World Nuclear Industry
Status Report 2013by Mycle Schneider

		 Antony Froggattwith Komei Hosokawa

		 Steve Thomas
		 Yukio Yamaguchi
		 Julie Hazemannforeword Peter Bradford

A Mycle Schneider Consulting ProjectWith the support ofParis, London, Kyoto, July 2013
Artwork Anna Jeretic

Fred & Alice Stanback

The World Nuclear Industry Status Report 2013
By

Mycle Schneider
Independent Consultant, Paris, France
Project Coordinator and Lead Author

Antony Froggatt
Independent Consultant, London, U.K.
Lead Author

With

Komei Hosokawa
Professor for Environmental and Social Research, Kyoto Seika University, Japan
Contributing Author

Steve Thomas
Professor for Energy Policy, Greenwich University, U.K.
Contributing Author

Yukio Yamaguchi
Co-director of the Citizen's Nuclear Information Center (CNIC), Tokyo, Japan
Contributing Author

Julie Hazemann
Director of EnerWebWatch, Paris, France
Documentary Research, Modeling and Graphic Design

Foreword by Peter A. Bradford

Paris, London, July 2013
A
Mycle Schneider Consulting
Project

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Acknowledgments
The project coordinator wishes to thank in particular his colleague, fellow lead author and friend
Antony Froggatt for his constant support and extraordinary reliability in this project, and his coauthors Steve Thomas, Komei Hosokawa and Yukio Yamaguchi for their creative special
contributions to this report. A big thank you to Peter A. Bradford for his thoughtful foreword.
The authors wish to thank Fred & Alice Stanback, Amory B. Lovins, Rocky Mountain Institute,
Rebecca Harms, the Greens-EFA Group in the European Parliament, Arne Jungjohann, Rebecca
Bertram, Heinrich Böll Foundation U.S., Sabine von Stockar, the Swiss Renewable Energy
Foundation for their generous support for this project.
A big thank you to John Corbett for his extensive research assistance on finances and to Philippe
Rivière for his creative work on the website and his generous assistance at any time of the day.
The report has greatly benefitted from partial or full proof-reading, editing suggestions andcomments by Aileen Smith, Amory B. Lovins, Miles Goldstick, MV Ramana and Shaun Burnie.
Thank you all.
Special thanks to Anna Jeretic for making available the beautiful artwork and to Adélaïde DuboisTaine for designing the cover page.
Note
This report contains a very large amount of factual and numerical data. While we do our utmost toverify and double-check, nobody is perfect. The authors are always grateful for corrections andsuggestions of improvement.
Lead Authors’ Contacts
Mycle Schneider
45, allée des deux cèdres
91210 Draveil (Paris)
FrancePhone: +33-1-69 83 23 79
Email: mycle@orange.fr

Antony Froggatt
53a Nevill Road
London N16 8SW
United Kingdom
Ph: +44-79 68 80 52 99
E: a.froggatt@btinternet.com

	
  
	
  
	
  

The World Nuclear Industry Status Report 2013
© Mycle Schneider Consulting

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Table of Contents
Foreword .............................................................................................................................................. 4	
  Executive Summary and Conclusions ............................................................................................... 6	  Introduction ....................................................................................................................................... 10	
  General Overview Worldwide .......................................................................................................... 11	  Potential Newcomer Countries ......................................................................................................... 25	
  Construction Times ........................................................................................................................... 33	
  Construction Times of Past and Currently Operating Reactors ......................................................................33	
  Construction Times and Costs of Reactors Currently Under Construction ....................................................34	
  The Economics of Nuclear Power – An Update .............................................................................. 34	
  Introduction ......................................................................................................................................................34	
  The Characteristics of Nuclear Economics ......................................................................................................35	
  The U.S. Nuclear Power Program ...................................................................................................................37	
  The U.K. Nuclear Program ..............................................................................................................................41	
  European Union Policy ....................................................................................................................................45	
  The Chinese Program.......................................................................................................................................46	
  Olkiluoto and Flamanville ...............................................................................................................................48	
  Conclusions on Nuclear Economics ................................................................................................................51	
  Financial Markets and Nuclear Power ............................................................................................ 52	  Fukushima – A Status Report .......................................................................................................... 61	
  Characteristics of the Fukushima Disaster.......................................................................................................61	  Off-site Challenges: Evacuation, Decontamination.........................................................................................62	
  Current Status of Fukushima Daiichi 1–4........................................................................................................64	
  Wave or Shake? ...............................................................................................................................................66	
  On-site Challenges: Water, Waste, Radiation .................................................................................................68	
  Summary and Prospects ...................................................................................................................................71	
  Nuclear Power vs. Renewable Energy ............................................................................................. 73	
  Investment ........................................................................................................................................................73	
  Installed Capacity ............................................................................................................................................75	
  Electricity Generation ......................................................................................................................................76	
  Annexes ............................................................................................................................................... 84	  Annex 1. Overview by Region and Country ................................................................................... 85	
  Africa ...............................................................................................................................................................85	
  The Americas ...................................................................................................................................................87	
  Asia ..................................................................................................................................................................94	
  European Union (EU27) and Switzerland .....................................................................................................106	
  Former Soviet Union .....................................................................................................................................122	
  Annex 2: Reactor Construction Times 2003-2013 ........................................................................ 127	  Annex 3: Definition of Credit Rating by the Main Agencies ....................................................... 128	  Annex 4: About the Authors ........................................................................................................... 129	  Annex 5: Abbreviations .................................................................................................................. 131	  Annex 6. Status of Nuclear Power in the World (1 July 2013) .................................................... 135	  Annex 7. Nuclear Reactors in the World Listed as “Under Construction” (1 July 2013) ......... 136	
  
	
  
	
  

	
  

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ForewordBy	
  Peter	
  A.	
  Bradford*	
  Nuclear power requires obedience, not transparency. The gap between nuclear rhetoric and nuclear
reality has been a fundamental impediment to wise energy policy decisions for half a century now.
For various reasons in many nations, the nuclear industry cannot tell the truth about its progress, its
promise or its perils. Its backers in government and in academia do no better.
Rhetorical excess from opponents of nuclear power contributes to the fog, but proponents have by
far the heavier artillery. During the rise and fall of the bubble formerly known as “the nuclear
renaissance” in the U.S. many of their tools have been on full display.
Academic and governmental studies a decade ago understated the likely cost of new reactors andoverstated their potential contribution to fighting climate change. By 2006 a few U.S. statelegislatures had been enticed to expose utility customers to all the risks of building new reactors.
Industry-sponsored conferences persuaded businesses and newspapers of an imminent jobs bonanza,
ignoring job losses resulting from high electric rates and passing up cheaper, more labor intensivealternatives. These local groups added to the pressure on Congress for more subsidies.
France and Japan were held out as examples of countries that had avoided the timidity andoverregulation that had stalled nuclear construction in the U.S. Indeed, it was argued, these nations
had even solved the waste problem through their commitment to reprocessing spent fuel.
At times inconsistent tales were told simultaneously. Thus the U.S. Congress was told that the newlicensing process and the new generic designs were so untried and environmental opposition so
formidable that loan guarantees were needed to lay the risks off on taxpayers. At the same time WallStreet and state legislatures were assured that these new features had chloroformed public oppositionand otherwise laid to rest the terrifying industry ghosts embodied by the nine figure dollar losses at
Shoreham, Seabrook, WPPSS, and Midland, sites that resonate in U.S. nuclear folklore like Civil
War battlefield names.
The renaissance story line was hard to resist. By early 2009, applications for 31 new reactors werepending at the U.S. Nuclear Regulatory Commission. The promises came garnished with tales ofremorseful changes of heart from oft-obscure nuclear converts. With few exceptions, the news media- especially television with its thirst for the short and the simple - fell for the renaissance story line.
It is all in ruins now. The 31 proposed reactors are down to four actually being built and a few others
lingering on in search of a license, which is good for 20 years. Those four are hopelessly uneconomic
but proceed because their state legislatures have committed to finish them as long as a dollar remains
to be taken from any electric customer’s pocket. Operating reactors are being closed as uneconomic
for the first time in fifteen years.
Still the band plays on. President Obama recently touted new reactors as part of his “all of the above”
policy on climate change. But is “all of the above” really a policy? Do we build palaces to avert
housing shortages? Don’t we instead prioritize, based on the best information available? U.S.
secretaries of energy enthuse that the four new reactors will be completed “on time and on budget”,
never mind that they are already behind and over and that “on budget” will mean “well above thecost of creating equivalent low carbon energy more sensibly”.
As always in the face of failure, the industry puts forth new designs as a basis for new promises, now
touting small modular reactors with the same fervor that it touted large partially modular reactors a
decade ago. Congress finds a few hundred million to preserve these dreams even as its cutbacks
shatter so many others.
––––––––––––––––––––––––––––––––*Adjunct Professor, Vermont Law School, teaching "Nuclear Power and Public Policy", former
commissioner U.S. Nuclear Regulatory Commission (NRC), former chair of the New York andMaine Utility Regulatory Commissions.
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A new movie, Pandora’s Promise (no filmmaker familiar with nuclear history would include“promise” in a title intended to be pronuclear1), recently screened at Sundance.
Featuring the same old converts and straw men, it opened in theaters a few weeks ago to tiny
audiences and generally unenthusiastic reviews, especially from reviewers knowledgeable about
nuclear power2.
In the astonishing persistence of the global appetite for false nuclear promises lies the criticalimportance of the World Nuclear Industry Status Report.
The Report sets forth in painstaking detail the actual experience and achievements of nuclear energy
around the world. It is based for the most part on generally accepted data distinctively graphed forclearer understanding. Where the authors introduce judgment, they explain what they have done andwhy. The Report has a track record stretching back years. It is much better than the embarrassing
exuberances of the International Atomic Energy Agency, the World Nuclear Association or the
pronouncements of most national governments. If more journalists would use it for reference, theirreaders would be spared much of the foolishness that they must now consume.
Most of the myths on which the purported nuclear renaissance rested founder on the rocks of theinformation presented here.
Is new nuclear power cheaper than alternative ways of meeting energy needs? Of course not. Whatabout low carbon “baseload” alternatives? See page 73ff. Can a country grow its economy bybuilding nuclear reactors? What don’t you understand about the employment consequences of
imposing rate shock on industrial and commercial customers? Are the consequences of the
Fukushima meltowns really being overstated by antinuclear activists? Maybe, but see the chapter on
the status of Fukushima.
In short, the nuclear renaissance –whatever it may be called throughout the world - has always
consisted entirely of the number of reactors whose excess costs governments were prepared to makemandatory for either customers or taxpayers. Investor capital cannot be conscripted. Investors of thesort that nuclear power must attract study risks carefully. They know the information in this report,
and so should everyone else with responsibility for energy decisions that allocate nuclear risk.
	
  

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

1

A more accurate use of the word is in M.V. Ramana’s aptly titled and excellent history of India’s nuclear
follies, The Power of Promise (Penguin Viking, 2012).
2
For an insightful example, see Victor Gilinsky and Henry Sokolski, “Pandora’s Promise: Is the Issue Really
Environmental”, Nuclear Intelligence Weekly, June 21, 2013,
http://www.npolicy.org/article.php?aid=1219&rtid=1.
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Executive Summary and Conclusions
Two years after the Fukushima disaster started unfolding on 11 March 2011, its impact on the global
nuclear industry has become increasingly visible. Global electricity generation from nuclear plants
dropped by a historic 7 percent in 2012, adding to the record drop of 4 percent in 2011. This World
Nuclear Industry Status Report 2013 (WNISR) provides a global overview of the history, the current
status and the trends of nuclear power programs worldwide. It looks at nuclear reactor units inoperation and under construction. Annex 1 provides 40 pages of detailed country-by-country
information. A specific chapter assesses the situation in potential newcomer countries. For thesecond time, the report looks at the credit-rating performance of some of the major nuclear
companies and utilities. A more detailed chapter on the development patterns of renewable energies
versus nuclear power is also included. Annex 6 provides an overview table with key data on theworld nuclear industry by country.
The 2013 edition of the World Nuclear Industry Status Report also includes an update on nuclear
economics as well as an overview of the status, on-site and off-site, of the challenges triggered by the
Fukushima disaster. However, this report’s emphasis on recent post-Fukushima developments should
not obscure an important fact: as previous editions (see www.WorldNuclearReport.org) detail, theworld nuclear industry already faced daunting challenges long before Fukushima, just as the U.S.
nuclear power industry had largely collapsed before the 1979 Three Mile Island accident3. The
nuclear promoters’ invention that a global nuclear renaissance was flourishing until 3/114 is equallyfalse: Fukushima only added to already grave problems, starting with poor economics.
The performance of the nuclear industry over the year from July 2012 to July 2013 can be summed
up as follows:

Operation and Construction Data (1 July 2013)5
Operation. There are 31 countries operating nuclear power plants in the world.6 A total of
427 reactors have a combined installed capacity of 364 GWe7. These figures assume the final
shutdown of the ten reactors at Fukushima-Daiichi and -Daini. It should be noted that as of
1 July 2013 only two (Ohi-3 and -4) of the 44 remaining Japanese reactors are operating andtheir future is highly uncertain. In fact, even if four utilities are expected to submit restart
requests in July 2013, many observers believe that a large share of the suspended Japaneseunits will likely never restart.
The nuclear industry is in decline: The 427 operating reactors are 17 lower than the peak inin 2002, while, the total installed capacity peaked in 2010 at 375 GWe before declining to
the current level, which was last seen a decade ago. Annual nuclear electricity generation
reached a maximum in 2006 at 2,660 TWh, then dropped to 2,346 TWh in 2012 (down7 percent compared to 2011, down 12 percent from 2006). About three-quarters of thisdecline is due to the situation in Japan8, but 16 other countries, including the top five nuclear
generators, decreased their nuclear generation too.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

3

See Nathan Hultman, Jonathan Koomey, “Three Mile Island: The driver of US nuclear power’s decline”,
Bulletin of the Atomic Scientists, May-June 2013, see http://bos.sagepub.com/content/69/3/63, accessed
7 July 2013.
4
3/11 refers to the triple disaster earthquake-tsunami-nuclear accident on 11 March 2011.
5
See Annex 7 for a country-by-country overview of reactors in operation and under construction as well as thenuclear share in electricity generation and primary energy.
6Unless otherwise noted, the figures indicated are as of 1 July 2013.
7
All figures are given for nominal net electricity generating capacity. GW stands for gigawatt or thousand
megawatt.
8
The continuing debacle of the Japanese reactors led to the provisional categorization as “in long-term
shutdown”, see main text for details.
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The nuclear share in the world’s power generation declined steadily from a historic peak of
17 percent in 1993 to about 10 percent in 2012. Nuclear power’s share of global commercial
primary energy production plunged to 4.5 percent, a level last seen in 1984.9 Only one
country, the Czech Republic, reached its record nuclear contribution to the electricity mix in
2012.
Age. In the absence of major new-build programs, the unit-weighted average age of the world
nuclear reactor fleet continues to increase and in mid-2013 stands at 28 years. Over 190 units(45 percent of total) have operated for 30 years of which 44 have run for 40 years or more.
Construction. Fourteen countries are currently building nuclear power plants, one more than ayear ago as the United Arab Emirates (UAE) started construction at Barrakah. The UAE isthe first new country in 27 years to have started building a commercial nuclear power plant.
As of July 2013, 66 reactors are under construction (7 more than in July 2012) with a total
capacity of 63 GW. The average construction time of the units under construction, as of theend of 2012, is 8 years. However:• Nine reactors have been listed as “under construction” for more than 20 years and four
additional reactors have been listed for 10 years or more.
• Forty-five projects do not have an official planned start-up date on the International Atomic
Energy Agency’s (IAEA) database.
• At least 23 have encountered construction delays, most of them multi-year. For theremaining 43 reactor units, either construction began within the past five years or they have
not yet reached projected start-up dates, making it difficult or impossible to assess whether
they are on schedule or not.
• Two-thirds (44) of the units under construction are located in three countries: China, India
and Russia.

The average construction time of the 34 units that started up in the world between 2003 andJuly 2013 was 9.4 years.

Reactor Status and Nuclear Programs• Startups and Shutdowns. Only three reactors started up in 2012, while six were shut down10
and in 2013 up to 1 July, only one started up, while four shutdown decisions—all in the
U.S.—were taken in the first half of 2013.11 Three of those four units faced costly repairs,
but one, Kewaunee, Wisconsin, was running well and had received a license renewal justtwo years ago to operate up to a total of 60 years; it simply became uneconomic to run. As of
1 July 2013, there were only two reactors operating in Japan and how many others will
receive permission to restart and over what timeframe remains highly uncertain.
• Newcomer Program Delays. Engagement in nuclear programs has been delayed by most of
the potential newcomer countries, including Bangladesh, Belarus, Jordan, Lithuania, Poland,
Saudi Arabia and Vietnam.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

9

According to BP, “Statistical Review of World Energy”, June 2013.
Shutdown is defined as definitively taken off the grid. The shutdown date is the last day when the reactor
generated electricity.
11
The operator decided in June 2013 to shut down the two San Onofre units in California. However, they havenot generated electricity for over a year. So in the WNISR database the units have been withdrawn for the year
2012 rather than 2013.
10

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Construction & New Build Issues• Construction Cancellation. In Russia, one reactor, which had just started construction in 2012
(Baltic-1), was abandoned in May 2013.
• Construction Starts. In 2012, construction began on six reactors and on three so far in 2013,
including on two units in the U.S. for the first time in three and a half decades. Those twounits have been offered over $8 billion in federal loan guarantees and other subsidies whose
total rivals their construction cost, and special laws have transferred financial risks to thetaxpayers and customers.
• Certification Delays. The certification of new reactor designs has continued to be delayed, in
the U.S. certification of the Franco-German-designed EPR12 was pushed back again, thistime to 2015. Only the Westinghouse AP1000 has received full generic design approval in
the U.S.
• Construction Start Delays. In various countries firmly planned construction starts were
delayed, most notably in China, where for almost two years, between December 2010 andNovember 2012, not a single new reactor building site was opened. Furthermore, in the firsthalf of 2013 it did not start any further constructions.

Economics & Finances• Capital Cost Increases. Construction costs are a key determinant of the final nuclear
electricity generating costs and many projects are significantly over budget. Cost estimateshave increased in the past decade from $1,000 to $7,000 per kW installed. The U.S. Vogtle
project, now officially under construction, is built by the same firm whose two previous
reactors at that site were originally budgeted at $660 million and were later estimated to havecost $9 billion.
• State Aid. The U.K. model of Contract for Difference (CFD), a kind of feed-in tariff agreement
for nuclear electricity that is aimed at providing a subsidy scheme for new-build, in the viewof many observers, is likely to violate current EU competition rules.
• Operating Cost Increases. In some countries, especially the U.S. illustrated by the Kewaunee
case, historically low inflation-adjusted operating costs—especially for major repairs—haveescalated so rapidly that the average reactor’s operating costs is barely below the normalband of wholesale power prices.
• Post-Fukushima Costs. Additional costs arising from upgrading and backfitting measures
following the lessons of the Fukushima crisis are only beginning to surface. They are likely
to have substantial impact on investment as well as operational costs.
• Income and Debt. Nine out of 14 major utilities assessed saw their earnings decline over the
past five years while 13 constantly increased their debt level.
• Credit Rating. Over the past five years, of 15 assessed nuclear utilities, 10 were downgradedby credit rating agency Standard and Poor’s, four companies remained stable, while only one
was upgraded over the same period. Rating agencies consider nuclear investment risky andthe abandoning of nuclear projects explicitly “credit positive”.
• Share Value. The share value of the world’s largest nuclear operator, French state utility EDF,
went down by 85 percent over the past five years, while the share price of the world’s largest
nuclear builder, French state company AREVA, dropped by up to 88 percent.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

12

European Pressurized Water Reactor (in Europe) or Evolutionary Pressurized Water Reactor (in the U.S. andelsewhere).
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Fukushima Status Report
This assessment includes analyses of on-site and off-site challenges that have arisen from the 3/11
disaster. To what extent the disaster was triggered by the earthquake or the tsunami or by both incombination cannot yet be conclusively elucidated.
• On-site Challenges. Radiation readings inside the reactor buildings of units 1–3 vary between
5 mSv/h and 73 Sv/h13, which makes human intervention almost impossible. Massive amounts ofwater, about 360 tons per day, are still pumped into the destroyed reactors via makeshift vinyl tubes
that frequently leak. This water, together with a similar additional amount of groundwater, seeps into
the basements of the reactor buildings, some of it decontaminated to some degree and re-injected.
The amount of radioactive water that cannot be re-used is constantly increasing and has reached
380,000 tons in precarious storage of which 90,000 tons in the basements. It is estimated that27 times the amount of cesium-137 released into the air in the first three weeks or more than
2.5 times the total amount released at the Chernobyl accident is contained in this water.
• Off-site Challenges. More than 150,000 people remain in forced evacuation. About 130,000
compensation claims have been filed. A total of 101 municipalities in 8 prefectures were designatedas a “Scheduled Contamination Survey Zone”, where annual doses between 1 and 20 mSv are
predicted and local authorities are responsible for decontamination work. In addition, the central
government is in charge of decontamination efforts in 11 municipalities in Fukushima Prefecture
covering 235 km2, where annual doses exceed 20 mSv. Less than 5 percent of the surface has seen
any decontamination efforts.
The worst-case scenario, as depicted by the Chairman of the Japan Atomic Energy Commission in
the middle of the crisis in March 2011, remains the collapse of the spent fuel pool of unit 414 and asubsequent fuel fire, potentially requiring evacuation of up to 10 million people in a 250 km radiusof Fukushima, including a significant part of Tokyo.

