska City 651.6 1979 NE Omaha Public Power District North Omaha 217.6 1968 NE Nebraska Public Power District Sheldon 119.9 1965 NE Omaha Public Power District North Omaha 136 1963 NE Nebraska Public Power District Sheldon 108.8 1961

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation NE Omaha Public Power District North Omaha 108.8 1959 NE Omaha Public Power District North Omaha 108.8 1957 NH Public Service Co of NH Merrimack 345.6 1968 NH Public Service Co of NH Merrimack 113.6 1960 NJ US Operating Services Company Chambers Cogeneration LP 285 1994 NJ US Operating Services Company Logan Generating Company LP 242.3 1994 NJ PSEG Fossil LLC PSEG Hudson Generating Station 659.7 1968 NJ RC Cape May Holdings LLC B L England 163.2 1964 NJ RC Cape May Holdings LLC B L England 136 1962 NJ PSEG Fossil LLC PSEG Mercer Generating Station 326.4 1961 NJ PSEG Fossil LLC PSEG Mercer Generating Station 326.4 1960 NM Tri-State G & T Assn, Inc Escalante 257 1984 NM Public Service Co of NM San Juan 555 1982 NM Public Service Co of NM San Juan 555 1979 NM Public Service Co of NM San Juan 369 1976 NM Public Service Co of NM San Juan 369 1973 NM Arizona Public Service Co Four Corners 818.1 1970 NM Arizona Public Service Co Four Corners 818.1 1969 NM Arizona Public Service Co Four Corners 253.4 1964 NM Arizona Public Service Co Four Corners 190 1963 NM Arizona Public Service Co Four Corners 190 1963 Newmont Nevada Energy NV Investment, LLC TS Power Plant 242 2008 NV Sierra Pacific Power Co North Valmy 289.8 1985 NV Nevada Power Co Reid Gardner 294.8 1983 NV Sierra Pacific Power Co North Valmy 277.2 1981 NV Nevada Power Co Reid Gardner 114 1976 NV Nevada Power Co Reid Gardner 114 1968 NV Nevada Power Co Reid Gardner 114 1965 NY AES Somerset LLC AES Somerset LLC 655.1 1984 NY Dynegy Northeast Gen Inc Danskammer Generating Station 239.4 1967 NY Dunkirk Power LLC Dunkirk Generating Plant 217.6 1960 NY Dunkirk Power LLC Dunkirk Generating Plant 217.6 1959 NY Dynegy Northeast Gen Inc Danskammer Generating Station 147.1 1959 NY NRG Huntley Operations Inc C R Huntley Generating Station 218 1958 NY NRG Huntley Operations Inc C R Huntley Generating Station 218 1957 NY AES Cayuga LLC AES Cayuga 167.2 1955 NY AES Cayuga LLC AES Cayuga 155.3 1955 NY AES Greenidge AES Greenidge LLC 112.5 1953 OH Duke Energy Ohio Inc W H Zimmer 1425.6 1991