Nuclear Power vs. Renewable Energy Deployment
In spite of a slight decrease in global investment in 2012, partly reflecting rapidly falling equipment
prices, renewable energy development continues its rapid expansion in both, capacity and generation.
China, Germany and Japan, three of the world’s four largest economies, as well as India, now
generate more power from renewables than from nuclear power.
• Investment. Global investment in renewable energy totaled $268 billion15 in 2012, down from$300 billion the previous year16 but still five times the 2004 amount. China increased spendingby 20 percent to $65 billion and was by far the largest investor. While some big investors (U.S.,
Germany, Italy) reduced their spending considerably, some smaller players boosted theirinvestments and reached the top ten, including South Africa, which skyrocketed spending by afactor of 200 to reach $5.5 billion, and Japan, which added 75 percent to reach $16 billion.
• Installed Capacity. Globally, since 2000, the annual growth rates for onshore wind power haveaveraged 27 percent and for solar photovoltaics 42 percent. This has resulted in 2012 in 45 GW
of wind and 32 GW of solar being installed, compared to a net addition of 1.2 GW of nuclear.
China has a total of 75 GW of operating wind power capacity, roughly doubled in each of thepast five years.
• Electricity Generation. In 2012 wind produced almost 500 TWh and solar power about 100 TWh
more than in 2000, while nuclear power generated 100 TWh less. For the first time in 2012
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
13

Without massive radiation protection a lethal dose would be reached within minutes.
Pools are above the reactor vessels between the 4th and the 5th floor. The pool of unit 4 contains as much fuelas the 3 others combined.
15
Does not include any investments in large hydropower projects, but a very small percentage on Carbon
Capture and Storage (CCS).
16
The figure had been corrected upwards from $260 billion after publication of WNISR 2012.
14

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China and India generated more power from wind than from nuclear plants, while in China solar
electricity generation grew by 400 percent in one year.

Introduction
On 29 June 2013, the Director General of the International Atomic Energy Agency (IAEA) declaredat the Ministerial Conference in St. Petersburg, Russia that “nuclear power will make a significant
and growing contribution to sustainable development in the coming decades”. 17 The future will showwhether or not nuclear power will play an increasing role. In the meantime, the World Nuclear
Industry Status Report 2013 (WNISR) provides a reality check of the current situation and trends ofan industry that in the past has rarely been able to fulfill its own promises. The 2012 edition of the
WNISR demonstrated that the IAEA consistently overestimated the development of nuclear power inthe world18, a side-effect of “the leading role of the IAEA in promoting peaceful uses of nuclear
energy”.19
Contrary to the IAEA’s hopes for the future, this edition of the WNISR shows that nuclear power
generation experienced a drop of 7 percent in 2012, larger even than the previous year’s record
4 percent decline. As in previous editions, this report provides many diverse health indicators of thenuclear industry, including numbers of reactors operating, under construction, installed capacities,
and extensive country-by-country assessments of nuclear programs around the world. As in the past
two editions, a chapter is included that compares certain trends in the nuclear industry with
developments in the renewable energy industry.
A greatly extended economic chapter provides data on key strategic markets, especially the U.S. andthe U.K., and financial indicators (e.g. share value and credit-rating developments). Professor SteveThomas once again shares his insights in this area.
In addition, now more than two years after the Fukushima disaster started unfolding, also included isa concise overview of the key issues that continue to raise serious concerns among international
experts and the Japanese population. Two independent Japanese experts, Professor Komei Hosokawa
from Kyoto and Professor Yukio Yamaguchi from Tokyo have contributed their analysis.
The World Nuclear Industry Status Report has turned into a major international reference on nuclear
issues. Over the past year, numerous mainstream publications20 use the WNISR as their information
source for analysis and/or as statistical reference for graphic work, rather than solely relying on
IAEA or World Nuclear Association (WNA) data.
The international team that has collaborated to make this project work sincerely hopes that the
WNISR 2013 will meet the increasingly high expectations.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

17

International Ministerial Conference, “Nuclear Power in the 21st Century”, St. Petersburg, 27-29 June 2013,
Concluding Statement by the President of the Conference, see
http://www.iaea.org/newscenter/statements/stpclosing.pdf, accessed 30 June 2013.
18“Unrealistic Projections”, in Mycle Schneider et al., “World Nuclear Industry Status Report 2012”, see
http://www.worldnuclearreport.org/The-World-Nuclear-Industry-Status.html#unpro.
19International Ministerial Conference, op.cit.
20
For a selection of media citations, see http://www.worldnuclearreport.org/-In-the-media-.html.
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General Overview Worldwide
I would like to begin by congratulating the Kingdom of Swaziland
on becoming the 159th Member State of the IAEA.
Yukiya Amano
IAEA, Director General
Introductory Statement to Board of Governors
4 March 2013

As of the middle of 2013, a total of 31 countries were operating nuclear fission reactors for energy
purposes. Nuclear power plants generated 2,346 terawatt-hours (TWh or billion kilowatt-hours) ofelectricity in 201221, less than in 1999 and a 172 TWh or 6.8 percent decrease compared to 2011 as
well as 11.8 percent below the historic maximum nuclear generation in 2006. The maximum
contribution of nuclear power to commercial electricity generation worldwide was reached in 1993
with 17 percent (see figure 1). It has dropped to 10.4 percent in 2012, a level last seen in the 1980s.
According to BP, the nuclear share in commercial primary energy consumption dropped to
4.5 percent, “the lowest since 1984”.22
Figure 1: Nuclear Electricity Generation in the World

Source : IAEA-PRIS, BP, MSC, 2013	  About three-quarters of the decrease is due to the continuing and substantial generation drop in Japan(–139 TWh or –50 percent over the previous year), which in three years fell back from the 3rd to the18th position of nuclear generators. Production also decreased for differing reasons in all top fivenuclear generating countries: United States (–20 TWh or –2.5 percent), France (–16 TWh/–4 percent),
Germany (–8 TWh/–10 percent), South Korea (–7 TWh/5 percent) and Russia with an insignificant
drop (–0.8 TWh/–0.5 percent).

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

21

If not otherwise noted, all nuclear capacity and electricity generation figures based on International Atomic
Energy Agency (IAEA), Power Reactor Information System (PRIS) online database,www.iaea.org/programmes/a2/index.html.
22BP, “Statistical Review of World Energy”, June 2013.
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Nuclear generation declined in a total of 17 countries, while in 14 countries it increased or remained
stable23. Seven countries24 generated their historic maximum in 2012.
Figure 2. Nuclear Power Generation by Country, 2012/2011 and Historic Maximum

Sources: IAEA-PRIS, MSC, 2013

The “big five” nuclear generating countries—by rank: the United States, France, Russia, South Korea
and Germany—generated 67 percent of all nuclear electricity in the world. The three countries thathave phased out nuclear power (Italy, Kazakhstan, Lithuania), and Armenia, generated their historicmaximum of nuclear electricity in the 1980s. Several other countries’ nuclear power generation
peaked in the 1990s, among them Belgium, Canada, Japan, and the U.K. A further six countries
peaked their nuclear generation between 2001 and 2005: Bulgaria, France, Germany, South Africa,
Spain, and Sweden. Among the countries with a steady increase in nuclear generation are China, theCzech Republic and Russia. However, even where countries are increasing their nuclear electricity
production this is in most cases not keeping pace with overall increases in electricity demand leading
to a reduced and declining role for nuclear power.
Only one country in the world, the Czech Republic, peaked its nuclear share in 2012 with 35 percent.
In fact, all other countries—except Iran, which started up its first nuclear plant in 2011—reached theirmaximum share of nuclear power prior to 2010. While three countries peaked in 2008 (China) or 2009
(Romania, Russia), the other 26 countries saw their largest nuclear share by 2005. In total, nuclear
power played its largest role in ten countries during the 1980s25, in 12 countries each in the 1990s andin the 2000s.
Increases in nuclear generation are mostly a result of higher productivity and uprating26 at existing
plants rather than due to new reactors. According to the latest assessment by Nuclear Engineering
International27, the global annual load factor28 of nuclear power plants decreased from 77 percent in
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

23

Less than 1 TWh variation from the previous year
Brazil, China, Czech Republic, Hungary, India, Iran, Pakistan
25
Armenia, Hungary, India, Germany, Italy, Netherlands, South Africa, South Korea, Spain, Taiwan.
26
Increasing the capacity of nuclear reactors by equipment upgrades e.g. more powerful steam generators or
turbines.
27
Nuclear Engineering International, “Load Factors to end December 2012”, May 2013.
24

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World Nuclear Industry Status Report 2013

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201129 to 70 percent in 2012. Not surprisingly the biggest change was seen in Japan, where the loadfactor plunged from 69.5 percent in 2010 to 39.5 percent in 2011 to 3.7 percent in 2012. This is also
due to the fact that officially 50 of the 54 pre-3/11 units in Japan are still counted as operational—eventhough some reactors have not generated electricity for years (see box hereunder).
Figure 3. Nuclear Share in Electricity Mix by Country, 2012/2011 and Historic Maximum

Sources: IAEA-PRIS, MSC, 2013

Although both countries decreased performance, as in 2011, Romania and Taiwan had the highest loadfactors in 2012 with 92.8 and 90.8 percent respectively. The most dramatic reductions in load factor
outside Japan were in Belgium (–11.8 percentage points), Mexico (–20 percentage points) and South
Korea (–9.5 percentage points). Belgium had two of its seven reactors off-line for much of the year
because of thousands of cracks discovered in their pressure vessels. They only restarted in June 2013.
Mexico is carrying out major uprating work on both of its units. South Korea had a series of scandals
involving quality control issues that kept a number of units down. Other major nuclear countries saw
their load factors deteriorate to some degree: the U.S. by 3.1 percentage points to reach 83.2 percent,France by 2.3 percentage points, now down to 73.6 percent and remaining at the lower end of global
performance.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
28

Nuclear Engineering International load factor definition: “Annual load factors are calculated by dividing thegross generation of a reactor in a one-year period by the gross capacity of the reactor (sometimes called output),as originally designed, multiplied by the number of hours in the calendar year. The figures are expressed aspercentages. Where a plant is uprated, the revised capacity is used from the date of the uprating.”
29
NEI revised the 2011 figure from 76 to 77 percent.
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World Nuclear Industry Status Report 2013

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Japanese Reactors “in Operation” or “in Long-Term Shutdown”?
In an unprecedented move, on 16 January 2013, the IAEA shifted 47 Japanese nuclear reactors from the category“In Operation” to the category “Long-term Shutdown” (LTS) in its web-based Power Reactor Information
System (PRIS)30. The number of nuclear reactors listed as “In Operation” in the world thus dropped to 390, alevel last seen in 1986, the year of the Chernobyl accident. The move was a dramatic step by the IAEA in its
official statistics by acknowledging the the current industrial reality in Japan. Coming from the IAEA this waswithout doubt a unique revision of world operational nuclear data.
Screen Capture 1 : The IAEA’s Online Database on Nuclear Power Reactors on 16 January 2013

Note: Yellow highlighting added.

Source: IAEA, 2013, see http://www.iaea.org/pris/

Screen Capture 2 : The IAEA’s Online Database on Nuclear Power Reactors on 19 January 2013

Note: Yellow highlighting added.

Source: IAEA, 2013, see http://www.iaea.org/pris/This historic revision however, did not last. Only two days later, the Japanese government requested
the reversal of the reactor status of the 47 Japanese reactors from the IAEA’s LTS category to “Inoperation”. The modification was thus reversed on 18 January and commented on by the IAEA in apress release on 19 January 2013.31
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
30
31

See http://www.iaea.org/pris/.
IAEA, “Japan corrects error in IAEA nuclear power database”, press release, 19 January 2013,

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An IAEA representative explained by email: “In communication with the Government of Japan, it was identified
that this status is not applicable for [the] time being and our Japanese counterpart changed the decision and thestatus was put back.”32 Another IAEA representative identified the “IAEA counterpart” in a phone interview as
the Japan Nuclear Energy Safety Organization (JNES). This was confirmed in the IAEA press release.
According to the IAEA, JNES, an incorporated Administrative Agency, modified the raw country data in the
online Power Reactor Information System (PRIS) of the IAEA. The modification was then automaticallyintegrated into the World Overview pages of the Agency’s website.
Any correspondent or counterpart to the IAEA’s online database has to be authorized by its respective
government. In addition, it is understood that modifications of the reactor status are controlled by the respective
government. However, it is unclear what happened in this case, as it is hard to believe that such a significant
modification of the reactor status of the Japanese reactor fleet happened at the initiative of an individual at JNES.
If this was indeed the case, the question remains why this was done. The IAEA stated that the Japanesecounterparts advised the Agency that the “changes resulted from a clerical error”.
The explanation given of a “clerical error” is surprising and unconvincing. The reactor-by-reactor changes wereprecise and made perfect sense. In fact, all of the 47 reactors could well fall within the IAEA definition for LTS
status33:
Reactor is considered in long-term shutdown status from the Long-term Shutdown date to the Restart
Date, if it has been shut down for an extended period (usually more than one year) and any of thefollowing conditions has occurred in early period of shutdown:
1. restart is not being aggressively pursued (there is no vigorous onsite activity to restart the unit) or
2. no firm restart date or recovery schedule has been established, but there is the intention to re-start theunit eventually.
This status may be for example due to technical, economical, strategic or political reasons. This status
does not apply to long-term maintenance outages, including unit refurbishment, if the outage schedule isconsistently followed, or to long-term outages due to regulatory restrictions (licence suspension), if restart(licence recovery) term and conditions have been established. Such units are still considered ‘operational’(in a long-term outage).
If an intention not to restart the shutdown unit has been officially announced by the owner, the unit isconsidered ‘permanently shut-down’.
Furthermore, if this incident was due to a simple “clerical error”, why would it take JNES two days to notify the
Agency?
The incident raises the question of the operational rules of the PRIS database. It seems astounding that
representatives of individual governments, utilities, research or safety organizations can actually directly modify
the IAEA’s public website. The IAEA explained that it “runs the PRIS database with input from its Member
States, which own the information provided”. However, as a consequence of the Japan incident, the Agency
decided to change the procedures34:
The Nuclear Energy Department of the IAEA, which runs the PRIS database, is implementing a software
upgrade that in future would prevent status changes being entered into the system without the agreementof the system administrators, and would require clear justification from the national counterparts.
Any outside observer would have expected this to be the rule before the incident. The overall information
management by the IAEA and the Japanese authorities—with very significant changes in reactor statistics, one
way or the other, without any public explanation for three days—puts serious doubts on the reliability of theinformation provided.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
see http://www.iaea.org/press/?p=3250, accessed 30 June 2013.
32
Email to Mycle Schneider, dated 18 January 2013 as a reply to our request from 16 January, prior to therelease of the first story on the issue on www.WorldNuclearReport.org, “Historic Move: IAEA Shifts 47
Japanese Reactors Into ‘Long-Term Shutdown’ Category”, 16 January 2013, see
http://www.worldnuclearreport.org/Historic-Move-IAEA-Shifts-47.html.
33
See IAEA Glossary http://www.iaea.org/pris/Glossary.aspx.
34
IAEA, “Japan corrects error in IAEA nuclear power database”, press release, 19 January 2013, see
http://www.iaea.org/press/?p=3250, accessed 30 June 2013.
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World Nuclear Industry Status Report 2013

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Overview of Operation, Power Generation, Age Distribution
Since the start of the commercial nuclear power age in the mid-1950s there have been two major
waves of grid connections (see Figure 4). A first wave peaked in 1974, with 26 reactor startups in thatyear. The second wave reached a historic maximum in 1984 and 1985, just before the Chernobyl
accident, reaching 33 grid connections in each year. By the end of the 1980s, the uninterrupted net
increase of operating units had ceased, and in 1990 for the first time the number of reactor shutdowns
outweighed the number of startups. The 1992-2001 decade showed twice as many startups than
shutdowns (51/23), while in the past decade 2003-2012 the trend reversed (31/51). Six reactors(including two units at San Onofre, California, that did not generate any power anymore in 2013) wereshut down in 2012, while only three started up. In the first half of 2013, another two units were closed(also in the U.S.), while only one unit started up (in China).
Figure 4. Nuclear Power Reactor Grid Connections and Shutdowns, 1956–2013

Source: IAEA-PRIS, MSC, 2013

As of 1 July 2013, under the Baseline Scenario (see hereunder), a total of 427 nuclear reactors wereconsidered operating in 31 countries, down 17 from the maximum of 444 in 2002. The current worldreactor fleet has a total nominal electric net capacity of about 364 gigawatts (GW or thousand
megawatts). However, there are large uncertainties in these figures, mainly stemming from theundefined future of the 50 Japanese nuclear reactors that are officially still operating but, except for
two units, are all shut down as of 1 July 2013. We have therefore considered three scenarios:• The Baseline Scenario. Only the 10 Fukushima reactors are permanently closed. Many industry
analysts now consider this as unrealistically optimistic. However, it remains unclear, which units willremain closed. Utilities were awaiting the Nuclear Regulatory Authority’s new safety rules that werereleased on 8 July 2013. Four utilities have announced “early applications for restart” for 10 reactors35,
whatever that means in practice.
• The East Coast Scenario. In addition to the Fukushima units, the seven reactors affected directly or
indirectly by 3/11 events remain closed. These include three Onagawa reactors that were closest to the
3/11 epicenter, the three remaining Hamaoka units shut down at the request of former Prime Minister
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

35

JAIF, “Nuclear Power Plants in Japan (in operation and under construction)”, 19 June 2013.

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Naoto Kan because of high earthquake risk estimates and the Tokai reactor, the nuclear plant closest to
the Tokyo Metropolitan area (ca. 100 km). Under this scenario, the total number of operating units inthe world would drop to 420 and the installed capacity to 354 GWe.
• The German Scenario. In addition to the units considered closed under the Baseline and East CoastScenarios the 13 reactors in Japan with an operational age in excess of 30 years will remain shut
down. The German government decided in the wake of 3/11 to permanently shut down the eightreactors down that had operated for over three decades. That would leave Japan with 24 operating
reactors, the worldwide figure would drop to 407, last seen in 1987, and the installed capacity to 349
GWe, not experienced since the mid-1990s.
Figure 5. World Nuclear Reactor Fleet, 1954–2013

Sources: IAEA-PRIS, MSC, 2013

Considering the opposition to nuclear power in Japan, especially by local authorities under the
influence of an increasingly vocal public opinion, against the restart of any nuclear reactor, it ispossible—even under a strongly pro-nuclear central government—that there will be the short-term
closure of the majority of the nuclear program in the country. This would not be a “phase-out”
scenario but rather the simple “abandoning” of nuclear power. Every authorization of restart will be
subject to intense battles between promoters and opponents of the nuclear option. The continuous
instability of the Fukushima site could also lead to further incidents and additional releases of large
amounts of radioactivity, especially following strong aftershocks, of which a substantial risk persists.
Under these circumstances, the scenarios above are likely to prove quite conservative.
The total world installed nuclear capacity has decreased six times since the beginning of thecommercial application of nuclear fission, all in the past 15 years—in 1997, 2003, 2007, 2008, 2009
and 2011. Despite 15 fewer units operating in early 2012 compared to 2002, the generating capacity is
still about identical and as of late June 2013, with two fewer units operating, the installed capacity isidentical to its value a year ago. This is a result of the combined effects of larger units replacing
smaller ones and, mainly, technical alterations at existing plants, a process known as uprating. In the
United States, the Nuclear Regulatory Commission (NRC) has approved 148 uprates since 1977.
These included, in 2012, six uprates between 1.6 percent (Harris 1) and 13.1 percent (Grand Gulf 1).

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The cumulative approved uprates in the United States total 6.9 GW.36 Most of these have already been
implemented. A similar trend of uprates and lifetime extensions of existing reactors can be seen in
Europe. The main incentive for lifetime extensions is their considerable economic advantage over
new-build, but upgrading and extending the operating lives of older reactors have lower safetymargins than replacement with more modern designs.
It appears however that the incentives for power uprates are waning as in 2012 the number of units
with pending applications dropped from 20 in the previous year to 14 and the total capacity increasethat would occur from 1.5 GW to 1 GW. 37 The increasing challenge for existing U.S. reactors tocompete with wholesale market prices set by the operating costs of gas-fired and wind generators led
nuclear giant Exelon to abandon planned uprates for four older units.38
Adding together uprates, new-build capacity, and substracting closures, the capacity of the global
nuclear fleet increased by about 30 GWe between 1992 and 2002 to reach 362 GWe; it peaked in 2010at 375 GWe before falling back to the level achieved a decade ago.
The use of nuclear energy has been limited to a small number of countries, with only 31 countries, or
16 percent of the 193 members of the United Nations, operating nuclear power plants in early 2013(see Figure 2). Half of the world’s nuclear countries are located in the European Union (EU), and in2012 they accounted for 36 percent of the world’s nuclear production. France alone generated about
half (48 percent) of the EU’s nuclear production.

Overview of Current New Build
Currently, 14 countries are building nuclear power plants. With the United Arab Emirates (UAE)
concreting the base-slab for two units at Barakah in July 2012 and May 2013, one country was added
to the list compared to the last edition of the WNISR. Japan halted work at two units following the
3/11 events, Ohma and Shimane-3, which had been under construction since 2007 and 2010
respectively. Officially construction resumed at Ohma on 1 October 2012 and Shimane-3 hasremained “under construction”, according to Japan Atomic Industrial Forum (JAIF) 39 and IAEA
statistics. However, in view of the current situation in Japan, we consider it very unlikely that theseplants will be completed; it will be hard enough for the industry to get its stranded plant restarted.
In the previous WNISR edition, the Russian Kursk-5 unit was removed from the list, following reportsthat the builder, Rosatom, confirmed that the project was abandoned. The unit finally disappeared
from the IAEA’s data base early July 2013. So, as of early July 2013, 66 reactors are defined here as
under construction, seven more than a year ago. However, 28 of these are in China, leaving the total in
the rest of the world being 38. The current number compares with a peak of 234 units in building
progress—totaling more than 200 GW—in 1979. However, many of those projects (48) were neverfinished (see Figure 6.) The year 2004, with 26 units under construction, marked a record low for
construction since the beginning of the nuclear age in the 1950s.
After a near two year freeze on nuclear plant construction following the events of March 2011, whenno new building site was opened, China resumed construction on on 17 November 2012. 40 The World
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

36

Nuclear Regulatory Commission (NRC), “Approved Applications for Power Uprates”, updated 29 March
2012, at www.nrc.gov/reactors/operating/licensing/power-uprates/status-power-apps/approvedapplications.html, accessed on 22 June 2013.
37
Nuclear Regulatory Commission (NRC), “Pending Applications for Power Uprates”, updated 30 April 2012,at www.nrc.gov/reactors/operating/licensing/power-uprates/status-power-apps/pending-applications.html,
accessed on 22 June 2013.
38
Platts, “Exelon cancels power uprates for LaSalle, Limerick nuclear plants”, 12 June 2013, see
http://www.platts.com/latest-news/electric-power/Washington/Exelon-cancels-power-uprates-for-LaSalleLimerick-21152061, accessed 7 July 2013.
39
JAIF, “Nuclear Power Plants in Japan”, 22 May 2013.
40
The previous construction start dated from 31 December 2010.
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Nuclear Association assumes that at least five authorized construction starts did not happen, with atleast another ten in the pipeline for 2011 alone.41

Figure 6. Number of Nuclear Reactors under Construction

Source: IAEA-PRIS, MSC 2013

The total capacity of units now under construction in the world is about 63 GWe, up by about 7 GWe
compared to a year ago, with an average unit size of 960 MW (see Table 1 and Annex 7 for details). A
closer look at currently listed projects illustrates the level of uncertainty associated with reactor
building, especially given that most constructors assume a five-year construction period:•

Nine reactors have been listed as “under construction” for more than 20 years. The U.S. Watts Bar-2
project in Tennessee holds the record, as construction started in December 1972, but was
subsequently frozen. It failed to meet the latest startup date in 2012 and is now scheduled to beconnected to the grid in 2015. Other long-term construction projects include three Russian units,
two Mochovce units in Slovakia, and two Khmelnitski units in Ukraine. The construction of theArgentinian Atucha-2 reactor started 32 years ago.

•

Four reactors have been listed as “under-construction” for over 10 years. These are two Taiwaneseunits at Lungmen for about 14 years and two Indian units at Kudankulam for around 10 years.

•

Forty-five projects do not have an IAEA planned start-up date.

•

At least 23 of the units listed by the IAEA as “under construction” have encountered construction
delays, most of them significant. All of the 43 remaining units were started within the last five
years or have not reached projected start-up dates yet. This makes it difficult to assess whether or
not they are on schedule.

•

Two thirds (44) of the units under construction are located in just three countries: China, India andRussia. Historically, none of these countries have historically been very transparent or reliable
about information on the status of their construction sites. It is nevertheless known that half of theRussian units listed are experiencing multi-year delays (see Annex 7 for details).

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
41

www.world-nuclear.com/info/inf63.html, accessed 3 May 2012.

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Table 1: Nuclear Reactors “Under Construction” (as of 1 July 2013)42
Country
China
RussiaIndia
South Korea
USA
Pakistan
Slovakia
Taiwan
UAE
UkraineArgentina
BrazilFinlandFrance
Total

Units MWe (net) Construction Start
28
27,7902008-2013
97,273
1983-2019
74,824
2002-2011
5
6,320
2008-2013
3
3,399
1972-2013
2
630
2011
2
880
1985
2
2,600
1999
2
2,690
2012-2013
2
1,900
1986-1987
1
692
1981
1
1,245
2010
1
1,600
2005
1
1,600
2007
66

63,4431972-2013

Grid Connection
2013-20172014-20192013-20162013-20172015-20172016-20172014-20152014-20152017-20182015-2016
2013
2016
2016
2016
2013-2019

Source : IAEA-PRIS, MSC, 2013

The lead time for nuclear plants includes not only construction times but also lengthy licensing
procedures in most countries, complex financing negotiations, and site preparation.
Past experience shows that simply having an order for a reactor, or even having a nuclear plant at anadvanced stage of construction, is no guarantee for grid connection and power production. The French
Atomic Energy Commission (CEA) statistics on “cancelled orders” through 2002 indicate
253 cancelled orders in 31 countries, many of them at an advanced construction stage (see also
Figure 6). The United States alone accounted for 138 of these cancellations.43 Many U.S. utilities
incurred significant financial harm because of cancelled reactor-building projects.

Operating Age
In the absence of any significant new-build and grid connection over many years, the average age(since grid connection) of operating nuclear power plants has been increasing steadily and now stands
at about 28 years.44 Some nuclear utilities envisage average reactor lifetimes of beyond 40 years andeven up to 60 years. In the United States, reactors are initially licensed to operate for 40 years. Nuclear
operators can request a license renewal for an additional 20 years from the NRC. As of June 2013,72 of the 100 operating U.S. units have received an extension, and another 18 applications are under
NRC review.45 However, these applications are currently on hold pending completion of a review ofthe management of commercial nuclear reactor spent fuel, with no license extension decision to be
granted until completion of this process.46
Even license renewal does not guarantee longer operating life. None of the 32 units that have been
shut down in the U.S. had reached 40 years on the grid. In other words, at least a quarter of thereactors built in the U.S. never reached their design lifetime. On the other hand, of the 100 currently
operating plants 24 units have operated for 40 years or more.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

42

For further details see Annex 8.
CEA, “Elecnuc – Nuclear Power Plants in the World”, 2002.
44
Here, reactor age is calculated from grid connection to final disconnection from the grid. In this report,“startup” is synonymous with grid connection and “shutdown” with withdrawal from the grid.
45
U.S.NRC, “Status of License Renewal Applications and Industry Activities”, updated 17 June 2013, see
http://www.nrc.gov/reactors/operating/licensing/renewal/applications.html, accessed 23 June 2013.
46
U.S.NRC, “Waste Confidence”, see http://www.nrc.gov/waste/spent-fuel-storage/wcd.html, accessed 10 July
2013.
43

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Many other countries, however, have no time limitations on operating licenses. In France, where thecountry’s first operating PWR started up in 1977, reactors must undergo in-depth inspection andtesting every decade. The French Nuclear Safety Authority (ASN) evaluates on a reactor-by-reactor
basis whether a unit can operate for more than 30 years. At this point, ASN considers the issue of
lifetimes beyond 40 years to be irrelevant, although the French utility EDF has clearly stated that, foreconomic reasons, it plans to prioritize lifetime extension over large-scale new-build. However, only afew plants have so far received a permit to extend their operational life from 30 to 40 years, but only
under the condition of significant upgrading. President François Hollande vowed to close down the
country’s oldest reactors at Fessenheim by the end of 2016 and to engage on a path leading to the
reduction of the nuclear share in power generation from 75 to 50 percent by 2025. These decisions
were confirmed in September 2012 by the Conseil de Politique Nucléaire, the highest nuclear
decision-making body chaired by the President himself.47 However, even if ASN gave the go-ahead
for all of the oldest units to operate for 40 years, 22 of the 58 French operating reactors will reach thatage by 2020.
Figure 7. Age Distribution of Operating Nuclear Reactors, 2013

Sources: IAEA-PRIS, MSC, 2013

In assessing the likelihood of reactors being able to operate for up to 60 years, it is useful to compare
the age distribution of reactors that are currently operating with those that have already shut down (seeFigures 7 and 8). As of mid-2013, 31 of the world’s operating reactors have exceeded the 40-year
mark.48 As the age pyramid illustrates, that number will rapidly increase over the next few years. A
total of 190 units have already reached age 30 or more.
The age structure of the 153 units already shut down confirms the picture. In total, 47 of these units
operated for 30 years or more and of those, 20 reactors operated for 40 years or more (see Figure 8).
The majority of these were Magnox reactors located in the U.K. As they were designed to produce
weapons-grade plutonium, these were all small reactors (50–490 MW) that had operated with very low
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

47

Conseil de Politique Nucléaire, 28 September 2012, press release issued on 15 October 2012, see
http://www.elysee.fr/communiques-de-presse/article/conseil-de-politique-nucleaire/, accessed 23 June 2013.
48
We count the age starting with grid connection, and figures are rounded by half-years.
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burn-up fuel and very low power density (watts of heat per liter of core volume). Therefore there are
significant differences from the large 900 MW or 1,300 MW commercial reactors whose high burn-up
fuel and high power density generate significantly more stress on materials and equipment. Many unitsof the first generation have operated for only a few years. Considering that the average age of the
153 units that have already shut down is about 24 years—with 8 more units shut down over the past
year the figure did not change—plans to extend the operational lifetime of large numbers of units to 40
years and beyond seem rather optimistic.
As a result of the Fukushima nuclear disaster questions have been raised about the wisdom of
operating older reactors. The Fukushima-I units (1 to 4) were connected to the grid between 1971 and1974. The license for unit 1 was extended for another 10 years in February 2011. Four days after theaccidents in Japan, the German government ordered the shutdown of seven reactors that had started up
before 1981. These reactors, together with another unit that was closed at the time, never restarted.
The sole selection criterion was operational age. Other countries did not adopt the same approach, but
it is clear that the 3/11 events had an impact on previously assumed extended lifetimes in othercountries as well, including in Belgium, Switzerland and Taiwan.
Figure 8. Age Distribution of Shutdown Nuclear Reactors, 2013

Sources: IAEA-PRIS, MSC, 2013

For the purposes of capacity projections, in a first scenario (40-Year Lifetime Projection, see
Figure 9), we have assumed a general lifetime of 40 years for worldwide operating reactors, with a
few adjustments, while we take into account already-authorized lifetime extensions in a second
scenario (PLEX Projection). There are several individual cases where continued operation or lifetime
extensions are in question and an official decision to shutdown earlier has been made 49 (seeFigure 10).
The lifetime projections make possible an evaluation of the number of plants that would have to comeon line over the next decades to offset closures and simply maintain the same number of operating
plants. Even with 66 units under construction—as of 1 July 2013, all of which are considered online
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

49

The Japanese reactors constitute the largest contingency of uncertainty. In this scenario all but the
10 Fukushima reactors would return to operation. A highly conservative assumption.
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by 2020—installed nuclear capacity would drop by 25 GW. Therefore in total 55 additional reactors
would have to be finished and started up prior to 2020 in order to maintain the status quo. This
corresponds to between eight and nine new grid connections per year, with an additional 205 units(191 GW) over the following 10-year period—one every 18 days. This compares to 33 gridconnections over the past 10-year period.
Figure 9. The 40-Year Lifetime Projection

Sources: IAEA-PRIS, WNA, MSC 2013

The achievement of the 2020 target appears increasingly unlikely given the existing difficult financial
situation of the world’s main reactor builders and utilities, the general economic crisis and generally
hostile public opinion—aside from any other specific post-Fukushima effects. A notable difference toprevious assessments consists in the assumption that constraints on the manufacturing of key reactor
components is playing a minor role as reactor orders have not been following capacity extensions, inparticular of key component manufacturer Japan Steel Works (JSW).
As a result, the number of reactors in operation will decline over the coming years unless lifetime
extensions beyond 40 years becomes widespread. The scenario of such generalized lifetime extensions
is however even less likely after Fukushima, as many questions regarding safety upgrades,
maintenance costs, and other issues would need to be much more carefully addressed.
Developments in Asia, and particularly in China, do not fundamentally change the global picture.
Reported figures for China’s 2020 target for installed nuclear capacity have fluctuated between 40 GW
and 120 GW in the past. The freeze of construction initiation for almost two years has reduced
Chinese ambitions. While there has been considerable acceleration of construction starts in the past—with 19 new building sites initiated in 2009 and 2010—not a single new construction site was initiatedbetween December 2010 and November 2012, and none was reported in the first half of 2013. In
addition, the average construction time for the 18 operating units in China was 5.8 years. At present,
28 units with about 28 GW are under construction and scheduled to be connected before 2018, which
will bring the total to 42 GW. The prospects for significantly exceeding the original 2008 target of
40 GW for 2020 is unlikely. There are also indications that new reactors will be allowed only incoastal, not inland, sites, restricting the number of suitable sites available.
We have also modeled a scenario in which all currently licensed lifetime extensions and license
renewals (mainly in the United States) are maintained and all construction sites are completed. For all

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other units we have maintained a 40-year lifetime projection, unless a firm earlier or later shutdown
date has been announced. The net number of operating reactors would still decrease by 11 units even if
installed capacity would grow by 11.5 GW in 2020. The overall pattern of the decline would hardly bealtered, it would merely be delayed by some years. (See Figures 10 and 11).
Figure 10. The PLEX Projection

Sources: IAEA-PRIS, US-NRC, WNA, MSC 2013

Figure 11. Forty-Year Lifetime Projection versus PLEX Projection (in numbers of reactors)

Sources: IAEA-PRIS, US-NRC, MSC 2013

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Potential Newcomer Countries
In its International Status and Prospects for Nuclear Power 201250 the IAEA estimates that there are atotal of 29 countries that are described as developing nuclear power programs for the first time. This
includes three countries that have ordered nuclear power plants, 14 countries that are considering
starting a nuclear power program and in which there is a “strong indication of intentions to proceed”,
six countries show “active preparation for a possible nuclear power program” and a further six that are
actively preparing for a possible nuclear power program with no final decision. The total number ofcountries listed as developing nuclear power programs has fallen since the IAEA last published its
assessment in 2010, when there were 33.
According to the IAEA, the three countries that have ordered nuclear power plants are the United ArabEmirates (UAE), Turkey and Belarus. The Agency also states that there are nine countries that havesuggested a start-up date for first power before 2030. The IAEA does not list those countries, but it islikely to include the three in which orders have been placed, plus Bangladesh, Jordan, Lithuania,
Poland, Saudi Arabia and Vietnam. This 2012 analysis from the IAEA is a retreat from its suggestions
earlier in the same year when it stated it expected Vietnam, Bangladesh, United Arab Emirates,
Turkey and Belarus to start building their first nuclear power plants in 2012 and that Jordan and Saudi
Arabia could follow in 2013.51 This prediction seems to be divergent with actual events, with only the
UAE starting construction, one unit each in 2012 and 2013. IAEA Director General Yukiya Amano
reported to his Board of Governors in March 2013: “The UAE is the first new country in 27 years tohave started building a nuclear power plant.”52
Figure 12 illustrates the history of national nuclear programs with the startup of the first and shutdownof the last reactor per country.
Figure 12. Start-ups and Closures of National Nuclear Power Programs, 1950–2013

Sources: IAEA-PRIS 2013, MSC, 2013

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
50

IAEA “International Status and Prospects for Nuclear Power 2012”, International Atomic Energy Agency,
Report by the Director General, 15 August 2012.
51
Enformable.com, “IAEA – Vietnam and 4 other countries to incorporate nuclear energy after Fukushima”,
Lucas W Hixson, 24 February 2012, http://enformable.com/2012/02/iaea-vietnam-and-4-other-countries-toincorporate-nuclear-energy-after-fukushima/; accessed 5 May 2012.
52
Yukiya Amano, “Introductory Statement to Board of Governors”, 4 March 2013, see
http://www.iaea.org/newscenter/statements/2013/amsp2013n03.html, accessed 10 June 2013.
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Below is an assessment by country of the status of the projects that the IAEA has referred to, whichindicates that most are much further from the launch of their program than the IAEA frequently
suggests.
Bangladesh currently has an installed electricity capacity of 6 GW, with plans to introduce anadditional 20 GW by 2020, reportedly to service the 60 percent of the population lacking access toelectricity.53 Bangladesh has been considering embarking on nuclear power for 50 years54 and thelatest attempt is expected to come from 2 GW of nuclear provided by Russian reactors. In 2011
Science Minister Yeafesh Osman was quoted as saying “we have signed the deal… to ease the powercrisis”. He said that construction of the plants would start by 2013 and would take five years tocomplete.55 In January 2013 Deputy Finance Minister of Russia Sergey Storchak and Economic
Relations Division (ERD) Secretary of Bangladesh Md Abul Kalam Azad signed an agreement on the
Extension of State Export Credit for financing the preparatory stage work at Rooppur.56 However, thedeal is only for $500 million57 and will only cover the site preparatory work.58 According to Rosatom
this will begin in January 201459 and is being complemented with $150 million of domestic financing.
Completion of this phase is expected by June 2017.60 Nuclear Intelligence Weekly suggests thatgroundwork will only start in January 2015 and startup by 2018.61
As with many other countries, access to water has been identified as a potential stumbling block of the
Rooppur (or Ruppur) plant, with plans to site it on the banks of the river Padmar. During the first halfof the year, much of the river’s water resource is already withdrawn by India through the Farakka
Barrage, leaving insufficient cooling water for the plant and other activities in Bangladesh.62
In mid-2006, the government of Belarus, which, 20 years before, was heavily contaminated by the
Chernobyl accident, approved a plan for construction of a nuclear power plant in the Mogilev region
in the east of the country. An agreement with Russia on cooperation for the construction of a nuclear
power plant in Belarus was signed on 15 March 2011. Expressions of interest were sought frominternational companies, and, not surprisingly given the existing economic and political ties, a bid
from Russia’s Atomstroyexport was taken forward. Under a financing agreement, Russia would
provide a $9 billion loan. Prior to 3/11, the two countries reportedly aimed at the signature of anagreement on plant construction in spring 2011, with construction starting in September of the same
year.63 In November 2011 it was agreed that Russia would lend up to $10 billion for 25 years tofinance 90 percent of the contract between Atomstroyexport and the Belarus Directorate for Nuclear
Power Plant Construction. In February 2012 Russian state-owned Vnesheconombank (VEB) andBelarusian commercial bank Belvnesheconombank signed an agreement to implement the Russian
export credit facility.64 In July 2012 a contract was signed for the construction of two VVER 1200
reactors (analogous to the Western PWR), with an estimated cost of $10 billion, including a $3 billion
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
53

Economist, “The most bucks for the biggest bang”, 6 February 2013.
WNN, “Russian loan for Rooppur construction”, 16 January 2013.
55
BBC, “Bangladesh agrees nuclear power deal with Russia”, 2 November 2011,
http://www.bbc.co.uk/news/world-asia-15552687, accessed 5 May 2012.
56
Energy Bangla “Bangladesh, Russia sign nuclear power pact”, 17 January 2013.
57
All dollar (equivalent) amounts are expressed in U.S. dollars unless indicated otherwise. However, the year’s
dollars are not always clear in the original references.
58
The Star, “Russia to lend $1.5B to Bangladesh to build nuclear power station, buy arms”, 15 January 2013.
59
Rosatom , “Photo exhibition ‘The Russian Nuclear Power’ started in Bangladesh”, 2 April 2013.
60
The Financial Express, “Building Rooppur nuke plant likely to start this year”, 2 April 2013.
61
Nuclear Intelligence Weekly, 15 March 2013.
62
A. Rahman, “Is Bangladesh Sleepwalking to Nuclear Power”, New Age Online, 7 February 2013
63
Voice of Russia, “Belarus Nuclear Deal to be Signed on March 15,” 16 February 2011.
64
WNA, “Nuclear Power in Belarus”, April 2013.
54

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in infrastructure costs to accommodate the undeveloped remoteness of Ostrovets in northern Belarus.65
In December 2012, Russian Vnesheconombank authorized allocating a $500 million credit line for the
Belarusian Finance Ministry to make advance payments for preparation work66. This phase wasscheduled to be completed by mid-2013 with concreting work to start in September 2013. The firstunit is scheduled to be operational in 2017.67
In August 2011, the Ministry of Natural Resources and Environmental Protection of Belarus statedthat the first unit would be commissioned in 2016 and the second one in 2018. Both would be of the
VVER “NPP-2006” type with a capacity of 1170 MW each.68 However, it is now expected that thereactors will not be completed until 2018 and 2020.69 Opposition to the project is increasing. On the
26th anniversary of the Chernobyl catastrophe in 2012, about one-thousand people demonstrated in the
Belarussian capital Minsk against the nuclear project,70 with a similar sized protest held in April
201371.
The Lithuanian Government has repeatedly criticised the safety of the project and has particularconcerns as the proposed site at Astravyets as it is only 50 km from its capital Vilnius. The Espoo
Convention Implementation Committee has instructed Belarus to continue environmental impact
assessment procedures based on the Espoo Convention in order to provide answers to all the questions
asked by Lithuania and take into consideration all comments. However, Vitalijus Auglys, director of
the Pollution Prevention Department in Lithuania’s Natural Resources Ministry, stated: “We haven’t
received the latest information from them. We can’t even start consultations with them, because wemust hold public discussions.”72
Lithuania had two large RMBK (Chernobyl-type) reactors at Ignalina which were shut down in 2004
and 2009 as part of the agreement to join the European Union. Before the 2009 shutdown, Lithuania’s
remaining unit generated 76.2 percent of the country’s electricity, the largest percentage shareworldwide. As a result of the closure, Lithuania has significantly increased electricity imports from
Belarus, Latvia and Russia. The decision to boost electricity imports is purely based on economic
considerations. By the end of 2011, the country had an installed capacity of about 2.8 GW compared
to a peak load of 1.9 GW.73
In February 2007, the governments of the three Baltic States and Poland agreed to build a new nuclear
power plant at Ignalina—the Visaginas project. Lithuania passed a parliamentary bill in July 2007
calling for construction and completion by 2015. The Lithuanian government announced that it would
conduct direct negotiations with potential investors and that it hoped to begin operation of the newplant in 2020.74 This led to exclusive negotiations with Korean utility KEPCO, which turned down
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