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation OH Dayton Power & Light Co Killen Station 660.6 1982 OH Columbus Southern Power Co Conesville 443.9 1978 OH Duke Energy Ohio Inc Miami Fort 557.7 1978 OH Cardinal Operating Co Cardinal 650 1977 OH Columbus Southern Power Co Conesville 443.9 1976 OH Duke Energy Ohio Inc Miami Fort 557.1 1975 OH Ohio Power Co General James M Gavin 1300 1975 OH Dayton Power & Light Co J M Stuart 610.2 1974 OH Ohio Power Co General James M Gavin 1300 1974 OH Columbus Southern Power Co Conesville 841.5 1973 OH Dayton Power & Light Co J M Stuart 610.2 1972 OH FirstEnergy Generation Corp Eastlake 680 1972 OH Dayton Power & Light Co J M Stuart 610.2 1971 OH FirstEnergy Generation Corp W H Sammis 680 1971 OH Dayton Power & Light Co J M Stuart 610.2 1970 OH Orion Power Midwest LP Avon Lake 680 1970 OH Duke Energy Ohio Inc Walter C Beckjord 460.8 1969 OH FirstEnergy Generation Corp W H Sammis 680 1969 OH FirstEnergy Generation Corp Bay Shore 217.6 1968 OH Ohio Power Co Muskingum River 615.2 1968 OH Cardinal Operating Co Cardinal 615.2 1967 OH Cardinal Operating Co Cardinal 615.2 1967 OH FirstEnergy Generation Corp W H Sammis 334 1967 OH FirstEnergy Generation Corp Bay Shore 140.6 1963 OH Columbus Southern Power Co Conesville 161.5 1962 OH Duke Energy Ohio Inc Walter C Beckjord 244.8 1962 OH FirstEnergy Generation Corp Lake Shore 256 1962 OH FirstEnergy Generation Corp W H Sammis 190.4 1962 OH FirstEnergy Generation Corp W H Sammis 190.4 1961 OH Duke Energy Ohio Inc Miami Fort 163.2 1960 OH FirstEnergy Generation Corp W H Sammis 190.4 1960 OH FirstEnergy Generation Corp Bay Shore 140.6 1959 OH FirstEnergy Generation Corp W H Sammis 190.4 1959 OH Duke Energy Ohio Inc Walter C Beckjord 163.2 1958 OH FirstEnergy Generation Corp Ashtabula 256 1958 OH Ohio Power Co Muskingum River 237.5 1958 OH Ohio Power Co Muskingum River 237.5 1957 OH FirstEnergy Generation Corp Eastlake 208 1956 OH Columbus Southern Power Co Picway 106.2 1955 OH FirstEnergy Generation Corp R E Burger 156.2 1955 OH FirstEnergy Generation Corp R E Burger 156.2 1955

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation OH Ohio Valley Electric Corp Kyger Creek 217.3 1955 OH Ohio Valley Electric Corp Kyger Creek 217.3 1955 OH Ohio Valley Electric Corp Kyger Creek 217.3 1955 OH Ohio Valley Electric Corp Kyger Creek 217.3 1955 OH Ohio Valley Electric Corp Kyger Creek 217.3 1955 OH Duke Energy Ohio Inc Walter C Beckjord 125 1954 OH FirstEnergy Generation Corp Eastlake 123 1954 OH Ohio Power Co Muskingum River 219.6 1954 OH Orion Power Midwest LP Niles 132.8 1954 OH Orion Power Midwest LP Niles 132.8 1954 OH Duke Energy Ohio Inc Walter C Beckjord 112.5 1953 OH FirstEnergy Generation Corp Eastlake 123 1953 OH FirstEnergy Generation Corp Eastlake 123 1953 OH Ohio Power Co Muskingum River 219.6 1953 OH Duke Energy Ohio Inc Walter C Beckjord 115 1952 OH FirstEnergy Generation Corp R E Burger 103.4 1950 OK AES Shady Point LLC AES Shady Point LLC 175 1990 OK AES Shady Point LLC AES Shady Point LLC 175 1990 OK Grand River Dam Authority GRDA 520 1985 OK Oklahoma Gas & Electric Co Muskogee 572 1984 Georgia Pacific Consumer Products OK LP Muskogee Mill 44.5 1982 OK Western Farmers Elec Coop, Inc Hugo 446 1982 OK Grand River Dam Authority GRDA 490 1981 OK Oklahoma Gas & Electric Co Sooner 569 1980 OK Public Service Co of Oklahoma Northeastern 473 1980 Georgia Pacific Consumer Products OK LP Muskogee Mill 44.5 1979 OK Oklahoma Gas & Electric Co Sooner 569 1979 OK Public Service Co of Oklahoma Northeastern 473 1979 OK Oklahoma Gas & Electric Co Muskogee 572 1978 OK Oklahoma Gas & Electric Co Muskogee 572 1977 OR Portland General Electric Co Boardman 601 1980 Reliant Energy Wholesale PA Generation LLC Seward 585 2004 PA Inter-Power/AhlCon Partners, L.P. Colver Power Project 118 1995 PA US Operating Services Company Northampton Generating Company LP 114.1 1995 PA AES Beaver Valley AES Beaver Valley Partners Beaver Valley 114 1987 PA FirstEnergy Generation Corp Bruce Mansfield 913.7 1980 PA FirstEnergy Generation Corp Bruce Mansfield 913.7 1977 PA Midwest Generations EME LLC Homer City Station 692 1977

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation PA FirstEnergy Generation Corp Bruce Mansfield 913.7 1976 PA PPL Montour LLC PPL Montour 819 1973 PA PPL Montour LLC PPL Montour 805.5 1972 PA Allegheny Energy Supply Co LLC Hatfields Ferry Power Station 576 1971 PA Reliant Engy NE Management Co Conemaugh 936 1971 PA Allegheny Energy Supply Co LLC Hatfields Ferry Power Station 576 1970 PA Orion Power Midwest LP Cheswick Power Plant 637 1970 PA Reliant Engy NE Management Co Conemaugh 936 1970 PA Allegheny Energy Supply Co LLC Hatfields Ferry Power Station 576 1969 PA Midwest Generations EME LLC Homer City Station 660 1969 PA Midwest Generations EME LLC Homer City Station 660 1969 PA PPL Brunner Island LLC PPL Brunner Island 790.4 1969 PA Reliant Engy NE Management Co Keystone 936 1968 PA Reliant Engy NE Management Co Keystone 936 1967 PA PPL Brunner Island LLC PPL Brunner Island 405 1965 PA Orion Power Midwest LP New Castle Plant 136 1964 PA Allegheny Energy Supply Co LLC Mitchell Power Station 299.2 1963 PA Reliant Energy Mid-Atlantic PH Portland 255 1962 PA PPL Brunner Island LLC PPL Brunner Island 363.3 1961 PA Exelon Power Eddystone Generating Station 353.6 1960 PA Exelon Power Eddystone Generating Station 353.6 1960 PA Orion Power Midwest LP Elrama Power Plant 185 1960 PA Reliant Energy Mid-Atlantic PH Shawville 188 1960 PA Allegheny Energy Supply Co LLC Armstrong Power Station 163.2 1959 PA Reliant Energy Mid-Atlantic PH Shawville 188 1959 PA Allegheny Energy Supply Co LLC Armstrong Power Station 163.2 1958 PA Orion Power Midwest LP New Castle Plant 114 1958 PA Reliant Energy Mid-Atlantic PH Portland 172 1958 PA Exelon Power Cromby Generating Station 187.5 1954 PA Orion Power Midwest LP Elrama Power Plant 125 1954 PA Reliant Energy Mid-Atlantic PH Shawville 125 1954 PA Reliant Energy Mid-Atlantic PH Shawville 125 1954 PA Orion Power Midwest LP Elrama Power Plant 100 1953 PA Sunbury Generation LP Sunbury Generation LP 156.2 1953 PA Orion Power Midwest LP Elrama Power Plant 100 1952 PA Sunbury Generation LP Sunbury Generation LP 103.5 1951 SC South Carolina Pub Serv Auth Cross 652 2008 SC South Carolina Pub Serv Auth Cross 591 2007 SC South Carolina Electric&Gas Co Cope 417.3 1996 SC South Carolina Pub Serv Auth Cross 590.9 1995 SC South Carolina Pub Serv Auth Cross 556.2 1984

March 2011 North America Natural Gas Market Dynamics: Coal-fired Generation in North America – A Review 49

Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation SC South Carolina Pub Serv Auth Winyah 315 1981 SC South Carolina Pub Serv Auth Winyah 315 1980 SC South Carolina Pub Serv Auth Winyah 315 1977 SC South Carolina Pub Serv Auth Winyah 315 1975 SC South Carolina Genertg Co, Inc Williams 632.7 1973 SC South Carolina Electric&Gas Co Wateree 385.9 1971 SC South Carolina Electric&Gas Co Wateree 385.9 1970 SC South Carolina Pub Serv Auth Jefferies 172.8 1970 SC South Carolina Pub Serv Auth Jefferies 172.8 1970 SC South Carolina Electric&Gas Co Canadys Steam 217.6 1967 SC South Carolina Electric&Gas Co Canadys Steam 136 1964 SC South Carolina Electric&Gas Co Canadys Steam 136 1962 SC Progress Energy Carolinas Inc H B Robinson 206.6 1960 SC Duke Energy Carolinas, LLC W S Lee 175 1958 SC South Carolina Electric&Gas Co McMeekin 146.8 1958 SC South Carolina Electric&Gas Co McMeekin 146.8 1958 SC South Carolina Electric&Gas Co Urquhart 100 1955 SD Otter Tail Power Co Big Stone 456 1975 TN Tennessee Valley Authority Cumberland 1300 1973 TN Tennessee Valley Authority Cumberland 1300 1973 TN Tennessee Valley Authority Bull Run 950 1967 TN Tennessee Valley Authority Allen Steam Plant 330 1959 TN Tennessee Valley Authority Allen Steam Plant 330 1959 TN Tennessee Valley Authority Allen Steam Plant 330 1959 TN Tennessee Valley Authority Gallatin 327.6 1959 TN Tennessee Valley Authority Gallatin 327.6 1959 TN Tennessee Valley Authority Johnsonville 172.8 1959 TN Tennessee Valley Authority Johnsonville 172.8 1959 TN Tennessee Valley Authority Johnsonville 172.8 1959 TN Tennessee Valley Authority Johnsonville 172.8 1958 TN Tennessee Valley Authority Gallatin 300 1957 TN Tennessee Valley Authority John Sevier 200 1957 TN Tennessee Valley Authority Gallatin 300 1956 TN Tennessee Valley Authority John Sevier 200 1956 TN Tennessee Valley Authority John Sevier 200 1955 TN Tennessee Valley Authority John Sevier 200 1955 TN Tennessee Valley Authority Kingston 200 1955 TN Tennessee Valley Authority Kingston 200 1955 TN Tennessee Valley Authority Kingston 200 1955 TN Tennessee Valley Authority Kingston 200 1955

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation TN Tennessee Valley Authority Kingston 200 1955 TN Tennessee Valley Authority Kingston 175 1954 TN Tennessee Valley Authority Kingston 175 1954 TN Tennessee Valley Authority Kingston 175 1954 TN Tennessee Valley Authority Kingston 175 1954 TN Tennessee Valley Authority Johnsonville 147 1953 TN Tennessee Valley Authority Johnsonville 125 1952 TN Tennessee Valley Authority Johnsonville 147 1952 TN Tennessee Valley Authority Johnsonville 125 1952 TN Tennessee Valley Authority Johnsonville 125 1951 TN Tennessee Valley Authority Johnsonville 125 1951 TX San Antonio City of J K Spruce 566 1992 TX Altura Power Twin Oaks Power One 174.6 1991 TX Altura Power Twin Oaks Power One 174.6 1990 TX Lower Colorado River Authority Fayette Power Project 460 1988 TX NRG Texas Power LLC Limestone 956.8 1986 TX Public Service Co of Oklahoma Oklaunion 720 1986 TX NRG Texas Power LLC Limestone 893 1985 TX Southwestern Electric Power Pirkey 721 1985 TX Southwestern Public Service Tolk 568 1985 TX Texas Municipal Power Agency Gibbons Creek 453.5 1983 TX NRG Texas Power LLC W A Parish 614.6 1982 TX San Miguel Electric Coop, Inc San Miguel 410 1982 TX Southwestern Electric Power Welsh 558 1982 TX Southwestern Public Service Tolk 568 1982 TX TXU Generation Co LP Sandow No 4 590.6 1981 TX ANP-Coleto Creek Coleto Creek 600.4 1980 TX Lower Colorado River Authority Fayette Power Project 615 1980 TX NRG Texas Power LLC W A Parish 614.6 1980 TX Southwestern Electric Power Welsh 558 1980 TX Southwestern Public Service Harrington 360 1980 TX Lower Colorado River Authority Fayette Power Project 615 1979 TX TXU Generation Co LP Martin Lake 793.2 1979 TX NRG Texas Power LLC W A Parish 734.1 1978 TX San Antonio City of J T Deely 446 1978 TX Southwestern Public Service Harrington 360 1978 TX TXU Generation Co LP Martin Lake 793.2 1978 TX TXU Generation Co LP Monticello 793.2 1978 TX NRG Texas Power LLC W A Parish 734.1 1977 TX San Antonio City of J T Deely 486 1977 TX Southwestern Electric Power Welsh 558 1977