65

Nuclear Intelligence Weekly, “Belarus, Aided by Russia and Broke, Europe’s Last Dictatorship Proceeds With
NPP, 28 September 2012
66
Belarusian Telegraph Agency, “Excavation of Belarusian nuclear station second power unit foundation pit
begins”, 1 February 2013
67
Itar-Tass, “Belarus NPP cost should not exceed funds for Kaliningrad NPP construction – Semashko”,
17 February 2012, see http://www.itar-tass.com/en/c154/346054.html, accessed 1 June 2012.
68
V.V. Kulik, Deputy Minister, Ministry of Natural Resources and Environmental Protection of the Republic of
Belarus, Letter to the European Commission, dated 9 August 2011.
69
Belarusian Telegraph Agency, “Excavation of Belarusian nuclear station second power unit foundation pit
begins”, 1 February 201370
Nuclear Intelligence Weekly, 17 April 2012.
71
Belarus Digest, “The Chernobyl Way 2013”, 29 April 201372
Lithuania Tribune, “Belarus wants dialogue on nuclear power plant, but no consultations planned”,
22 April 201373
Vladas Paskevicius, “Electricity Sector Development in Lithuania”, Lithuanian Electricity Association,
December 2011.
74
WNA, “Nuclear Power in Lithuania,” October 2012, www.world-nuclear.org/info/inf109.html, accessed
10 June 2013.
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cooperation in early December 2010, two weeks after submitting a bid. In December 2011 Poland
withdrew from the project75.
The Lithuanian government, along with its partners in Estonia and Latvia, picked Hitachi together
with its Hitachi-GE Nuclear Energy Ltd. unit as a strategic investor and technology supplier toconstruct a nuclear plant by the end of 2020.76 In May 2012, the percentage breakdown of the initially$6.5 billion project were announced with a 20 percent ownership for Hitachi, and 38 percent for
Lithuania, while Estonia would take 22 percent and Latvia 20 percent.77
However, in October 2012 a consultative national referendum on the future of nuclear power was heldin Lithuania and 63 percent voted against new nuclear construction, with sufficient turnout to validate
the result.78 Prior to his appointment as Prime Minister, Algirdas Butkevicius, stated that legislationprohibiting the project would be submitted once the new parliament convenes and that “the people
expressed their wish in the referendum, and I will follow the people’s will”.79
Renewable energy suppliers are making use of the current situation to promote their expansion. The
Lithuanian wind energy association has stated: “The newly elected government will have to make a
new energy strategy, where onshore and offshore wind power possibly could take the place of nuclear
power”, both with a doubling of domestic production, to 500 MW and imports linked to winddevelopment in Sweden and Poland.80
Remarkably a Lithuanian government commissioned report concluded that under both low and highgas price scenarios it would be cheaper to buy electricity from the regional market than to proceedwith the construction of a nuclear reactor in the country. Consultants at the Lithuanian Energy Instituteconcluded that current costs of electricity, including imports, would be 4–10 Lithuanian cents (1.5–3.8
US cents) per kilowatt-hour less than power from a new reactor. Under these conditions it would save
Lithuania $152.8 million per year not to build the reactor.81
Poland planned the development of a series of nuclear power stations in the 1980s and started
construction of two VVER 1000/320 reactors in Żarnowiec on the Baltic coast, but both construction
and further plans were halted following the Chernobyl accident. In 2008, however, Poland announced
that it was going to re-enter the nuclear arena. In November 2010, the government adopted theMinistry of Economy’s Nuclear Energy Program, which was submitted to a Strategic Environmental
Assessment. Poland aims to build 6 GW of nuclear capacity with the first reactor starting up by 2020.
In response over 60,000 submissions were received from neighboring Germany; the results are due inthe summer of 2013.
Officials have revised the planning in the meantime targeting 2022–23 for the startup of the firstreactor. The State utility PGE set up two daughter companies to implement the project, which is
supposed to result in two nuclear power stations with 3 GW capacity each. PGE announced the choiceof three potential sites in December 2011: Gąski (Mielno), Lubiatowo (Choczewo) and Żarnowiec.
Financing of the ambitious project remains unclear and public opinion is highly uncertain. While
Poland was the only country showing a majority in favor of nuclear new-build in a 24-country opinion
survey in June 201182, a local referendum in February 2012 in Mielno showed a surprising 94 percent
opposed to the plan. The Polish government reacted by starting a $6 million public information
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

75

Nuclear Power Daily, “Poland Freezes Role in Lithuania Atomic Project,”, 9 December 2011
Bloomberg, “Lithuania Seeking Lower Electricity Prices at New Nuclear Plant”, 15 February 2012,
http://www.bloomberg.com/news/2012-02-15/lithuania-seeking-lower-electricity-prices-at-new-nuclearplant.html, accessed 10 June 2013.
77
Nuclear Intelligence Weekly, “Lithuania”, 11 May 2012.
78
Reuters, “Lithuanians send nuclear plant back to drawing board”, 15 October 2012.
79
Nuclear Intelligence Weekly, “Lithuania, Prospective PM Wants to Scrape Visaginas”, 9 November 2012.
80
Bloomberg, “Lithuania May Partly Replace Nuclear Power With Wind, Lobby Says”, 20 November 2012.
81
Nucleonics Week, “Visaginas generation cost would be above market prices: consultants”, 2 May 2013.
82
IPSOS, “Global Citizen Reaction to the Fukushima Nuclear Plant Disaster”, June 2011.
76

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campaign, labeled “Meet the Atom”. “We want to make sure that the first Polish nuclear power plantis established with the approval of Polish society”, Hanna Trojanowska, vice minister and government
commissioner for nuclear energy, stated in late March 2012.83 The director of external relations for thestate utility PGE, which promotes the project, stated that “obviously we will not proceed against thewill of local people”.84 A September 2012 update of the 24-country opinion survey identifies Poland
as one in only three countries where public support for nuclear power decreased, from 61 to
53 percent.85
The project does not seem to be going forward very quickly, and in January 2013 the Polish utility
PGE selected Australia’s Worley Parsons to conduct a five-year, $81.5 million study on the siting anddevelopment of a nuclear power plant, with a capacity of up to 3 GW.86 The Polish government isreviewing the project and aims to streamline project management in order to reduce costs. It wasforeseen that the first units will come into operation around 2023, with the last ones before 2030. A
tender for construction and financing was to be opened in the end of 2013. But this schedule is likely
to slip as the Prime Minister, Donald Tusk, stated in June 2013 that new nuclear may not be needed if
shale gas is developed: "I'm not ruling out nuclear in our energy mix, but later than planned (...) Thisis primarily due to the expected growth of natural gas as an energy source, including domestic shalegas."87
In August 2009 the Kingdom of Saudi Arabia announced that it was considering launching a nuclear
power program, and in April 2010 a royal decree stated: "The development of atomic energy isessential to meet the Kingdom's growing requirements for energy to generate electricity, produce
desalinated water and reduce reliance on depleting hydrocarbon resources.”88 The King Abdullah City
for Atomic and Renewable Energy (KA-CARE) has been set up in Riyadh to advance this agenda andto be the competent agency for treaties on nuclear energy signed by the Kingdom. It is also
responsible for supervising works related to nuclear energy and radioactive waste projects. In June2010 it appointed the Finland- and Switzerland-based consultancy firm Pöyry to help define a "highlevel strategy in the area of nuclear and renewable energy applications" with desalination. In June
2011 the coordinator of scientific collaboration at KA-CARE said that it plans to construct 16 nuclear
power reactors over the next 20 years at a cost of more than 300 billion riyals ($80 billion). The firsttwo reactors would be planned to be online in ten years and then two more per year until 2030.89
However, according to a World Energy Council survey, “Saudi Arabia reported that using nuclear isstill under consideration and that the WNA figures given above [16 reactors, 20 GW] are
speculative.”90 The assessment confirms reports that the KA-CARE nuclear proposal has still not been
approved by the country’s top economic board, headed by King Abdullah.91 In March 2013, it wasreported that a KA-CARE official has said that a tender is now unlikely for another 7–8 years.92
Saudi Arabia has very large electricity expansion projects. It plans to double installed capacity to
100 GW by 2021, mainly through fossil fuels, but with a 10 percent renewable target by 2020. There
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
83

Nucleonics Week, “As Polish nuclear plans progress, government seeks public support”, 5 April 2012.
Idem.
85
IPSOS 2012, “Global support for energy sources September 2012 – Change since Fukushima”,
12 October 2012.
86
Nuclear Intelligence Weekly, Briefs-Poland, 8 February 2013.
87
Business New Europe, “Poland backpedals on nuclear strategy”, 19 June 2013.
88
World Politics Review, “Saudi Arabia’s Nuclear Ambitions Part of Broader Strategy”, 16 June 2011,
http://www.worldpoliticsreview.com/articles/9186/saudi-arabias-nuclear-ambitions-part-of-broader-strategy,
accessed 6 May 2012.
89
WNA, “Emerging Nuclear Energy Countries”, February 2012, see http://www.worldnuclear.org/info/inf102.html, accessed 7 May 2012.
90
WEC, “World Energy Perspective: Nuclear Energy One Year After Fukushima”, 9 March 2012.
91
Nuclear Intelligence Weekly, “Saudi Arabia – Nuclear Plans Remain Stalled”, 13 February 2012.
92
Nuclear Intelligence Weekly, “US-Saudi NCA Talks Have Yet to Tackle ENR”, 1 March 201384

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is a $100 billion state spending commitment over the next ten years on renewables and nuclear
combined.93 Recent announcements tend to emphasize renewables; for example, 24 GW of renewablecapacity (producing one-third of projected electricity use) is reportedly targeted by 2020 and 54 GW
by 2032. A renewable-and-nuclear policy statement is expected later in 2013.94
However, these choices are not only about energy and economics. Senior Saudi Arabian diplomats
have reportedly stated that “if Iran develops a nuclear weapon, that will be unacceptable to us and wewill have to follow suit”, and officials in Riyadh have said that the country would reluctantly pushahead with their own civilian nuclear program.95 Independent experts have suggested that the drive forcivil nuclear power in the region is seen by some as a “security hedge”, and that “if Iran was not on
the path to a nuclear weapon capability you would probably not see this [civil nuclear] rush”.96
Concerns over nuclear non-proliferation have led the Canadian Government, in a briefing note, toconclude that the Kingdom “does not meet Canada’s requirements for nuclear co-operation”.97
U.S. firms are also currently excluded from any projects due to the lack of a nuclear co-operationagreement. The likelihood of an agreement being signed has been reduced recently with a speech by
Hashim Yamani, head of the KA-CARE that the Kingdom was reluctant to willingly forgo enrichment
and reprocessing98.
Turkey has a decades long history of attempting to build a nuclear power program, starting in theearly 1970s. In 2006, the government presented a revised nuclear initiative and announced plans for up
to 4.5 GW of capacity at Akkuyu and at the Black Sea site of Sinop. The plans met with large-scale
local protests. The following year, Turkey approved a bill introducing new laws on the construction
and operation of nuclear power plants, which led in March 2008 to a revised tender process for the
Akkuyu plant. Only one bid was received jointly from Atomstroyexport and Inter RAO (both from
Russia) and Park Teknik (Turkey) for an AES-2006 power plant (another name for the VVER-1200)
with four 1200 MW reactors. In May 2010, the Russian and Turkish heads of state signed anintergovernmental agreement for Rosatom to build, own, and operate the Akkuyu plant with four 1200
MW AES-2006 units—a project reported to be worth $20 billion.99 The main opposition party, theRepublican People’s Party, resorted to the courts to have the agreement overturned as it says that thetender was not open as required.100 In December 2011, the project company filed applications forconstruction permits and a power generation license, as well as for an environmental impact
assessment, with a view to starting construction in 2013.101 However, the power generation licence andenvironmental approval are only expected by the end of 2013 and the construction licence by mid
2014, enabling full construction to start in 2015.102 The most recent cost estimate is $25 billion, withthe project being built on a ‘build, own and operate’ (BOO) basis by the Russian consortium, with theelectricity being sold at a fixed price. Russia has indicated it would provide 100 percent of financing
and reportedly has already spent $700 million on the project. Accordingly, the negotiations about theelectricity price are difficult and have been ongoing for years. One source indicates that the 2010
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

93

Ernst&Young, “Renewable energy country attractiveness indices”, February 2012.
Saudi Gazette, “Saudi Arabia seeks to become ‘green’ energy efficient by 2032”, 5 July 2013, see
http://www.saudigazette.com.sa/index.cfm?method=home.regcon&contentid=20130705172382, accessed
7 July 2013.
95
Guardian, “Riyadh will build nuclear weapons if Iran gets them, Saudi prince warns”, Jason Burke,
29 June 2011.
96
The Times, “Six Arab States join rush to go nuclear”, Richard Beeston, 4 November 2006.
97
Ottawa Citizen, “Canada concerned about Saudi Arabia’s nuclear intentions”, 28 January 201398
Nuclear Intelligence Weekly, “US-Saudi NCA Talks Have Yet to Tackle ENR”, 1 March 2013
99
WNN, “Russia’s Plans for Akkuyu”, 13 May 2010.
100
Todays Zaman, “Turkey's main opposition to appeal nuclear power plant bill”, 22 July 2010
101
WNN, “Site Work to Start for Turkish Plants,” 25 February 2011.
102
WNA, “Nuclear Power in Turkey”, 9 April 2013.
94

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intergovernmental agreement committed to paying Turkey $123.5/MWh for the first 15 years.103 The
licensing process is by its very nature complex, especially as this is the first time a commerical nuclear
reactor would be licenced in the country and that there are no VVER 1200 designs in operation.
Therefore the licensing process will be heavily reliant on the reactor vendor.104
In March 2010, Turkey also signed an agreement with Korea Electric Power Corporation (KEPCO) toprepare a bid for the Sinop plant. However, the parties failed to reach an agreement because of“differences in issues including electricity sales price.”105 Negotiations switched to Toshiba, with thesupport of the Japanese government, and in December 2010 the parties signed an agreement to preparea bid for development. A French consortium of AREVA and GDF Suez has also indicated an intention
to bid for the project, as has French state utility EDF and the Chinese Guangdong Nuclear Power
Company (CGN). In November 2011 the prime minister requested the South Korean president torenew the KEPCO bid106. Yet another candidate entered the process when, on 24 April 2012, Turkish
state utility EUAS signed a memorandum of understanding with the Canadian firm CANDU-AECL(now owned by SNC-Lavalin) that covers a feasibility study for a 4-unit nuclear plant at Sinop.
However, as the trade journal Nuclear Intelligence Weekly points out, “the deciding factor in Ankara
will almost certainly not be the technology as much as the financing that comes with it”.107
In May 2013, a $22 billion intergovernmental agreement was signed between Japan and Turkey forthe construction of the Sinop plant. Within the Japanese lead consortium will be Mitsubishi, the Itochu
Corportation, and GDF-Suez. The consortium chose a, as yet never built PWR Generation III+
design—the ATMEA—form the French nuclear group AREVA. The bulk of the project will befinanced by Nippon Export and Investment Insurance (NEXI), Japan's export credit agency, andFrench credit insurer Coface.108
In October 2010, Vietnam signed an intergovernmental agreement with Russia’s Atomstroyexport tobuild the Ninh Thuan 1 nuclear power plant, using 1200 MW reactors. Construction was slated to
begin in 2014, and the turnkey project will be owned and operated by the state utility Electricity ofVietnam (EVN), with operations beginning in 2020. 109 However, in April 2013, the Song Da
Corporation stated that it expected to start construction in the next 2–3 years. 110 Rosatom has
confirmed that Russia’s Ministry of Finance is prepared to finance at least 85 percent of this firstplant, and that Russia will supply the new fuel and take back used fuel for the life of the plant. An
agreement for up to $9 billion finance was signed in November 2011 with the Russian government's
state export credit bureau, and a second $0.5 billion agreement covered the establishment of a nuclear
science and technology center.111
Vietnam has also signed an intergovernmental agreement with Japan for the construction of a second
nuclear power plant in Ninh Thuan province, with its two reactors to come on line in 2024–25. The
agreement calls for assistance in conducting feasibility studies for the project, low-interest andpreferential loans, technology transfer and training of human resources, and cooperation in the waste
treatment and stable supply of materials for the whole life of the project. In July 2011, the government
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
103

NIW, “Turkey – Financing Continues to Hold Back Nuclear Plans”, 7 September 2012.
Bookings Institute, “Human Resource Development in New Nuclear Energy States: Case Studies from theMiddle East, John Banks, Kevin Massy, Charles Ebinger (Ed.), November 2012.
105
Bloomberg, Tsuyoshi Inajima, “Turkey Holds Nuclear Talks With Japan After South Korean Discussions
Fail,” Bloomberg.com, 23 December 2010.
106
WNA, “Nuclear Power in Turkey”, May 2013.
107
Nuclear Intelligence Weekly, “Candu Down in Jordan, Up in Turkey”, 4 May 2012.
108
Reuters, “UPDATE 1-Turkey, Japan sign $22 bln nuclear power plant deal”, 3 May 2013.
109
Global Energy Magazine, “Japan and Russia to Build Ninhthuan Nuclear Power Plants for Vietnam,”
3 November 2010.
110
Investvine, “Vietnam prepares for nuclear power”, posted by Arno Maierbrugger on 13 April 2013
111
WNA, “Nuclear Power in Vietnam”, May 2013, http://world-nuclear.org/info/vietnam_inf131.html, accessed
10 June 2013.
104

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issued a master plan specifying Ninh Thuan 1 & 2 nuclear power plants with a total of eight 1000
MWe-class reactors, one coming on line each year 2020–27, then two more larger ones to 2029 at a
central location. However, the State owned Electricity of Vietnam Corporation, which is to be the soleinvestor in the four reactors, is still preparing the feasibilty studies.112 In May 2013, the Government
set up a National Council for Atomic Energy, which is designed to identify the strategies and priorities
for the development of nuclear power.113 Both of these development suggest that a 2020 startup date
for the first reactor is unrealistic.
The United Arab Emirates (UAE) has the most advanced new nuclear development plans in the
Middle East. In April 2008, the UAE published a nuclear energy policy that stated that nuclear power
was a proven, environmentally promising and commercially competitive option that “could make asignificant base-load contribution to the UAE’s economy and future energy security.”114 The policy
proposed installing up to 20 GW of nuclear energy capacity, including 5 GW by 2020, which would
then represent about 22 percent of total planned installed power generating capacity. This would
require the operation of four reactors, two between Abu Dhabi city and Ruwais, one at Al Fujayrah,
and possibly one at As Sila.
A joint-venture approach, similar to that developed for the water and conventional power utilities, wasproposed in which the government would retain a 60 percent share and a private company a 40 percent
share. A call for bids in 2009 resulted in nine expressions of interest and the shortlisting of threecompanies: AREVA (France) with GDF-SUEZ, EDF, and Total, proposing EPRs; GE-Hitachi (U.S.Japan), proposing ABWRs; and a South Korean consortium, proposing APR1400 PWRs. In December
2009, the Korean consortium was awarded the $20 billion contract for the construction and first fuelloads of four reactors, reportedly because the consortium could demonstrate the highest capacity
factors, lowest construction costs, and shortest construction times. The trade press considers that “itremains to be seen whether South Korea’s bid was realistic, or whether it was seriously under-priced”.
The outcome might be fatal: “If things go wrong, Korea’s entry to the nuclear export market could beshort-lived.“115 Indeed, updated cost estimates are reportedly already skyrocketing between $36 billionand “closer to $40 billion”.116
The regulatory review undertaken in the UAE has relied on the original 2008 assessement by the
Korean Institute of Nuclear Safety (KINS), as “since the basic reactor design had already beenreviewed by another nuclear regulator, FANR (Federal Authority for Nuclear Regulation) said that it
used the KINS Safety Evaluation Report to gloss over some parts of the Preliminary Safety Analysis
report, provided that the documentation was complete”.117
In July 2010, a site-preparation license and a limited construction license were granted for four
reactors at a single site at Barakah, 53 kilometers along the coast from Ruwais.118 The application isbased substantially on the safety analysis prepared for South Korea’s Shin–Kori units 3 and 4, the“reference plant” for the UAE’s new-build program. A tentative schedule published in late
December 2010, and not revised since, projects that Barakah-1 will start commercial operation in 2017with unit 2 operating from 2018. Construction of Barakah-1 officially started on 19 July 2012 and of
Barakah-2 on 28 May 2013. In March 2013, the Emirates Nuclear Energy Corporation (ENEC)
submitted its application for the construction of units 3 and 4, to the national regulator.119
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
112

Nucleonics Week, “Vietnam might require investors to set up fund for closure costs”, 11 January 2013.
WNN, “New nuclear development council for Vietnam”, 9 May 2013.
114
ArabianOilandGas.com “Abdullah Al Mutawa Explains How the UAE is Preparing to Meet Future Power
Demands,”, 10 June 2008.
115
Energy Economist, “Prospects for Nuclear Power in 2012”, Platts, February 2012.
116
Nuclear Intelligence Weekly, “United Arab Emirates: No Plans for Second NPP”, 20 April 2012.
117
Nuclear Engineering International, “Building Barakah”, 28 September 2012
118
ArabianBusinesss.com, “ENEC Welcomes Regulator’s License Approval,” 11 July 2010.
119
WNN, “Application in for the next two Barakah units”, 4 March 2013
113

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Construction Times
Construction Times of Past and Currently Operating Reactors
There has been a clear global trend towards increasing construction times since the beginning of thenuclear age. National building programs were faster in the early years of nuclear power. As Figure 13
illustrates, in the 1970s and 1980s construction times were quite homogenous, while in the past two
decades they have been varied. The only unit that started up in the first half of 2013, a Chinese reactor,
took 5.5 years to build and two South Korean units and a Chinese reactor that were connected to thegrid in 2012 averaged a 4.5-year construction time. Worldwide, however, it took an average of 13.8
years to build the seven units started up in 2011 and 9.5 years for the five reactors that began operatingin 2010.
The reasons for gradually increasing construction times are not well understood. It is clear that
continuously increasing safety requirements and, in some countries, lengthy legal cases due to public
opposition have played a role. While growing system complexity as a consequence of the previous
conditions is also likely to have affected construction times and costs.
Most, but not all of the nuclear countries have experienced this symptom. The latest generation ofoperating units provides an illustration of this. Over a 10-year period between 2003 and July 2013 a
total of 34 reactors started up. Average construction time was 9.4 years with a large range from
3.8 to 26.8 years. (See Annex 2 for details). There are significant differences between the ninecountries that started up reactors during that period.
Figure 13: Average Annual Construction Times in the World 1954–2013

Sources: MSC based on IAEA-PRIS 2013

Note: The bubble size is equivalent to the number of units started up in the given year.
________________________________________________________________________________All 34 reactors that started up over the past decade are located in Asia (China, India, Japan, Pakistan,South Korea), Eastern Europe (Romania, Russia, Ukraine) or the Middle East (Iran). Not a single unit

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was started up in the Western world during that period.120 With 11 units China, started up the largest
fleet, followed by India (6), and South Korea (5).
Construction times over the past decade were most impressive in Japan and South Korea with
4.4 years on average for the nine units built in both countries together, compared to performance inother countries. China reached an average of just under six years, ranging from 4.4 to 11.2 years.
Iran holds the negative record. Its only commercial nuclear power reactor took over 36 years to finallyoperate, while Romania built for over 24 years to finish its second unit and Russia an average of justunder 24 years to complete three reactors.
The increase in construction times is considered the primary driver of rising costs.