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation TX TXU Generation Co LP Martin Lake 793.2 1977 TX Southwestern Public Service Co Harrington 360 1976 TX TXU Generation Co LP Monticello 593.4 1975 TX TXU Generation Co LP Monticello 593.4 1974 TX TXU Generation Co LP Big Brown 593.4 1972 TX TXU Generation Co LP Big Brown 593.4 1971 UT Los Angeles City of Intermountain Power Project 820 1987 UT Deseret Generation & Tran Coop Bonanza 499.5 1986 UT Los Angeles City of Intermountain Power Project 820 1986 UT PacifiCorp Hunter 495.6 1983 UT PacifiCorp Hunter 488.3 1980 UT PacifiCorp Hunter 488.3 1978 UT PacifiCorp Huntington 498 1977 UT PacifiCorp Huntington 498 1974 UT PacifiCorp Carbon 113.6 1957 VA Birchwood Power Partners LP Birchwood Power 258.3 1996 VA Virginia Electric & Power Co Clover 424 1996 VA Virginia Electric & Power Co Clover 424 1995 VA Virginia Electric & Power Co Chesterfield 693.9 1969 VA Virginia Electric & Power Co Chesterfield 359 1964 VA Virginia Electric & Power Co Chesapeake 239.3 1962 VA Appalachian Power Co Clinch River 237.5 1961 VA Virginia Electric & Power Co Chesterfield 187.5 1960 VA Virginia Electric & Power Co Chesapeake 185.2 1959 VA Virginia Electric & Power Co Yorktown 187.5 1959 VA Appalachian Power Co Clinch River 237.5 1958 VA Appalachian Power Co Clinch River 237.5 1958 VA Virginia Electric & Power Co Bremo Bluff 185.2 1958 VA Appalachian Power Co Glen Lyn 237.5 1957 VA Mirant Potomac River LLC Potomac River 110 1957 VA Virginia Electric & Power Co Yorktown 187.5 1957 VA Mirant Potomac River LLC Potomac River 110 1956 VA Mirant Potomac River LLC Potomac River 110 1954 VA Virginia Electric & Power Co Chesapeake 112.5 1954 VA Virginia Electric & Power Co Chesapeake 112.5 1953 VA Virginia Electric & Power Co Chesterfield 112.5 1952 VA Appalachian Power Co Glen Lyn 100 1944 WA TransAlta Centralia Gen LLC Transalta Centralia Generation 729.9 1973 WA TransAlta Centralia Gen LLC Transalta Centralia Generation 729.9 1972 WI Wisconsin Public Service Corp Weston 595 2008

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation WI Wisconsin Electric Power Co Pleasant Prairie 616.5 1985 WI Wisconsin Power & Light Co Edgewater 380 1985 WI Wisconsin Public Service Corp Weston 350.5 1981 WI Wisconsin Electric Power Co Pleasant Prairie 616.5 1980 WI Dairyland Power Coop John P Madgett 387 1979 WI Wisconsin Power & Light Co Columbia 511 1978 WI Wisconsin Power & Light Co Columbia 512 1975 WI Dairyland Power Coop Genoa 345.6 1969 WI Wisconsin Electric Power Co Valley 136 1969 WI Wisconsin Power & Light Co Edgewater 330 1969 WI Wisconsin Electric Power Co Valley 136 1968 WI Wisconsin Electric Power Co South Oak Creek 324 1967 WI Wisconsin Electric Power Co South Oak Creek 317.6 1965 WI Wisconsin Public Service Corp Pulliam 149.6 1964 WI Wisconsin Power & Light Co Nelson Dewey 100 1962 WI Wisconsin Electric Power Co South Oak Creek 275 1961 WI Wisconsin Electric Power Co South Oak Creek 275 1959 WI Wisconsin Power & Light Co Nelson Dewey 100 1959 WV Allegheny Energy Supply Co LLC Pleasants Power Station 684 1980 WV Appalachian Power Co Mountaineer 1300 1980 WV Allegheny Energy Supply Co LLC Pleasants Power Station 684 1979 WV Allegheny Energy Supply Co LLC Harrison Power Station 684 1974 WV Allegheny Energy Supply Co LLC Harrison Power Station 684 1973 WV Appalachian Power Co John E Amos 1300 1973 WV Virginia Electric & Power Co Mt Storm 522 1973 WV Allegheny Energy Supply Co LLC Harrison Power Station 684 1972 WV Appalachian Power Co John E Amos 816.3 1972 WV Appalachian Power Co John E Amos 816.3 1971 WV Ohio Power Co Mitchell 816.3 1971 WV Ohio Power Co Mitchell 816.3 1971 WV Monongahela Power Co Fort Martin Power Station 576 1968 WV Monongahela Power Co Fort Martin Power Station 576 1967 WV Virginia Electric & Power Co Mt Storm 570.2 1966 WV Virginia Electric & Power Co Mt Storm 570.2 1965 WV Appalachian Power Co Philip Sporn 495.5 1960 WV Monongahela Power Co Willow Island 163.2 1960 WV Ohio Power Co Kammer 237.5 1959 WV Ohio Power Co Kammer 237.5 1958 WV Ohio Power Co Kammer 237.5 1958 WV Monongahela Power Co Albright 140.2 1954 WV Appalachian Power Co Kanawha River 219.6 1953

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Nameplate Initial Year Capacity of State Company Plant Name (MW) Operation WV Appalachian Power Co Kanawha River 219.6 1953 WV Appalachian Power Co Philip Sporn 152.5 1952 WV Appalachian Power Co Philip Sporn 152.5 1951 WV Appalachian Power Co Philip Sporn 152.5 1950 WV Appalachian Power Co Philip Sporn 152.5 1950 WY Basin Electric Power Coop Laramie River Station 570 1982 WY Basin Electric Power Coop Laramie River Station 570 1981 WY Basin Electric Power Coop Laramie River Station 570 1981 WY PacifiCorp Jim Bridger 584 1979 WY PacifiCorp Wyodak 362 1978 WY PacifiCorp Jim Bridger 577.9 1976 WY PacifiCorp Jim Bridger 577.9 1975 WY PacifiCorp Jim Bridger 577.9 1974 WY PacifiCorp Dave Johnston 360 1972 WY PacifiCorp Naughton 326.4 1971 WY PacifiCorp Naughton 217.6 1968 WY PacifiCorp Dave Johnston 229.5 1964 WY PacifiCorp Naughton 163.2 1963 WY PacifiCorp Dave Johnston 113.6 1961 WY PacifiCorp Dave Johnston 113.6 1959

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Appendix B: Coal Power Stations in Canada by Province, Station Name, First Unit Commissioned Date, Age and Installed Capacity, 2011167

Age of Station in Province Station First Unit Commissioned 2011 MW ON Atikokan Generating Station 1985 26 211 AB Battle River Generating Station 1956 55 670 NB Belledune Generating Station 1993 18 450 MB Brandon Generating Station 1958 53 105 SK Boundary Dam Power Station 1959 52 814 AB Genesee Generating Station 1989 22 1,315 AB Keephills Generating Station 1983 28 1,262 ON Lambton Generating Station 1969 42 988 NS Lingan Generating Station 1979 32 614 AB H.R. Milner Generating Station 1972 39 144 ON Nanticoke Generating Station 1972 39 2,660 NS Point Aconi Generating Station 1994 17 176 NS Point Tupper Generating Station 1973 38 151 SK Poplar River Power Station 1981 30 572 AB Sheerness Generating Station 1986 25 760 AB Sundance Power Station 1970 41 1,564 SK Shand Power Station 1992 19 279 ON Thunder Bay Generating Station 1963 48 306 NS Trenton Generating Station 1969 42 310 Average Age 35 13,351

167 “Clean Coal: A compendium of Canada’s Participation”, NRCAN, 2007, http://www.nrcan.gc.ca/com/resoress/publications/ carbone/coalcarbon-eng.pdf?PHPSESSID=c3eac71055856ac30ae7c43ba69e01a4 & various company websites

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