Construction Times and Costs of Reactors Currently Under Construction
As indicated in the General Overview section, at least 23 of the units listed by the IAEA as “underconstruction” have encountered costly multi-year construction delays. All of the 42 remaining units
were started within the last five years or have yet to reach their projected start-up date, making it
difficult to assess whether they are on schedule. Average construction time of the 62 listed projects
started up before 2013 currently stands at eight years, ranging from Tianwan-3, launched on
27 December 2012, to the Watts Bar-2 site in the U.S. with 40 years.

The Economics of Nuclear Power – An Update
Introduction
At the center of the claims for the new generation of nuclear power plants, so-called Generation III,
that was expected to drive a “Nuclear Renaissance” were ambitious forecasts for their economics. Ten
years ago, construction cost estimates of around $1,000/kW allowed the nuclear industry to claim thatpower from these new designs would be competitive with the cheapest source of power, natural gas,then being sold at low prices compared to current prices. The two key markets these claims seemed tohave opened up were the U.S. and the U.K., both potentially substantial markets but also highly
influential because of their historically pioneering role in nuclear power development and the strong
credibility of their safety regulatory bodies. The present chapter looks at whether the U.K. proposals
for nuclear new-build would be legal under current European Union legislation, and whether, if itwere, other Member States could adopt the ‘British Model’ to launch their own nuclear programs.
The chapter also assesses developments in China, by far the largest market for nuclear power plants inthe past decade and a potential proving ground for Generation III+ designs121; as well as progress at
the two sites in Western Europe, Olkiluoto (Finland) and Flamanville (France), where there has been
instructive construction experience with one of the two key Gen III+ designs, the French AREVA
European Pressurized water Reactor (EPR).122
A decade on, it is clear that claims for these new reactors were hopelessly inaccurate and by 2012/13,
the typical cost estimate for Gen III+ designs is of the order $7,000/kW (levelized 2012/13 USD).
Analyzing which kinds of organizations published which costs at what dates reveals that the low early
estimates were by vendors or their surrogates.123 Moreover, as analyst Jim Harding first noted, these
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
120

The last units to start up in the Western world were Brazil’s Angra-2 after 24 years of construction andCivaux-2 in France in 1999 after 8.5 years of construction.
121
The criteria for the different design generations are not precise but generation III+ designs are generally
expected to rely more on ‘passive’ rather than ‘engineered’ safety features and were therefore expected to be
simpler and cheaper than its predecessors
122
For the US market, the EPR is known as the Evolutionary Power Reactor.
123
Amory, B. Lovins, Rocky Mountain Institute, “Reinventing Fire: Bold Business Solutions for the New
Energy Era”, White River Junction, VT: Chelsea Green, see www.reinventingfire.com.
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were ‘variable’ prices, meaning that the buyer took all the risk of cost overruns. But in the late 2000s,
as commercial discussions developed for many proposed U.S. reactors, financial institutions andindependent analysts found that the actual bids suddenly became many times higher if, as they nearly
always were, the prices were ‘fixed’ (the vendor takes all the price risk) or ‘firm’ (the vendor takes all
the price risk beyond predefined metrics of inflation in the cost of the main factor inputs like steel,concrete, and labor). That is, when the vendors actually had to take much or all of the price riskthemselves, so they had an incentive to bid honest prices rather than seductive but ephemeral dreams,
the quoted nuclear construction cost soared by several- to manifold, to levels that are far, often several
or many times, higher than the observed market prices of available carbon-free alternatives (notably
efficient use, combined-heat-and-power, onshore wind power, and, in some cases, even modern
photovoltaics).
Thus at the order of cost revealed in the marketplace in recent years, new nuclear power plants areamongst the most expensive generation options available and, despite a substantial rise in gas prices inmost regions, far more expensive than gas and renewable options such as onshore wind. Whilst thecost curve for renewables is generally downwards, nuclear costs, as throughout the 60 year history of
nuclear power are still on an upward trend, especially as lessons from Fukushima are identified andincorporated into reactor designs.
Deriving a full estimate of the cost of a kWh of electricity from a nuclear power plant is an immenselycomplex process requiring a large number of assumptions. Many of these are based on little or nopractical experience of the processes involved, such as disposal of intermediate and high-level wastes
and the decommissioning of retired nuclear power plants. However, from a corporate point of view
and using conventional project appraisal techniques, there are just three variables that will largely
determine the cost of nuclear power: the cost of construction, the cost of capital and the reliability.
These three variables determine the fixed cost element of a kWh of nuclear electricity, which isnormally more than 70 percent of the total cost of a kWh of nuclear electricity.
It is important to note that the process of ‘discounting’ future costs and benefits, explained below,
under which the further into the future costs and benefits occur, the less weight they carry in projectappraisals means that any costs and benefits incurred decades in the future have much less impact on
the overall economics. This is particularly important for waste disposal and decommissioning but it
also means that the economics of nuclear power is, all things being equal, relatively insensitive toassumed plant lifetime but is particularly sensitive to reliability in the early years of operation.

The Characteristics of Nuclear Economics“What is clear is that it is completely impossible to produce definitive
estimates for new nuclear costs at this time.”
Steve Kidd
Director of Strategy & Research
World Nuclear Association
22 August 2008124

Fixed Costs
Reliability

Reliability is measured by the plant’s load factor (capacity factor in U.S. parlance). This is calculated
as the kWh produced by the plant in a given period as a percentage of the kWh that would have been
produced had the plant operated uninterrupted at its maximum power rating. Typically, the nuclear
industry has forecast the nuclear power plants would achieve load factors of 85 percent or more. In
practice relatively few plants have achieved this level of reliability over a significant period of timeand in 1980, the worldwide average load factor was 60 percent with some plants achieving good levels
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
124

Steve Kidd, “Escalating costs of new build: what does it mean”, 22 August 2008, see
http://www.neimagazine.com/opinion/opinionescalating-costs-of-new-build-what-does-it-mean/, accessed
7 July 2013.
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of reliability but others performing very poorly. Reliability is less uncertain than it was and theworldwide average is now about 70 percent with some plants tending to do considerably better than
the average. A high level of reliability of nuclear plants is not guaranteed, especially for new untested
designs, but the risk of poor performance might be less than in the past.
Construction Costs

As noted above, construction costs are highly uncertain with little prospect in the next few years that
estimating accurate construction costs will become any easier. For the purposes of analysis andcomparison, costs should exclude the financing cost during the construction process but include thecost of the first fuel charge. In other words, overnight costs should be clearly distinguished from total
costs. Comparisons also require conversion into a common currency (usually the US$) and commonbase date. This can cause problems because currency exchange rates are unstable and can fluctuate by
10 percent or more, even in a short period, so care must be taken to ensure exchange rates are
representative of long-term exchange rates and that costs are adjusted to a common time basis. These
adjustments are inevitably not exact, and mean that modest differences in costs (perhaps ±10 percent)may result simply from the inaccuracies inherent in translating to a common currency and time-basis.
Cost of CapitalIn the past, the cost of capital was not subject to much debate in forecasts of nuclear power costs. Thiswas because electricity was then a monopoly business under which the owner of the power plants
could pass on to consumers whatever costs were incurred. This meant that while nuclear power was
clearly a very risky investment because of its poor record of plant being built to time and cost andoperating reliably, this risk was generally entirely borne by customers. For financiers, nuclear power
was a low risk loan because electricity is a vital purchase and consumers nearly always paid their bills.
This meant the cost of finance—rightly or wrongly—was also assumed to be low in developed
countries. In developing countries with unstable economies and currencies, finance often has been
problematic.
As soon as the assumption of cost pass-through no longer held, either because regulators no longer
allowed whatever costs were incurred to be passed through (as in the U.S. in the late 1970s) or
because monopoly had been replaced by a competitive electricity market, finance became problematic.
In a competitive market, if a company’s power is too expensive, it will be forced out of business. It
seems highly likely that if there is no assurance that regulators will allow cost pass through or the
nuclear plant will have to survive in a genuinely competitive market, finance will not be available (orprohibitively expensive). All the nuclear plants on which construction has started in the past decade
are in monopoly systems, usually state-owned, or in markets where the plant owner has such adominant position that competition is too weak to have any impact on the owner’s ability to set prices
or the plant is largely protected by a long-term power purchase agreement (PPA).
In general, large investments are typically financed by a mix of debt (borrowing from financiers) andequity (typically from the company’s own resources or effectively foregone profits). The relative
proportions of debt and equity vary but typically equity is significantly more expensive than debt. If a
project is financed by 60 percent debt at a real interest rate of 5 percent and 40 percent equity at a realinterest rate of 10 percent, the Weighted Average Cost of Capital (WACC) is 7 percent.125
Whilst it can be helpful to compare construction costs using the “overnight cost” convention (what theplant would cost to build if that could be done overnight), over the years of actual construction the
project must also finance its capital. Longer construction thus incurs more interest (and/or dividend)costs, which compound. Moreover, if real (inflation-adjusted) construction costs escalate over time, as
they have tended to do virtually worldwide, longer construction means more cost escalation, also
compounding. The combined effect of these two phenomena in U.S. nuclear projects proposed since
the mid-2000s has been that expected total construction cost, including financing and real escalation
during construction, approaches double the overnight cost.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
125

5*0.6 + 10*0.4 = 7

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Cost of Decommissioning and Waste Disposal

Other costs such as waste disposal and decommissioning are expected to be huge, on the order ofbillions of dollars per reactor, and are highly uncertain because of the relative lack of experience of
these processes, (especially if many reactors must be decommissioned at once, straining limited
technical resources). But under conventional project appraisal techniques, these costs are ‘discounted’
to give a ‘net present value’ (NPV) far below their undiscounted cost. For example, it is often
assumed, as in the U.K., that the expensive, problematic and unproven part of the decommissioning
process, cutting up and disposing of the reactor vessel, takes place perhaps 150 years after the start ofoperation. Under conventional accounting procedures, the owner of the plant effectively puts aside asum of money now and it is assumed this money will earn interest until it is required to pay fordecommissioning. If we assume a real (net of inflation) interest rate of 3 percent, over 150 years126, a
sum of money will grow by a factor of more than 80. So if we assume that the construction of a newreactor would be $10 billion and the undiscounted decommissioning cost would be half that figure, thediscounted cost of decommissioning (NPV) would be just $59m. Even if we assume a delay of
75 years (perhaps 15 years after plant closure) and take the more cautious assumption, of a real interest
rate of 2 percent earned over 75 years127, the discounted decommissioning cost (NPV) would be about$1 billion. In practice, the funds are accumulated through what is effectively a surcharge on the priceof electricity, although in some countries they may be not set aside at all but spent for other purposes.
For this method of provisioning to give a high level of confidence that sufficient funds are available tocarry out decommissioning when a future generation (whose decision it will be on timing, not thecurrent generation) decides to carry out the task, the following conditions will have to be fulfilled:• The funds are actually set aside and are not lost, for example due to investment in funds that fail;• The processes required are technically feasible, including disposal of the waste;• The cost estimates for each step are accurate;• The forecast rate of interest is actually achieved;• The forecast timing of decommissioning is correct; and• The plant operates for as long as expected.
Current best-practice, certainly not implemented in most countries, is that decommissioning funds andfunds to pay for waste disposal, are invested in funds that are ‘segregated’ from the company thatowns the plant so if the company fails, the provisions are not lost and the company cannot use theprovisions as a cheap source of capital to fund its own, perhaps risky investments. Funds are also
placed in very low risk investments—inevitably, this means the interest rate will be correspondingly
low—to minimize the risk of failure of the investments made. This best practice partly addresses thefirst risk but addressing the other risks, where possible at all, would require additional safeguards, forexample, expensive financial instruments that would be guaranteed to make up any shortfall in funds.
It is not clear whether such instruments would be available and credible, nor what their cost would be.

The U.S. Nuclear Power Program
The U.S. government was the first to respond to the promises made of a ‘Nuclear Renaissance’
through President George W. Bush’s Nuclear 2010 Program launched in 2002. At that time, the mostrecent order for a nuclear power plant not subsequently cancelled was placed in 1973. The Bushgovernment believed that new nuclear power plants were competitive with any other form ofgeneration (including gas) and all that was needed to re-start ordering was to provide subsidies toallow the construction of a handful of demonstration plants (perhaps three projects) that would showthat the issues that had led to the collapse of ordering in the U.S. had been solved by Generation III+
designs. The expectation at the time of the launch of the program was that the first plants would comeon line by 2010.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
126
127

Based on an operating life of 60 years and a delay to complete decommissioning of 90 years.
Based on an operating life of 40 years and a delay to complete decommissioning of 35 years.

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Loan Guarantees and Other Subsidies128
The U.S. Energy Policy Act of 2005 (EPACT 2005) provided a legal basis for the program andenvisaged three types of support.129 First, a limited number of new nuclear power plants could receive$18/MWh production tax creditfor eight years for up to $125m per 1000MW (or about 80 percent ofwhat the plant could earn if it ran 100 percent of the time).130 The second benefit was a provision forfederal loan guarantees covering up to 80 percent of project costs. The third benefit provided up to$500m in risk insurance for the first two units and $250m (€187.5m) for units 3–6. This insurance wasto be paid if delays not the fault of the licensee slow the licensing of the plant.131
The key subsidy was the Federal loan guarantees which allowed the developers to borrow at interest
rates comparable to the Treasury rates. In 2009, four of the projects were shortlisted for loan
guarantees. Two of these, the Summer (South Carolina) and Vogtle (Georgia) projects, were for twin
AP1000s and were in states where electricity remains a regulated monopoly, while the other two,
Calvert Cliffs (a single EPR) and South Texas (a pair of ABWRs) are in states with competitive
wholesale electricity markets. Not by coincidence, the two projects in competitive markets are highly
unlikely to go ahead even with loan guarantees. Federal loan guarantees require the payment of a feethat reflects the riskiness of the project.
The fee for the Calvert Cliffs plant was reported to be 11.6 percent of the amount of loan guarantees
offered, $7.6 billion and the size of this fee was reported to be a key element in the decision not topursue this project.132 There was also an issue over the ownership of the plant. U.S. law prohibits
foreign control of nuclear power plants, but after the main U.S. partner, Constellation, withdrew fromthe project, this left EDF as the sole owner. As a result, the NRC refused permission for the project togo ahead.133 In April 2011, NRG, the main developer for the South Texas project stopped funding andwork effectively ceased on the project.134 This left Toshiba American Nuclear Energy Corporation(TANE) as the effective controller of the project. Whilst TANE’s nominal stake is only 10 percent in
Nuclear Innovation North America (NINA), the NRC ruled that “its overwhelming financial
contributions give it significantly more power than is reflected by this ownership stake.”135
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

128

Doug Koplow dedicated an entire report to the specific issue of nuclear subsidies. He concluded that in the
U.S. proposed subsidies to many of the new-build projects exceed actual power generation prices. See Doug
Koplow, “Nuclear Power: Still Not Viable without Subsidies”, Union of Concerned Scientists (UCS), February
2011, available at http://www.ucsusa.org/nuclear_power/nuclear_power_and_global_warming/nuclear-powersubsidies-report.html.
129This subsidy, in pretax levelized value, is worth $25/MWh at a 15 percent annual hurdle rate, 40 percent
marginal tax rate, and 40-year operating life (or $11/MWh using a 3 percent real discount rate). That’s less thanthe value—$28 and $18/MWh respectively—of new wind power’s tax credit, which (unlike the permanent
nuclear one) currently expires for projects not begun by the end of 2013. However, legacy operating subsidies of$3–8/MWh more than make up the difference, giving the next 6 GW of U.S. nuclear new-build a higher-thanwind-power operating subsidy in addition to ~100% construction subsidies; Amory B. Lovins, personalcommunication, 7 July 2013.
130
This production tax credit, which approximates the credit available for wind power, is available to the first
6GW of new units over the next eight years and is to be divided among the eligible plants. So if 12GW worth of
new plants meets the criteria each one would get the credit only for 500 MW. It is equivalent to paying about$140/ton for avoided carbon assuming that the plant displaces half coal and half gas, though of course the plant
would go on avoiding carbon for many years after the credit expired.
131
All three measures require implementing regulations, and the loan guarantees require an appropriation. So theactual scope and benefit of the subsidy is unclear.
132
Nucleonics Week, “Constellation move casts doubt about nuclear merchant plants' future”, 14 October 2010.
133
Washington Post, “New nuclear reactor rejected; Rule against foreign ownership trips up UniStar's bid”,
12 March 2013.
134
Nucleonics Week, “Merchant economics hurt new projects, operating units: analysts”, 13 September 2012.
135
http://www.worldnuclearreport.org/US-Ownership-Rules-Hurdle-for.html, accessed 9 May 2013.
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Generic Design Reviews136
Four designs137 started a process of generic design review intended to resolve all significant design
issues other than site-specific ones. A fifth design, the ABWR138 , had already received generic design
approval in 1997 but this approval expired in 2012 and is being renewed. A large number of potential
projects quickly emerged with about 23 substantial proposals with a total of 36 reactors projected. The
optimism quickly waned as estimated costs escalated at an alarming rate, the required Federal budget
for loan guarantees skyrocketed, generic design reviews took much longer to complete than expected
and natural-gas prices fell. Many of the projects made little significant progress.
Of the five designs, the ESBWR and the APWR have no realistic prospects for orders. Only the
AP1000 has received full generic design approval.139 In April 2013, no completion date for the ABWR
reviews was specified, the EPR review was not expected to be complete before 2015,140 and the
APWR review was scheduled for completion in 2015.141 The ESBWR review was said to be nearcompletion but a new issue arose and there is now no scheduled date for completion.142

Vogtle and Summer
The Vogtle site is where two reactors were completed in the 1980s which suffered some of the largest
cost escalations of any project. Those two reactors were originally budgeted to cost $660m but ended
up costing $9 billion. 143 The current Vogtle project, to add two modern reactors, was given a
conditional offer of $8.3 billion in loan guarantees in 2010. The size of the fee was not published but
was reported to be between 0.5 and 1.5 percent based on the strong backing of the parent company ofthe developer, Southern Company, and on the expectation that the Georgia Public Service
Commission (PSC) would allow full cost recovery.144 The Georgia PSC allowed Southern Company tobegin to recover the costs of the plant from consumers in 2011.
By early July 2013, there was still no agreement on the final terms of the loan guarantees and theoffer’s deadline was extended for the third time, to the end of September 2013. On 21 June 2013,
ratings agency Zacks downgraded Southern Company’s credit rating.145 Construction (pouring of firststructural concrete) at the first unit at Vogtle started on 12 March 2013146, by which time the cost andschedule were already beginning to overrun.147 When the project was approved, its estimated cost hadrisen to $14 billion. However, in the year up to the start of construction, problems with site preparationand initial construction work had led to the owners of the plant to sue two major contractors for$900 million.148 The plant is reported to be already about a year behind its schedule of completing thefirst unit in 2017. Georgia Power, the largest partner in the project (but still a minority owner, having
laid off most of the cost and risk on relatively small partners), requested a $381 million increase in thecertified capital cost of its share of the project to approximately $4.8 billion from $4.4 billion,
according to Moody's. It also indicated that financing costs would rise to about $2.1 billion from
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

136

http://www.nrc.gov/reactors/new-reactors/design-cert.html, accessed 1 May 2013.
These were the Westinghouse AP1000, the GE-Hitachi ESBWR, the AREVA EPR, the Mitsubishi AP1400.
138
The ABWR is offered both by Toshiba and GE-Hitachi in competition.
139
http://www.nrc.gov/reactors/new-reactors/design-cert/ap1000.html, accessed 13 May 2013.
140
http://www.nrc.gov/reactors/new-reactors/design-cert/epr/review-schedule.html, accessed 13 May 2013.
141
http://www.world-nuclear-news.org/RS-APWR_design_certification_rescheduled-1306124.html, accessed
13 May 2013.
142
http://www.nrc.gov/reactors/new-reactors/design-cert/esbwr/review-schedule.html, accessed 13 May 2013.
143
Associated Press, “'Significant' issues building new Ga. nuke plant”, 10 June 2011.
144
Nucleonics Week, “Varying financing terms seen for utility, merchant projects”, 11 March 2010.
145
PR Newswire, “Another Vogtle Reactor Deadline Passes: Taxpayer Advocates Warn Government Keeps
Pushing Bad Deal That Wall Street Won't Touch”, 2 July 2013.
146
http://www.worldnuclearreport.org/Construction-Start-at-Vogtle.html, accessed 13 May 2013.
147
The Atlanta Journal-Constitution, “Vogtle rises, but nuke revival lags”, 17 February 2013.
148
Nucleonics Week, “US modular nuclear construction going slower than expected: monitor”, 3 January 2013.
137

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$1.7 billion because of a delay in the scheduled completion date.149 Credit rating agencies are criticallyexamining the credit rating of one of the smaller of the four partners in the project.150 The largest
partner in the project with 46 percent is Georgia Power, part of the huge Southern Company and seen
as being large enough not to be put at risk by cost overruns. However, the second largest partner with
30 percent is the much smaller Oglethorpe Power Corp. The cost overruns led Fitch to put its credit
rating on “negative outlook”, i.e. at risk of being downgraded.
The Summer project has even stronger backing from the state regulatory body in South Carolina, andalthough the owners sought loan guarantees of about $8 billion, which they may decline if they
consider the fee too high. In March 2013, an appeal to the South Carolina Supreme Court was
launched by, amongst others, the Sierra Club, against the decision by the South Carolina PublicService Commission to allow recovery of $300m from consumers for expenses related to constructionof Summer.151 Construction of the first unit started in March 2013 with a targeted completion date of2017 and 2018 for the second unit.152
The Vogtle and Summer projects both depend on unusual state laws that require customers to pay forthe plant as it’s built, whatever it costs, and whether it ever runs or not. The owners apparently think
this manages their own risk. However, similar arrangements turned out in the 1970s–80s nuclear boom
to increase the owners’ risk for two reasons: price elasticity has longer to work during construction—
increasing the likelihood of lower-than-expected demand and hence revenue once the plant isfinished—and continual price increases and cost-overrun headlines annoy customers and hence
regulators, who have many ways to penalize the utility no matter what the law says about the project.

Further prospects
The low spot price of natural gas in the U.S. and the booming renewable energy industry (see Chapter
Nuclear Power vs. Renewables) have limited prospects for new nuclear (and coal-fired) plants andeven threaten the viability of existing plants. Beyond Summer and Vogtle, there seems little prospectin the next few years of any other projects going ahead. The former CEO of Constellation, Michael
Wallace, told Nucleonics Week153:
It is now not possible for merchant generating companies to move forward with new nuclear projects.
Only those projects in highly-supportive states like Georgia and South Carolina, where nuclear plant
expansions at Southern Nuclear's Vogtle and South Carolina Electric & Gas' Summer are located, appear
likely to go ahead. The economic pressures are threatening even operating units. It is quite likely—more
than that, highly probable—that there will be existing plants prematurely shut down for economic
reasons.

The closure of the Kewaunee154 (PWR, 584 MW started up in 1973) and Crystal River155 (PWR,
838 MW, started up in 1977) plants was announced in 2012/13 despite both plants’ having received
NRC license extensions from 40 years to 60 years.
UBS saw these closures as harbingers of further closures for ‘merchant plants’ (those exposed tocompetitive electricity markets) as the non-fuel operating costs of nuclear plants more thancounterbalanced low fuel costs. UBS stated156:
Following Dominion’s recent announcement to retire its Kewaunee nuclear plant in Wisconsin in
October, we believe the plant may be the figurative canary in the coal mine. Despite substantially lower
fuel costs than coal plants, fixed costs are approximately 4–5x times higher than coal plants of

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
149

The Bond Buyer, “Moody's: Vogtle Nuclear Plant Cost Hikes, Delays are Negative”, 4 March 2013.
Associated Press, “Credit agencies eyeing Plant Vogtle cost overrun”, 10 April 2013.
151
SNL Generation Markets Week “SC court to review SCE&G's recovery of additional Summer nuke project
costs”, 26 March 2013.
152
http://www.worldnuclearreport.org/Summer-South-Carolina-First.html, accessed 13 May 2013.
153
Nucleonics Week, “New nuclear expectations modest, conference told”, 21 June 2012.
154
http://www.worldnuclearreport.org/Kewaunee-Plant-in-Wisconsin-Closed.html accessed 10 May 2013.
155
http://www.worldnuclearreport.org/Crystal-River-Reactor-Shut-Down.html, accessed 10 May 2013.
156
UBS Investment Research, “Re-evaluating merchant nuclear” 2 January 2013.
150

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comparable size and may be higher for single-unit plants. Additionally, maintenance capex of ~$50/kWyr, coupled with rising nuclear fuel capex, further impede their economic viability and mask underlying
FCF generation when comparing EBITDA and ascribing EV/EBITDA multiples. Units at particular risk
include Exelon’s Clinton unit in Central Illinois, and its Ginna plant (CENG) in upstate NY, as well as
ETR’s Fitzpatrick and Yankee plants. We see risk to primarily deregulated assets in New York andMidwest, which suffer from low capacity payments due to over-capacity and structural regulatoryinterference, in conjunction with low power prices.

The U.K. Nuclear Program
The U.K.’s commitment to renew nuclear ordering came in 2006, a year later than that of the U.S. By
then, the promise of $1,000/kW had been proven to be far too optimistic by the fixed-price bid that
had won the tender for the Olkiluoto plant at more than $2,000/kW in 2003. The basis for the U.S.
program was that the new designs would be economically competitive with the cheapest fossil-fueled
options. All that was needed was a handful of subsidized demonstration plants after which ordering
without subsidies would supposedly be self-sustaining. The British case was that new nuclear would
not be as cheap as the cheapest fossil-fueled options but with a carbon price on the European Union
Emissions Trading System (EU ETS) of €36 in 2020 (in 2008 values) new nuclear would becompetitive. On this basis, the government claimed that with a few enabling decisions, such as
allocation of sites and generic approval of the designs, utilities would choose nuclear power over otheroptions.
To back this claim, the government made a firm commitment that no public subsidies would be given.
This claim was never realistic, and as is discussed below, what is proposed now, despite the U.K.
government’s claim that no subsidies are being offered, represents a massive subsidy to new nuclear
power plants. Nevertheless, like the U.S. program before it, the claim that subsidies would not beneeded was a hugely influential endorsement of the new-generation designs.

The Plans: 2006–10
In November 2005, the Government of Tony Blair instituted a review of energy policy widelyreported as being aimed at restarting a nuclear program only two years after the completion of an
earlier review that found no economic case for new nuclear power stations157 . A key element of the
proposed nuclear program was the promise that there would be no subsidies. In 2006, well before thereview was complete, the Secretary of State for Trade and Industry (the ministry then responsible forenergy) was questioned by a Select Committee on the issue of subsidies:158
Q: ‘Do you think the Government would be prepared to consider guarantees: for example, a cap on thewaste costs of new nuclear, or sharing initial planning costs, or even guaranteeing the price of the energy
produced from nuclear?
A: ‘I would be very surprised if we issued that kind of guarantee. The one thing I am clear about is thatwhen we look at nuclear, we have to look at cost, safety and waste. Those are the three big issues thatwere around in 2003 and they are the big issues now. I expect new plant to be built and run by the private
sector. There is a market here…. First of all, and I know this is not the precise question you are asking,there is no expectation of taxpayers' money being thrown into this. It is down to the private sector.’

The government was also adamant that there would be competition between vendors and developers.
It therefore instigated a program in 2007 of Generic Design Assessment (GDA) under which the U.K.
safety regulator, then the Nuclear Installations Inspectorate, subsequently renamed the Office of
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
157

The Energy Policy Review of 2003 found: “While nuclear power is currently an important source of carbon
free electricity, the current economics of nuclear power make it an unattractive option for new generating
capacity and there are also important issues for nuclear waste to be resolved.”, BERR (2003) “Our energy future- creating a low carbon economy”, BERR, London p 61
http://webarchive.nationalarchives.gov.uk/+/http://www.berr.gov.uk/files/file10719.pdf, p.61, accessed
1 May 2013158
http://www.publications.parliament.uk/pa/cm200506/cmselect/cmenvaud/584/5112304.htm, accessed
1 May 2013
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Nuclear Regulation (ONR), would carry out a comprehensive review of a number of designs so that apotential customer would know the only regulatory issues remaining for that design would be limitedsite-specific ones. Four designs entered the GDA: the AREVA EPR, the Toshiba/Westinghouse
AP1000, the Hitachi-GE ESBWR, and the AECL ACR1000. This process was scheduled to becompleted in July 2011.
In 2009, EDF took over the company that owned most of the U.K.’s nuclear power plants, British
Energy, giving it access to the main expected sites for new nuclear power plants. To ensurecompetition between developers, the government auctioned land at sites of existing nuclear power
plants to other potential developers. It was expected such sites would be suitable for new nuclear
power plants and would see much less opposition than new sites. Three consortia were set up to
develop new nuclear plants:• NNB GenCo, a joint venture between EDF (80 percent) and the U.K. energy supplier, Centrica(20 percent);• Horizon, a 50/50 joint venture between the two German utilities, E.ON and RWE, which alreadyhad a strong position in the U.K. market; and• Nugen, a joint venture comprising the owner of Scottish Power, the Spanish Iberdrola(37.5 percent), the French GDF Suez (37.5 percent), and Scottish & Southern Energy, S&SE
(25 percent).
NNB GenCo planned to build four EPRs, two each at Hinkley Point and Sizewell, the first then
expected on-line by 2017. Horizon also planned to build four reactors, design not specified, two eachat Oldbury and Wylfa; while Nugen acquired a site at Sellafield but did not specify the number anddesign of reactor to be built. A White Paper on nuclear power was published in January 2008. It
concluded:159
The Government believes it is in the public interest that new nuclear power stations should have a role toplay in this country’s future energy mix alongside other low-carbon sources; that it would be in the public
interest to allow energy companies the option of investing in new nuclear power stations; and that theGovernment should take active steps to open up the way to the construction of new nuclear power
stations. It will be for energy companies to fund, develop and build new nuclear power stations in the
U.K., including meeting the full costs of decommissioning and their full share of waste management
costs.

The cost calculations behind this conclusion showed that nuclear power was not as cheap as gas-fired
plants but with a carbon price of €36/ton, it was competitive.160 The Government’s cost-benefit
analysis used a central assumption on an overnight construction cost of £1,250/kW (less than
$2,000/kW). A lower-cost case of £850/kW (about $1,300/kW) and two higher-cost scenarios of£1,400/kW (about $2,100/kW) and £1,625/kW (about $2,400/kW) were examined. Even then, thehighest-cost estimate was grossly out of line with estimates emerging from the U.S. program and fromtenders for new nuclear capacity in Canada and South Africa, which were then around $5,000/kW.161

Electricity Market Reforms
Until 2010, the government maintained the façade that new nuclear power stations would compete in
the wholesale electricity market set up 20 years earlier on equal terms with other forms of generation,with just the Carbon market price derived from the EU ETS as support. In February 2010, the Labour
energy minister, Ed Miliband,162 and the energy economic regulator, Ofgem,163 both stated that the
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
159

Department for Business, Enterprise & Regulatory Reform (2008), “Meeting the Energy Challenge: A White
Paper on Nuclear Power”, The Stationery Office, Norwich.
http://webarchive.nationalarchives.gov.uk/+/http://www.berr.gov.uk/files/file43006.pdf, p.10, accessed
1 May 2013.
160
Idem, p.59.
161
Steve Thomas, “The economics of nuclear power: an update”, Heinrich Boell Stiftung, 2010, see
http://www.boell.de/downloads/ecology/Thomas_economics.pdf, p.48 accessed 1 May 2013
162
The Times, “Labour prepares to tear up 12 years of energy policy”, 1 February 2010.
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existing electricity market arrangements had to be reformed if security of supply were to be
maintained and the U.K.’s targets on reductions of greenhouse gas emissions were to be met. In May
2010, Gordon Brown’s Labour government was replaced by a coalition government comprising theConservatives and Liberal Democrats (previously opposed to nuclear power) but there was no lessgovernmental enthusiasm for nuclear power, and the process of Electricity Market Reform (EMR)
foreshadowed in the February statements, noted above, was instigated in July 2010.164
In a statement to Parliament in October 2010165 by Chris Huhne, the Government maintained therhetoric of no subsidies for new nuclear: “I should like to take the opportunity to reconfirm theGovernment’s policy that there will be no public subsidy for new nuclear power.” However, in thenext sentence the government acknowledged that subsidies could be offered: “To be clear, this meansthat there will be no levy, direct payment or market support for electricity supplied or capacity
provided by a private sector new nuclear operator, unless similar support is also made available more
widely to other types of generation.” The current minister in charge of the Department of Energy andClimate Change (DECC), Ed Davey (also a Liberal Democrat), has affirmed that this statement
remains Government policy.166
A White Paper on EMR in July 2011 was eventually followed by a draft Energy Bill in November
2012. The two proposals of most relevant to nuclear power were:167
1. A Carbon Price Floor to reduce investor uncertainty, putting a fair price on carbon andproviding a stronger incentive to invest in low-carbon generation now;
2. The introduction of new long-term contracts (Feed-in Tariff with Contracts for Difference) to
provide stable financial incentives to invest in all forms of low-carbon electricity generation.
The Carbon Floor Price (CFP) was introduced in 2013 and will rise to €36/ton (in 2010 prices) by
2020, the level at which the 2008 White Paper claimed it would be competitive with gas-fired
generation.

Technologies
Less than a year after GDA was started, the Canadian ACR1000 design was withdrawn from theprocess.168 Hitachi-GE’s application for the ESBWR was suspended in September 2008.169 The GDA
process was due to be completed in July 2011, but some time before then, the U.K. regulatory body,the Office of Nuclear Regulation (ONR) acknowledged that it would not be able to issue a timely
Design Acceptance Certificate (DAC). It proposed that it could issue an Interim DAC (IDAC) with alist of issues to be resolved subsequently. The Fukushima disaster delayed things for six months and in
December 2011, the ONR issued IDACs for the two remaining designs, EPR and AP1000.170 The
AP1000 vendor, the Westinghouse division of Toshiba, stated that as they had no prospective
customer for the AP1000, they would not be attempting to resolve the remaining issues, and no further
work on the AP1000 has been carried out by ONR since then.171
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
163

http://www.ofgem.gov.uk/Media/PressRel/Documents1/Ofgem%20%20Discovery%20phase%20II%20Draft%20v15.pdf, accessed 1 May 2013.
164
http://www.decc.gov.uk/en/content/cms/consultations/emr/emr.aspx, accessed 1 May 2013.
165
http://www.decc.gov.uk/en/content/cms/news/en_statement/en_statement.aspx, accessed 1 May 2013.
166
http://www.libdemvoice.org/there-will-be-no-public-subsidy-for-nuclear-28150.html, accessed 1 May 2013.
167
http://www.decc.gov.uk/en/content/cms/legislation/white_papers/emr_wp_2011/emr_wp_2011.aspx,
accessed 1 May 2013.
168
Nuclear News, “AECL drops out of new build process”, May 2008.
169

European Daily Electricity Markets “Two designs left in UK's nuke screening process, as GE-Hitachisuspends involvement”, September 2008.
170
http://www.hse.gov.uk/newreactors/regulators-issue-interim-dac-soda-gda-key-milestone.htm, accessed
1 May 2013.
171
http://www.prnewswire.com/news-releases/westinghouse-welcomes-interim-approval-for-ap1000-reactorfrom-uk-regulators-135586383.html, accessed 1 May 2013.
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In effect, given that the only remaining developer in the near term is EDF, which is highly unlikely tochoose any technology other than one supplied by AREVA—both companies being majority ownedby the French state—this means that the objective to have competing technologies has failed and theonly option is the EPR (discussed below). ONR claimed the remaining 31 issues could be resolved
within a year of issuing the IDAC. In December 2012, ONR issued a DAC for the EPR.172 It istherefore clear that in the short term there can be no competition between technologies except in theunlikely event that a new developer emerges hoping to build the AP1000.

Developers
NNB GenCo owns the prime sites, having been granted in November 2012 a site license for Hinkley
Point.173 EDF’s commitment to nuclear power is strong and it has the full backing of the French
Government and NB GenCorp must be seen, for these purposes, as driven by EDF. Centrica withdrew
from the joint venture in January 2013 and despite speculation that a Chinese partner would be
brought in to replace it, EDF remains the sole owner.
In March 2012, E.ON and RWE announced they were seeking to sell their stakes in Horizon. Several
buyers were mooted but in November 2012, Horizon was sold to the reactor vendor Hitachi-GE.174
The sale figure was reported to be £700m175 but it is likely this figure is contingent on a number offactors. Hitachi-GE’s technology is the Advance Boiling Water Reactor (ABWR). The U.K. safety
authorities have little experience of assessing boiling water reactors and so it seems highly unlikely
getting a DAC would take less than the 5–6 years it took the EPR, so it seems unlikely that an order
for an ABWR could be placed before about 2020.
The Nugen joint venture was always the least committed of the three consortia. S&SE announced its
withdrawal from the consortium in September 2011176, leaving the other two members to increase theirstake to 50 percent. In autumn 2012, it was widely rumored that Iberdrola was also considering
withdrawal from Nugen.177 Keith Anderson, the U.K. head of Iberdrola, said that with the possibilityof blackouts looming as soon as 2015, there was no point rushing to build nuclear reactors because
they take about ten years to go online.178 The assumption must therefore be that Nugen is not likely toproceed with new-build in the near future.

The Negotiations
With Nugen and Horizon not in a position to proceed, the Government has opened bilateral talks with
EDF on the terms of a long-term Contract for Difference (CFD) for the first station, Hinkley Point.
The CFD and Feed-in Tariff (FIT) framework to be set up under EMR provided a framework underwhich negotiations were able to start between the Government and NNB GenCo. The FIT
arrangements provided certainty that all the output of any nuclear plant would be sold at apredetermined price, while the CFD provided predictability on the income per unit sold. Under a CFD,
the selling price is partly fixed but with “escalators” to cover general inflation and allow priceincreases outside the control of the plant owner to be passed on to consumers. The “difference”
element is simply a device for reimbursing any difference between the market price and the sale price.
So if the market price is less than the contract price, the plant owner will receive the market price fromthe market, and any difference between the contract price and the market price will be paid to or fromthe plant owner, ultimately by customers.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

172

http://www.hse.gov.uk/newreactors/reports/step-four/close-out/epr70475n.pdf, accessed 1 May 2013.
http://www.hse.gov.uk/nuclear/hinkley-point-c/index.htm, accessed 1 May 2013.
174
http://www.horizonnuclearpower.com/files/downloads/Horizon%20Completion%20Release%20%28National%29.pdf, accessed 1 May 2013.
175
Independent, “Hitachi signs '100-year commitment' to boost UK's nuclear expansion plans”, 30 October 2012.
173

176

http://www.nugeneration.com/download/GDF_SUEZ_IBERDROLA%20release.pdf., accessed 1 May 2013.
Utility Week, “Iberdrola cooling on UK nuclear?”, 5 October 2012.
178
The Times, “The answer to future power supply is blowing in the wind, says Iberdrola” February 15, 2013
177

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Negotiations will focus on two elements. The more obvious one, the “strike price”, is the basic pricepaid per MWh. This has to be high enough to cover the full expected costs of building and operating
the nuclear plant and much of the publicity has included speculation on what the price will be with
reports in 2013 suggesting a price of £100/MWh.179 However, of at least as much concern to NNB
GenCo and its financiers are the escalators. It might be expected that the strike price would be indexed
to general inflation so the real value of the income from the plant was protected, but this does notcover the economic risk. If construction costs escalate, or reliability is poorer than assumed, or
operations & maintenance costs are higher than forecast, the costs will be higher than expected and if
these costs cannot be recovered from consumers, the viability of NNB GenCo would be in doubt. Notethat it is not clear how far EDF would back NNB GenCo if it did get into financial difficulties. If it
were allowed to fail as happened when British Energy went bankrupt in 2002, British taxpayers could
again be called upon to provide subsidies to allow the plants to continue to operate. Whether thedetailed conditions of the CFDs will be made public is doubtful even though it would be a contract
signed by a public body underwritten by taxpayers and electricity consumers. It is likely that theGovernment and NNB GenCo would argue important details were commercially sensitive and should
not be made public. There has also been no decision on the duration of the CFD although media
reports in late May 2013 suggest 35 years.180 Reports also suggest that EDF is holding out for terms
that will ensure it obtains a 10 percent real rate of return.
Negotiations will hinge on whether a contract can be agreed that passes enough of the economic riskof a nuclear power plant on to consumers to satisfy financiers that their loans were secure enough toissue, but not so much that the Government, especially the Treasury, will be unwilling to agree to theterms because they placed too much risk on taxpayers. In June 2013, the U.K. Government announced
it would offer loan guarantees, reported to be worth about £10 billion of the £14 billion that the
Hinkley Point reactors are forecast to cost. 181 Despite this, the Secretary of State for Energy
acknowledged on 2 July 2013 that agreement was “a few months away”.182

Further Prospects
At time of writing, it is unclear whether an agreement can be reached. However, as in the U.S., thecosts are so high and the problems of obtaining terms that will allow finance to be obtained ataffordable interest rates that the prospect of a stream of orders following to fulfill the Government’s
objective of getting orders for 16 GW of new capacity placed appear to be minimal. Also note thateven an agreement on a CFD is no guarantee to secure financing for the actual implementation of a
new-build project. And whatever the financing, there is no guarantee that the project can be built tocost, nor that even if it is, customers will want to buy its output, since the prices reportedly being
discussed are roughly twice the market price of U.K. electricity and far above those of abundantcompetitors, such as onshore wind power.

European Union Policy
State Aid
While prospects in the U.K. are limited, even if only one or two reactors are ordered in the U.K., theimplications for the rest of the EU would be significant. If an agreement can be struck between the
U.K. Government and EDF, it seems inevitable that a major investigation by the EU Competition
Commission will have to take place to determine whether the U.K. contracts represent illegal state aid.
This is likely to further delay start of construction by two or three more years. Nevertheless, about
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

179

See Independent, 29 October 2012; Financial Times, 24 July 2012 and Daily Telegraph, 13 August 2012.

180

Wall Street Journal, “EDF, U.K. Near Agreement on Most of Nuclear Reactor Deal”, 26 May 2013.
See https://www.gov.uk/government/speeches/speech-by-chief-secretary-to-the-treasury-danny-alexanderinvesting-in-britains-future and Guardian, “Nuclear power gets £10bn financial guarantee boost”, 27 June 2013.
181

182

Bloomberg, “EDF Nuclear Deal in U.K. May Take ‘A Few Months’’, 2 July, 2013

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eleven other Member States are reported to be interested in using the U.K. model of CFDs as a basis
for ordering in their home markets. This includes Poland, Czech Republic and France.
There would seem to be little doubt the CFD regime for nuclear power does represent state aid – itdoes clearly benefit nuclear power and it is granted by the State. The crux of the case would bewhether it “favors certain undertakings or the production of certain goods (selectivity)”; and “is liable
to distort competition and affect trade between Member States”. Fouquet & Thomas183 argue it clearly
does violate these conditions and would, or at least should, be judged to be unfair state aid andtherefore illegal under EU law.

Changes to State Aid Guidelines
In parallel with this effort, there is also pressure to change the EU guidelines on state aid for nuclear
power so that it can be subsidized in the way that renewables and energy efficiency are subsidized insome countries. These efforts are part of a review by the Commission of “block exemption regulation”
under which the Commission can exempt certain categories of aid from the notification requirement
applicable to all State aid measures of Article 108(3) of the Treaty on the Functioning of the European
Union (TFEU). Those categories refer, among others, to environmental protection. Thus the General
Block Exemption Regulation does not, for example, provide for a general exemption in the field ofenergy, or an exemption to ensure security of supply.
State aid can be cleared by the Commission in some specific cases under the guidelines forenvironmental protection (2008) and under the Internal Electricity Market directive (2009). In the firstcase energy efficiency and renewables are exempted whereas in the second case, the state cansubsidize infant technologies or projects remedying problems of security of supply. It is hard to see
how an industry with more than half a century of commercial experience can be categorized as“infant”. Equally, given the very long lead-time for nuclear projects of a decade or more if things go toplan and up to two decades or more if they go wrong, as has frequently been the case, it is hard to see
how nuclear power could be portrayed as being appropriate to meet shorter-term concerns on securityof supply.
Draft revised guidelines for state aid for energy were due to be published for consultation in late
July 2013 at time of writing with an expectation that final guidelines would be agreed in early 2014.

Likely Outcomes in the Rest of Europe
It is clear the nuclear industry will lobby hard for favorable treatment under European legislation
because without this, its prospects in Europe are minimal. However, the impact of the Fukushimadisaster has been to change the political balance in the EU and it looks highly unlikely that a majorityof Member States could be engineered for proposals that favored nuclear power. Regardless, as with
the U.S. and the U.K., the economic fundamentals of nuclear power seem so poor that even if the“British Model” were cleared for application elsewhere, the resulting number of additional orders
would be minimal.

The Chinese Program
Whilst the U.S. and the U.K. were expected to bring credibility to the ‘nuclear renaissance’ because of
their long history and expertise in the sector, China has increasingly been seen as the market with
sufficient volume to provide scale economies and learning; to identify and deal with ‘teethingproblems’ with the new design; and to provide an efficient, cheap and high-quality supply chain forthe major components.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
183

Steve Thomas & Dörte Fouquet, “The new UK nuclear power programme – a FIT for nuclear and a blueprint
for illegal state aid?”, 2013, Greens/EFA Group – European Parliament, Brussels, Belgium.
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Old Designs
China started to order nuclear power plants in large numbers from 2008 onwards, and today 28 of
66 units under construction worldwide are in China. The Chinese program has been based mainly on a1000 MW design called M310 licensed from AREVA, which in turn had licensed it from
Westinghouse based on a design ordered before 1970. The reactors were supplied mainly by Chinese
Guangdong Nuclear Power Company (CGNPC) using its CPR1000 design, with a couple of orders
going to its competitor Chinese National Nuclear Company (CNNC) based on the same French design
as CGNPC, designated CNP1000. Even in 2008, it was clear that the M310 derived designs were too
old to be a basis for the future and plans were underway to move to Gen III+ designs. A third Chinese
vendor, State Nuclear Power Technology Corp (SNPTC), was also active but did not win any orders inthis phase. An additional issue was that the designs were still under license to AREVA who are notwilling for China to export such reactors.

Gen III+ Designs
China ordered six Gen III+ reactors in 2007–08, four from Westinghouse using the AP1000 design (incollaboration with SNPTC) and two from AREVA using the EPR design (in collaboration withCGNPC/EDF). This was a major plus for the Western vendors because it was expected to provide a
shop-window for the new designs and, because it was China, the reactors would be built to time andapparently to cost. The expectation was that the AP1000 rather than the EPR would take over as themain design for reactors built in China supplied under license by local companies. However, as
estimated costs of these designs escalated in China as well as the West, there was an increasing
perception that these designs were too expensive for China. There are also reports of construction
delays of about a year and cost overruns with the AP1000s. And around the time when Kang Rixin,
the head of CNNC, was arrested on corruption charges in 2009 (he was sentenced to life imprisonmenta year later), press reports suggested he may have accepted bribes from a foreign reactor vendor.184
When the Fukushima disaster occurred, there were already signs that the ordering rate of up to ten
reactors per year was putting unsustainable strains on the Chinese nuclear supply chain, and in thethree months up to the Fukushima disaster, no reactor construction starts took place. After the
Fukushima disaster, a halt to new reactor starts was called and not lifted until November 2012. Then
construction started on two more reactors of the old 1000-MW design, and a month later on two
demonstration plants using the pebble bed modular reactor design.185 However, by the end of April
2013, no further construction starts had taken place in China and it seems clear that China has not
returned to the days of ten reactor orders per year.
For the future, the prospects for large numbers of orders of AP1000s and EPRs in China appear to bereceding, and the three Chinese vendors are all reported to be developing their own Gen III+ designs.
CGN is working with AREVA to develop a 1000-MW design, designated ACPR1000; SNPTC is
working with Westinghouse to develop a scaled up AP1000, designated CAP1400; and CNNC isdeveloping its own design which would be entirely independent of foreign vendors, ACP1000.
How close these designs are to deployment is difficult to tell, and whether they would satisfy an
experienced Western regulator like the U.S. NRC is hard to know. Equally, it is too early to tellwhether these designs would prove significantly cheaper to build than AP1000 and EPR.
Development of the ACP1000 appears to be ahead of the other two designs. In April 2013, it wasreported that the design had passed an “authoritative industry evaluation” and was on par with Gen III
designs elsewhere.186 This is clearly not equivalent to the generic design assessment process carried
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

184

RFI, “L’ex-patron du nucléaire chinois condamné à la perpetuité”, 19 November 2010, see
http://www.rfi.fr/asie-pacifique/20101119-ex-patron-nucleaire-chinois-condamne-perpetuite, accessed
8 July 2013.
185
http://www.worldnuclearreport.org/Reactor-Building-Starts-Again-in.html Accessed May 13, 2013
186
Xinhua General News Service, “China's self-developed nuclear reactor passes industry evaluation”,
19 April 2013.
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out by the U.S. and U.K. safety authorities, because the detailed design, which would be needed for ageneric review, was only then going to commence. It was also reported that an export sale had beenachieved, but the country involved was not named so this report must be treated with skepticism.187 A
vice president of CNNC claimed: “We have submitted an application to the International Atomic
Energy Association [Agency] for a review of the ACP1000, which will help us get the permits toexport to Europe and North America.” This suggests a naivety about the Western regulatory processes,
as the IAEA has no jurisdiction over national safety issues and a positive verdict by the IAEA would
have little impact on national safety authorities’ verdicts.188
Nevertheless, reports did suggest the design would be ready for start of construction by the end of
2013, and with 85 percent indigenous content, would be 10 percent cheaper than foreign Gen III+
designs.

Relevance of Chinese Experience
With much of the recent experience of nuclear construction taking place in China particularly withGen III+ designs, it is important to determine how much can be learnt from this experience. The
majority of plants built recently use an old design closely based on the one used for the 34 900-MW
reactors completed in France during 1977–1987. Most of these were built largely to time, though theconstruction period did keep lengthening, and experience in China also appears to be good in that
respect. In terms of costs, the picture in France was more complex.189 However, no useful and reliable
cost data from China have been published.
For the Gen III+ designs, there are two EPRs under construction at Taishan and four AP1000s, two at
Sanmen and two at Haiyang. The EPRs started construction in October 2009 and April 2010. There is
no strong evidence of any delays at Taishan.190 It is clear that the Instrumentation & Control systeminstalled would not satisfy the U.K. safety regulator, which until November 2012 had not approved thedesign submitted to it (see below for a discussion of Instrumentation & Control). It is also not clear
what would have happened if the quality control issues that have bedeviled the Olkiluoto andFlamanville projects (see below) had first occurred in China.
The Haiyang reactors started construction in September 2009 and June 2010 while the Sanmen
reactors were started in April and December 2009. While Westinghouse claimed in early 2012 that theoriginal schedule of completion of the first unit at Sanmen before end 2013 can still be met191, there
are industry reports that all of the Haiyang and Sanmen units are to start up “in 2014 or 2015”192.
Overall, whilst the apparently smoother progress with these Gen III+ designs in China certainly serves
their reputation, until Chinese experience is more clearly and independently documented and theregulatory process is more open, it would be dangerous to read too much into this experience. Basic
cost factors also differ markedly: a common remark in the industry is that Chinese reactor-builders
employ twice as many people at a tenth the salary of their Western counterparts.193

Olkiluoto and Flamanville
These two projects, Olkiluoto-3 in Finland and Flamanville-3 in France, were meant to be theshowcase for Gen III+ projects. France generally had a good reputation for completing plants to time,
while Finnish reactors were also completed largely to time and have a formidable reputation for
reliability. Given the importance of these projects to the credibility of the EPR and the need to show
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
187

China Daily European Edition, “Nuke reactor gets foreign contract”, 20 April 2013.
China Daily European Edition, “Nuke reactor gets foreign contract”, 20 April 2013.
189
Arnulf Grübler, “The costs of the French nuclear scale-up: A case of negative learning by doing“, Energy
Policy 38, 2010, 5174–5188.
190
Nucleonics Week, “Heavy component installation finished at Taishan-1”, 24 January 2013.
191
Nucleonics Week, “AP1000 in China to start up as scheduled: Westinghouse”, 2 February 2012.
192
Nuclear Energy Institute, “Nuclear Energy Overview”, 26 April-2 May 2013.
193
Amory B. Lovins, personal communication, 7 July 2013.
188

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that the problems of cost and time control that earlier generation reactors had suffered, there was astrong expectation that enough resources would be devoted to these projects to ensure theirconstruction went smoothly. In fact, closer examination of the French record would have led to someconcerns. Experience with the EPR’s predecessor design and the design it was developed from, theN4, was extremely bad. The four reactors of this design built took on average 14 years fromconstruction start to commercial operation and their costs were also very high.194 The N4 was the firstindigenous French design while the previous models were built under Westinghouse license. And
equally seriously, the French constructor’s latest construction start was in 1991—long enough before
to have lost a whole generation of experienced managers for such complex projects. This as much asother factors—such as the dozens of main languages spoken by the highly international workforce,and cultural and procedural mismatches between the French designer/builders and the Finnish safety
regulator—proved to be the project’s undoing despite Finland’s well-earned reputation for engineering
prowess and general competence.

Olkiluoto-3
As has been amply documented, these projects have gone wrong on a scale exceptional even for
nuclear projects. The latest estimates for Olkiluoto suggest that the reactor, which was expected atconstruction start to take four years to build and cost €3 billion, will take at least 11 years (completionin 2016) and cost at least €8.5 billion. With three years of construction still left, there can be little
confidence that there will not be further cost and time overruns (see Table 2).
A large number of issues, in particular quality-control problems, have contributed to the delays (seeprevious editions of the World Nuclear Industry Status Report), so there is no simple fix. For futurebuyers of the EPR, there can be no confidence that relatively simple changes to project management
can remove the risk that projects will go badly wrong.

Flamanville-3
By the time construction at Flamanville-3 began, a rationale was emerging that the problems at
Olkiluoto were due to Finland’s lack of experience with nuclear construction, and to AREVA’s lack ofproject management experience195 and the shortage of relevant skills. In France, with EDF’s vast
experience of nuclear construction and its wealth of relevant skills, the problems would not recur.
However, as with Olkiluoto, problems emerged immediately with errors in the pouring of the firststructural concrete.196 As with Olkiluoto-3, no single, particular issue was behind the delays andtherefore no easy lessons emerge for future customers for the EPR to learn. It seems clear the
Flamanville project is going wrong just as badly as the Olkiluoto project and perhaps worse (seeTable 2).
	
  

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

194

Arnulf Grübler, “The costs of the French nuclear scale-up: A case of negative learning by doing “ Energy
Policy 38, 2010, 5174–5188.
195
OL3 is actually the first time that AREVA has overall project responsibility. In the case of all previous
French nuclear construction projects, inside and outside the country, EDF was the architect.
196
Nucleonics Week “Concrete pouring at Flamanville-3 stopped after new problems found”, May 29, 2008
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World Nuclear Industry Status Report 2013

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Table 2: Evolution of EPR Cost Estimates 2003-2012
Origin of Estimate

Construction Costs (€/kW)197

Production Costs(€/MWh)

DGEMP 2003198
EDF 2005200
EDF 2005202
EDF 2006204
AREVA 2007205
DGEC 2007207
EDF 2008208
Cour des Comptes 2012210
EDF 2012211 [U.K. EPR]
EDF 2012213 [Finland EPR]
EDF 2012214 [France EPR]

1,043 (1,274 €2012)?
?
2,063 (2,331 €2012)
1,300–1,800 (1,498–2,074 €2012)?
2,500 (2,677 €2012)
3,700 (3,874 €2012)
5,400 €2012
5,300€2012
5,300€2012

28.4199 €uro2001(33-)41201 €uro2004(35-)43203 €uro2004
46 €uro2005
29.9206 €uro2004
44.9 €uro2007
54-60209 €uro2008
70-90 €uro2010
110-166212 €uro2012?
?

Sources: As indicated, assembled by MSC

Instrumentation & Control
A particular issue that has caused regulatory concern has been the level of redundancy in theInstrumentation & Control (I&C) system. As far back as 2004, there were small delays in AREVA’s
supplying the Finnish regulator with details of the design of the I&C, which was to be entirely
digital.215 There continued to be apparently small issues arising on the I&C and in 2006, it became

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

197

Figures in brackets are adjusted for inflation.
DGEMP, “Coûts de référence de la production d’électricité”, Ministère de l’Industrie, 2003.
199
Equivalent to 29.9€2004/MWh, according to EDF.
200
Serge Massart, Goulven Graillat, “La place d’EPR dans la stratégie d’EDF”, EDF, in Revue Contrôle,
May 2005.
201
41€ pour la tête de série, 33€ pour une série de 10 réacteurs.
202
EDF, “Projet Flamanville 3 – Construction d’une central électronucléaire ‘tête de série EPR’ sur le site deFlamanville”, Dossier Débat Public, CPDP, July 2005.
203
43€ pour la tête de série, 35€ pour une série de 10 réacteurs.
204
EDF, “Investor Day”, London, 4 December 2008.
205
Anne Lauvergeon, “Le nucléaire, un des atouts maîtres dans la nouvelle donne énergétique mondiale”,
Réalités Industrielles, February 2007.
206
Equivalent to 28.4€2001/MWh.
207
According to Cour des Comptes, “Les coûts de la filière électronucléaire”, January 2012.
208
EDF, “Investor Day”, London, 4 December 2008.
209
Low estimate Flamanville-3 case; high estimate potential additional costs inherent to the site.
210
Cour des Comptes, “Les coûts de la filière électronucléaire”, January 2012.
211
The Times, “Soaring costs threaten to blow nuclear plans apart”, 7 May 2012.
212
Citigroup; “New Nuclear in the UK – It isn’t getting any easier”, 8 May 2012.
213
Kauppalehti.fi, “Olkiluoto kolmonen maksaa 8,5 miljardia”, 13 December 2012, see
http://www.kauppalehti.fi/etusivu/olkiluoto+kolmonen+maksaa+8,5+miljardia/201212321921, accessed
8 July 2013.
214
Le Figaro, “EDF: la facture de l’EPR s’envole de 2 milliards”, 4 December 2012, see
http://www.lefigaro.fr/societes/2012/12/03/20005-20121203ARTFIG00635-la-facture-de-l-epr-s-envole.php,
accessed 8 July 2013.
215
Nucleonics Week, “I&C data lagging slightly for STUK safety analysis of new EPR”, January 29, 2004
198

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clear the Finnish and French regulators were imposing different requirements with the Finnish
regulator requiring a hard-wired back-up to the digital system.216
Concerns continued and culminated in a letter in April 2009 from the U.K. regulatory authority to
EDF and AREVA expressing its concern about the adequacy of the redundancy in the I&C system.217
The Finnish regulator voiced similar concerns in July and in November 2009, the French, Finnish andU.K. regulators wrote jointly to AREVA expressing their worries.218 The French authorities were still
not expecting to require a hard-wired back-up but the U.S. authorities, who had launched their genericreview a couple of years before, were also asking questions. In 2010, AREVA modified its U.S. EPR
design to include a hard-wired back-up in response to issues raised by the U.S. NRC.219
In December 2011, when the U.K. safety regulator, Office of Nuclear Regulation (ONR) issued an“Interim Design Acceptance Certificate” (IDAC) for the EPR, six of the 31 issues still to be resolved
concerned the I&C system. The ONR forecast that these issues could be resolved in a year. However,progress with I&C seemed slow. The ONR introduced a “traffic light” system to indicate the status ofthese issues in their quarterly progress reports. In the report for the period to end June 2012, four outof six of the issues were given a “red light” signifying that “closure of the GDA Issue is in serious
doubt with major risks apparent”, while the other two were given an amber light—“closure of the
GDA Issue appears feasible but significant risks exist requiring prompt attention.”220 By the end of thenext quarter, one of the issues had been completely resolved, three were given green lights—“Closureof the GDA Issue appears highly likely”, one was given an amber light, and one still had a red light.221
However, in December 2012, the ONR announced all issues had been resolved.222 It is not clear how
an issue that had been causing serious concern for more than three years and which in June 2012
appeared nowhere near resolution could be resolved so quickly. This is especially puzzling given that
there appears no agreement in sight on how the Finnish regulators can be satisfied.223
In April 2012, the French regulator announced that it was satisfied with the solution offered by
AREVA and lifted the hold it had placed on the design of the system placed in October 2009.224 While
the French solution was reported to require an element of hard-wired back-up, it was not as extensive
as the U.K. and Finnish regulators are requiring. China is reported to be adopting whatever system isapproved for Flamanville, although it is not clear whether this was finalized in time for installation at
Taishan.225

Conclusions on Nuclear Economics
Making significant improvements to the economics of nuclear power plants was central to thepromises of the ‘Nuclear Renaissance’. Simplification of the designs was meant to reduce both thecost and the risk of problems in the construction phase. By making construction more predictable, thiswas expected to make nuclear projects less economically risky and therefore easier and cheaper tofinance. These promises are in tatters with cost estimates now roughly seven times the level predicteda decade ago and the two projects underway in the West using Franco-German EPR technology
massively over budget and time. Early experience with the two projects recently stated in the U.S.
using AP1000 technology gives little confidence that these problems are restricted to the EPR.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
216

Inside NRC, “DGSNR says license for EPR at Flamanville-3 'months' away”, May 15, 2006
http://www.hse.gov.uk/newreactors/ri-ukepr-0002.pdf, accessed April 30, 2013
218
Nucleonics Week, “Regulators from France, UK, Finland share concerns about EPR's I&C”, November 5,
2009219
Nucleonics Week, “AREVA agrees to modify US-EPR after NRC raises I&C concerns”, July 1, 2010220
http://www.hse.gov.uk/newreactors/reports/gda-q2-12.pdf accessed April 30, 2013221
http://www.hse.gov.uk/newreactors/reports/gda-q3-12.pdf accessed April 30, 2013222
http://news.hse.gov.uk/onr/2012/12/uk-regulators-confirm-acceptance-of-new-nuclear-reactor-design/accessed April 30, 2013
223
Nucleonics Week, “Olkiluoto-3 EPR likely not to operate before 2016: TVO”, 14 February 2013.
224
Nucleonics Week, “ASN lifts hold on Flamanville-3 I&C architecture”, 19 April 2012
225
Nucleonics Week, “Olkiluoto-3 EPR likely not to operate before 2016: TVO”, 14 February 2013.
217

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Largely as a result, what were probably the three key markets to crack—the U.S., the U.K. andChina—now look very restricted whilst other major and previously influential potential markets like
Germany and Italy are closed to nuclear or, like India, remain—perhaps—a potential market for
tomorrow. Both the U.S. and the U.K. now appear likely to build fewer than a handful of new reactors,
while China has slowed down the pace and appears likely to opt for its own rather than Western
designs.
With the credibility of Gen III+ designs in serious doubt and little significant progress made on their
expected successor designs, so-called Generation IV, the nuclear industry is seeking funding for new
design concepts, such as Small Modular Reactors (SMRs). Experience suggests that after significant
amounts of public money have been spent on these, they will probably turn out to have no significant
advantages over existing designs. One analyst, having long asked in vain for SMR advocates toprovide a production-cost and economic analysis demonstrating their claimed advantages, summarizes
their key issue thus: “As a matter of physics, reactors don’t scale down well; that’s why they’re big. If
you try to overcome this handicap by capturing economies of mass production, you quickly run up
against a fatal competitor called Small Modular Renewables (and efficiency techniques). Those doscale down very well; they currently outcompete new reactors by severalfold; and they’re alreadydecades ahead of SMRs in exploiting their mass-production economies (they’re attracting a quartertrillion dollars of private investment per year), and will be another decade ahead by the time an SMR
could be demonstrated. So SMRs might have been worth considering a half-century ago, but today
they’re far too late. End of story.”226
The U.K. Government is considering guaranteeing a profit range for nuclear investors in the form of a“Contract for Difference” (CFD). However, making up for the difference between the current baseload
power on the market and the estimated cost range of 110–166 €uro per MWh (the “strike price”)
would be difficult to sell for the Government. A Citigroup analysis227 wonders:
Transfer Construction Risk?: if construction costs are rising, then the only way to contain the rise in the
strike price is to reduce the risk faced by the developer and thereby lower their cost of capital. In practicethis means transferring the construction risk to the taxpayer / consumer. On the face of it the CFD
arrangement is not designed to tackle construction risk allocation so some other mechanism will beneeded alongside the CFD. If the government shoulders all of the construction risk then a cost of capital
below 10 percent is feasible; but the government would be taking on a huge risk over which it has little
control.
Conclusion: if construction costs are indeed anything like £7 billion per reactor, then an already very
challenging programme may be reaching the point of impossibility in our view.

Citigroup’s analysis resonates interestingly with the May 2012 statement by Energy Secretary Ed
Davey when introducing the draft energy bill that would pave the way for a CfD scheme:
Unless nuclear can be price competitive, as the industry says it can be, unless it can be price competitive,these nuclear projects won’t proceed.228

The bill, in contrast, apparently seeks to ensure nuclear new-build regardless of its economic merit.

Financial Markets and Nuclear PowerElectricity utilities in many parts of the world are facing significant economic and financial problems.
These problems are, in most OECD countries, as a result of low demand increases, often withaccompanying lower market prices, uncertainties over carbon markets and pricing, greater demand andsupply interventions from government to address concerns over climate change and energy security,
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

226

Amory B. Lovins, personal communication, 6 July 2013; see also “‘New’ nuclear reactors, same old story,”
2009, www.rmi.org/Knowledge-Center/Library/2009-07_NuclearSameOldStory
227
Citigroup; “New Nuclear in the UK – It isn’t getting any easier”, 8 May 2012.
228
BBC, “Energy bill avoids carbon pledge”, 22 May 2012, see http://www.bbc.co.uk/news/scienceenvironment-18146940, accessed 22 May 2012.
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volatile global energy prices and higher costs of capital. These conditions have led many analysts topredict a gloomy future for utilities.
Nomura says of the current situation in Europe that “there is no let-up in the dire outlook for
utilities”229. The situation in Europe is particular acute for utilities in Europe, due to the significant
increase in the use of renewable energy, at a time of flat demand, which is squeezing out thetraditional utilities and investors. Worse, having almost no running cost, renewables in competitive
power markets drive down the market-clearing wholesale price—which just hit new lows inGermany—and thus force fossil-fueled and even some nuclear plants to operate fewer hours, sell their
output for a lower price, and thus earn lower, zero, or negative profits. According to Moody’s:
Large increases in renewable energy have had a profound negative impact on power prices and thecompetitiveness of thermal generation in Europe. What were once considered stable companies have seen
their business models severely disrupted. Given that further increases in renewables are expected, thesenegative pressures will continue to erode the credit quality of thermal based utilities in the near to
medium term.230

While in North America it is primarily the rise in production from shale gas in the last few years thathas had a significant impact on the U.S. utility sector and in particular on the traditional central
thermal power plants, primarily coal and nuclear. Moody’s stated in February 2013 that there was still
no sign of recovery for the unregulated utilities due to low gas prices’ depressing electricity prices.
Furthermore, they state “the low natural gas prices make operating coal and nuclear power lesscompetitive because their fixed costs are relatively high”.231 However, gas is not the only formidable
competitor: wind power, recently selling 25-year fixed-price power for around $22/MWh in the U.S.
Midwestern ‘Windbelt’ net of its $18–28/MWh Production Tax Credit, combined-heat-and-power,
and efficient use of electricity are all helping to drop power prices.
The impact of these conditions was seen in early 2013 with the retirement of the Kewaunee nuclear
power plant, which was described by UBS as potentially “the figurative canary in the coal mine”. UBS
further stated that232 :We believe what started as a focus on coal plant retirements has been expanding into growing risk ofretirement of all fuel types, particularly nuclear and oil-fired units.

However, in North America it is not just the rise in shale gas and wind power that is making current
capacity less profitable or unprofitable to operate; renewables are fundamentally threatening utilities’
business model with ‘radical bypass’, much as mobile telephones bypassed wire-line telephonecompanies and stranded their assets. 233 For example, in more than 20 of the United States,
entrepreneurs offer to install solar power on your roof with no down payment and beat your utility bill;this is expected to spread to most other states within the next few years. The Edison Electric Institutepublished a report on the disruptive challenge of new technologies, particularly small scale renewables
and storage, on the electricity utility sector and concluded that “recent technological and economicchanges are expected to challenge and transform the electric utility industry” and that “while thevarious disruptive challenges facing the electric utility industry may have different implications, they
all create adverse impacts on revenues, as well as on investor returns234 ”. In the United States revenues
from retail sales in 2012 were at the same level as in 2007.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

229

Nomura, “Utilities sector Outlook – 2013”, December 2012
Moody’s, “European Utilities: Wind and Solar Power Will Continue to Erode Thermal Generators’ Credit
Quality”, 5 November 2012231
Moody’s, “Moody's: Still no sign of recovery for unregulated utilities; regulated remain stable”,
6 February 2013.
232
UBS, “ Re-evaluating Merchant Nuclear”, UBS 2nd January 2013.
233
Amory B. Lovins, 9-page feature (article, interview, and retrospective), Public Utilities Fortnightly,
March 2013.
234
EEI, “Disruptive Challenges: Financial Implications and Strategic Responses to a Changing Retail ElectricBusiness”, Edison Electric Institute, January 2013.
230

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As can be seen in Figure 14, the majority of the major utilities across the various continents havesuffered loss of income in the past few years. Of the 13 companies measured, only four have shown agrowth in earnings, two of them in the U.S., SCE (Southern California Electric) and NextrEra(formerly Florida Power and Light Company), while there have been slight increases or stagnation in
Europe from Germany’s E.ON and France’s EDF. The earnings of the U.S. utilities have benefited
from relatively low fossil fuel prices. In 2012 coal prices for the power sector fell by 2.1 percent,while the price of gas did increase, they are still significantly lower than a decade ago. While the retailprice for electricity across all types of consumers (residential, commercial, industrial and transport)
increased on average, between 2012 and 2013, by 12 percent.235
Not surprisingly there have been major falls in income in Japan, in this case Kansai Electric Power
Company and TEPCO, the owner of the Fukushima nuclear power plant, which along with all but two
Kansai reactors has been closed for nearly a year. KEPCO, of South Korea, while showing positive
earnings in 2009 and 2010, has seen losses since 2011.
Figure 14: Annual Growth Rates of Earnings of Major Nuclear Companies 2008-2012

Source: Financial Times 2013

The utility sector is finding it increasingly difficult to attract investment. A global survey by PWC
found that many utilities are facing a reduction in capital raising options, with 78 percent of thosesurveyed reporting that the financial crisis and economic downturn have had a medium to very highimpact on shortage of capital for infrastructure projects, and 63 percent saying it has had a high orvery high impact. Somewhat surprisingly, PWC found that shortage of capital for infrastructure
projects is felt even more acutely among companies in Asia, the Middle East and Africa than in North
America and Europe236 .
The perception of a higher financial risk associated with nuclear power is important as it can lead to ahigher interest rate at which utilities can borrow, and therefore significantly raises the final cost of
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
235

US EIA, “Electricity Data”, US Energy Information Administration, accessed June 2013,
http://www.eia.gov/electricity/data.cfm#avgcost, accessed 11 June 2013.
236
PWC, “The shape of power to come, investment, affordability and security in an energy-hungry world”, the12th Pricewaterhouse Coopers Annual Global Power and Utilities Survey, 2012
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construction. This is why investment institutions, such as Citibank, have stated: “Due to theuncertainties on timing and cost, we believe nuclear projects should have a higher ERP [Equity risk
premium] than the overall market”237 and more recently have stated on the situation in the U.K. that "if
the latest cost figures are true, new nuclear power plants in the U.K. are not commercially viable… the
only way they could be built is if the construction risk was transferred to the taxpayer”.238
As a result nuclear power is perceived as a higher risk investment than other conventional electricitygenerating sources, particularly gas. Even amongst the major utilities, gas ranks the most likely new
projects, with 55 percent making major or very major investments versus 37 percent onshore wind,
24 percent offshore wind, and only 21 percent for new coal and nuclear generation.239
Most utilities do not have the financial capabilities to finance new nuclear build solely with their own
balance sheets: to do so could place the entire company at risk. Therefore the companies need toborrow. However, with nuclear projects having high capital costs, long construction times and a bad
construction track record, the financial risks and therefore the borrowing costs are high. This is one
reason why nuclear projects often involve financing through export credit agencies and why somegovernments, such as the U.S., make available loan guarantees to lower the cost of borrowing.240
Figure 15: Compound Annual Growth Rate of Debt levels of Major Utilities 2008–2012

Source: Financial Times 2013

Since 2008, only one of the companies analyzed in Figure 15, E.ON, has decreased its debt levels,
while all 11 other companies have seen an increase in debt. Over the past year E.ON has made aconcerted effort to reduce its engagement in new investment across Europe. This has included thesales of its share of Horizon, a company established with RWE to build a nuclear power station in the
U.K., and in October 2012 the announcement it was selling its 34 percent stake in the Fennovoimma
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
237

CitiBank, “New Nuclear – The Economics Say No”, November 2009
Reuters, “UK nuclear build requires taxpayer rescue –Citi”, 8 May 2012
239
PWC, “The shape of power to come - Investment, affordability and security in an energy-hungry world”, the12th Pricewaterhouse Coopers Annual Global Power and Utilities Survey, 2012
240
UCS, “Nuclear Loan Guarantees – Another Taxpayer Bailout Ahead?” Union of Concerned Scientists, March
2009
238

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nuclear projects where the plans were to begin construction of a 1,600 to 1,800 MW reactor at
Pyhaejoki in northern Finland in late 2016241.
The higher debt level of the utilities will make it particular difficult for these important firms to invest
in large, risky and long-term projects, which will affect investment in nuclear power.
Figure 16 shows the relative share price performance of twelve utilities across Europe, Asia and North
America, and compares them to the S&P Global 100 index, which measures the performance of
100 global companies that derive a substantial portion of their operating income from multiple
countries.
Figure 16: Share or Bond Prices of Major Utilities in Key Regions 2008–June 2013 compared to
S&P Global 100

Source: Yahoo Finance, Accessed June 2013

Nuclear companies are not the only energy sector whose share prices have fallen. Changes ingovernment policies have also had a significant impact on the prices of renewable energy companies.
Uncertainties over the relative prices of fossil fuels, particularly relating to reductions in demand
resulting from the economic downturn, have led to reductions in the values of many other majorenergy companies. However, as the next chapter illustrates, the renewable energy sector is rather
subject to a shift between companies, and continues overall to retain very substantial growth figures.
Since 2011, the share or bond prices of North American companies have diverged from those inEurope and Asia despite increasing indebtedness amongst all four companies shown, and a decline inrevenues from both PG&E and TVA242. The share prices of North American companies, Southern
California Edison, NextEra Energy, TVA and PG&E have either tracked or outperformed the S&P
Global 100 Index. However, Exelon, operating 20 per cent of the U.S. nuclear fleet, has seen theperformance of its stock prices track more closely to the European and Asian utilities.
AREVA, Hitachi-GE, Toshiba Power Systems, and Mitsubishi Heavy Industry are the major nuclear
vendors; of these only AREVA is an almost purely nuclear stand-alone nuclear constructor. HitachiGE is a joint venture between the two firms, while Toshiba Power Systems is a subsidiary of Toshiba,
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

241

Bloomberg, “EON Withdraws From Finnish Nuclear Project on Price Slide”, 24 October 2012
Although TVA isn’t a public traded company, its bonds are traded on the New York stock exchange, see
http://www.snl.com/IRWebLinkX/GenPage.aspx?IID=4063363&GKP=205782
242

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and Mitsubishi Heavy Industries is a subsidiary of Mitsubishi, a group of autonomous companies.
Figure 17 shows the share price of these highly diversified companies or their parent companies andcompares them to the global average. What is important to note is the extent to which all of theseelectrical and heavy electrical firms have performed below the global average. However, AREVA, apurely nuclear company, has had a significantly worse performance over the past five years, with its
share price just 20 percent of that of 2008.
The fall in share value for AREVA is reflected in the company’s credit rating (defined in Annex 3),
which, according to S&P, was cut in December 2011 to BBB-, as they believed that “credit metrics
and free cash flow to remain very weak in 2012, with a substantial recovery only in 2014, two years
later than we previously assumed”.243 With net losses in the second half of 2012, at €179 million244,
the group will have to see a significant upturn in its fortunes to see a upgrading of its credit rating.
Figure 17: Share Price of major nuclear vendors, 2008-13, Compared to the S&P Global 100

Source: Yahoo Finance, Accessed June 2013

Rating agencies, of which there are three major institutions, Moody’s, Standard and Poor’s (S&P) and
Fitch, assess the financial strength of companies and governmental entities and their ability to meet theinterest and principal payments on their bonds and other debts. (See Annex 3 for rating definitions).
The ratings given can affect the interest rates at which a company is able to borrow and therefore is an
important factor for utilities’ ability to fund nuclear and other projects through external investment. A
Moody’s analyst was quoted in the energy trade press in March 2012 as stating:
The risks are writ larger when you think of a nuclear project [than for other forms of generation], because
construction and planning is that much more tortuous, construction risk is higher and from an operational
point of they have a high fixed cost base.245

Another utility analyst stated:
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
243

Bloomberg, “AREVA Credit Rating Cut to BBB- by S&P on Weak Cash Flow”, 20 December 2011
Bloomberg, “AREVA – information page”, http://www.bloomberg.com/quote/AREVA:FP, accessed
June 2013.
245
ICIS Heren, “New nuclear electricity costs hit utility ratings - Moody’s”, 27 March 2012,
http://www.icis.com/heren/articles/2012/03/27/9545356/power/edem/new-nuclear-electricity-costs-hit-utilityratings---moodys.html, accessed 11 June 2013.
244

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If [a utility] is already on the edge of a ratings band, a nuclear project could be the thing that pushes themover the edge—it's just another negative factor.246

Of the utilities surveyed, only one, Korea Electric Power Co. (KEPCO), has received a ratings upgradefrom S&P. 247 In the rational for this upgrade, S&P state that the “potential extraordinary support”
from the Government of the Republic of Korea in the event of financial stress would be “extremelyhigh”. This upgrade the highlights the important role that Government support plays in many nuclear
operators ability to secure finance. In essence, KEPCO, like EDF and TVA, is being rated more on its
government’s than on its own stand-along creditworthiness.
As can be seen in Table 3, other than KEPCO, all utilities examined that have nuclear interests acrossthe world continue to be static or downgraded by S&P. In some cases this relates to specific events,
such as Fukushima or it may be a reflection of the general problems facing the electricity sector. July2012 saw the downgrading of Germany’s two largest utilities, RWE and E.ON, driven by declines inwholesale power markets, and the divestment from nuclear energy following the acceleration of thenuclear phase out in Germany. S&P also note that the increasing share of renewable energy has
pushed many of the company’s traditional thermal plants down the merit order: : they run fewer hours
and take lower prices in Europe’s competitive power markets.248
Table 3: Long Term Credit Ratings of Utilities with Nuclear Investments
Company

Date oflast action

2013
June

2012
June

2011
June

2011
April

2010

2009

2008

European Union

CEZ
EDF
E.ON
ENEL
GDF-Suez
RWE
TVO

Oct 2006

A-

A-

A-

A-

A-

A-

A-

Jan 2012

A+

A+

AA-

AA-

A+

A+

AA-

July 2012

A-

A

A

A

A

A

A

Mar 2012

BBB+

BBB+

A-

A-

A-

A-

A-

July 2008
July 2012
June 2012

A
BBB+
BBB

A
ABBB

A
A-

A
A-

A
A

A
A

A
A

AA

AA

AA

AA

Asia, South Africa, USA
249

Kansai
KEPCO
TEPCO
ESKOM
SCE
PG&E
FLP
TVA

May 2012

AA-

AA-

AA-

Sept 2012

A+

A

A

A

A

A

A

May 2012

B+

B+

B+

BBB+

AA

AA

AA

Sept 2012

BBB

BBB+

BBB+

BBB+

A-

A-

A-

Feb 2005

BBB+

BBB+

BBB+

BBB+

BBB+

BBB+

BBB+

Dec 2011

BBB

BBB

BBB

BBB+

BBB+

BBB+

BBB+

Mar 2010

A-

A-

A-

A-

A

A

A

Aug 2011

AA+

AA+

AA+

AAA

AAA

AAA

AAA

Sources: S&P, Financial Times, Reuters, Company websites and Annual Reports 2013250

In addition to the general trends, there have been a number of notable recent judgments by the rating
agencies on nuclear power. For example, in the U.K., the announcement that Centrica would not
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

246

ICIS Heren, “Nuclear electricity investment could risk utility credit ratings – analysts”, 20 March 2012,
http://www.icis.com/heren/articles/2012/03/20/9543406/power/edem/nuclear-electricity-investment-could-riskutility-credit-ratings--analysts.html, accessed 11 June 2013.
0247 Standard and Poor’s, “Korea Electric Power Corp”, http://www.standardandpoors.com/prot/ratings/entityratings/en/eu/?entityID=269949&sectorCode=UTIL, accessed 3 July 2013.
248
Reuters, “S&P cuts German Utility E.ON to 'A-/A-2';outlook stable”, 27 July 2012.
249
Moody’s rating cited because Kansai is not rated by S&P.
250
Based on research by John Corbett, London, commissioned by MSC.
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exercise its option to take a 20 percent interest in the construction of new nuclear plants in conjunction
with its partner EDF Energy, led Moody’s to state:This decision is credit positive because it removes the high investment and construction risks that would
have resulted from the project. The costs, according to the company, were uncertain and the construction
251
timetable had lengthened by a number of years since Centrica's original investment in 2009.

Likewise in April 2012, RWE and E.ON announced that they would no longer proceed with theirplans to build nuclear power in the U.K.. The reaction of Moody’s investor service was again credit
positive:
The companies’ decision to pull out of their U.K. nuclear joint venture, known as Horizon Nuclear
Power, is credit positive for both German utilities, which can instead focus on investment in less risky
252
projects .

In its rating rationale for the Czech utility CEZ in May 2013, Moody’s stated that important factors in
its credit downgrade is the fall in electricity prices and the decline of nuclear energy as the marginal
producer. Moody’s noted that electricity prices have fallen in Central and Eastern Europe due to lowcost renewables and weak demand for electricity in the region, which has pushed higher-cost plants
down the merit order, including “fixed cost” lignite, nuclear and hydro power plants. As a result, many
nuclear power plants are not price-competitive with renewables, placing considerable financialpressure on their operators. Further, Moody's comments that the strategy to develop new nuclear units
could put further downward pressure on the group’s credit rating, due to the financial burden of theCapex requirements. 253 In relation to CEZ’s credit profile, S&P notes that “...although nuclear
electricity generation is favorable as a low carbon-emission generation source, we believe that it
introduces significant construction, operating, and market-exposure risks, especially in volatileliberalized energy markets.”
The ongoing construction problems at the Finnish Olkiluoto-3 reactor have significantly affected theviews of the rating agencies on the utility Teollisuuden Voima Oyj (TVO).
Table 4 shows the extent to which in the past few years the cost over-runs have harmed the rating of
the utility, taking its Fitch rating from A- to BBB.
Standard & Poor’s rated TVO BBB in 2012 and argued that risk was linked to operating as well as tonew-build reactors: “TVO's dependence on its current two nuclear plants in Finland exposes thecompany to asset concentration risk, primarily disruption of operations” and “we expect that TVO's
financial risk profile will continue to be negatively affected in the near to medium term by the large
investment in the new nuclear plant” (Olkiluoto-3). Standard & Poor’s does not exclude further downrating, arguing that ratings could be negatively affected if TVO’s liquidity position weakened, forexample if the company's net cash outflows were higher than expected primarily related to theconstruction of Olkiluoto-3. 254
Construction delays and cost over-runs have also affected the credit rating of EdF in France. In
December 2012, following further announcements of the cost increases for the Flamanville-3 project(to €8.5 billion) and a ruling by the Conseil d’Etat on the tariff for distribution of electricity, Moody’s
investment services changed from stable to negative the outlook on the Aa3 senior unsecured ratingsof EdF255.
	
  
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

251

Moody’s, “Centrica's Withdrawal from New Nuclear Plants Is Credit Positive” 7 February 2013.
I-nuclear, “Moody’s says German withdrawal ‘credit positive’; decision gives EDF bargaining power”,
2 April 2012, http://www.i-nuclear.com/2012/04/02/moodys-says-german-withdrawal-credit-positive-decisiongives-edf-bargaining-power/, accessed 11 June 2013.
253
Moody’s, “Credit Opinion: CEZ”, 14 May 2013.
254
Standard & Poor’s, “Ratings Direct, Teollisuuden Voima Oyj”, 28 June 2012255
Moody’s, “Moody’s changes outlook on EDF’s Aa3 rating to negative from stable”, 5 December 2012
252

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Table 4: Fitch Rating for Teollisuuden Voima Oyj (TVO) during 2009–2013
Date

Rating	  June 2009	
  

A-	
  

June 2010	
  

A-	
  

June 2011	
  

A-	
  

June 2012	
  

BBB+	
  

May 2013	
  

BBB	
  

Fitch Comments	
  As at May 2009, the new Olkiluoto-3 (OL3) plant is likely to be commissioned by 2012,a delay of 38 months. However, given the fixed‐price, turn‐key nature of the contract
with the AREVA‐Siemens Consortium, Fitch Ratings expects TVO’s exposure to thedelay to be relatively modest, with only a small impact on annualized production costs.	
  (OL3) to 2013 (from June 2012) to have a limited effect on TVO’s costs—with only asmall impact on annualized production costs. Fitch anticipates production costs to remaincompetitive after the commissioning of OL3 and subsequently to fall as capital costs
decrease. Fitch notes that while the OL3 project carries construction and project risks,these are largely mitigated by the fixed-price, turn-key nature of the contract.	
  The new Olkiluoto 3 (OL3) plant will be commissioned by end‐2012, a 52‐month delay.
TVO’s exposure to the delay is likely to be modest, with only a small impact onannualized production costs, as the contract with the AREVA‐Siemens consortium is a
fixed‐price, turn‐key contract.	
  The Long-Term IDR and senior unsecured ratings were downgraded in June 2012 due tothe impact on Teollisuuden Voima Oyj (TVO)’s credit profile of the continued delay incommissioning the third 1,600 megawatt (MW) nuclear plant Olkiluoto 3 (OL3). The
delay to August 2014 is of 64 months. Annual production costs will increase as a result,and while still competitive against forward Nord Pool prices, the gap between the two has
narrowed and indicates some erosion of cost advantage.	
  The downgrade reflects the continued delay in expected commissioning of the third 1,600
MW nuclear plant Olkiluoto 3 (OL3) and our weakened mid-term outlook for the forward
Nord pool wholesale electricity prices. This will erode the value creation for TVO’s
shareholders, a key consideration for our assessment of TVO’s credit profile. The delayof OL3 to 2016 is about seven years against the original schedule. The substantiallylonger than planned construction phase of OL3 is negative for TVO’s cash flows as thecompany continues to service debt related to OL3, while OL3’s full cost coverage by
TVO’s shareholders may be initiated only when the new plant is commissioned.	
  Source: Fitchrating256

In Korea, Moody’s announced in May 2013 that the scandal relating to the stoppage of operation atfour reactors as a result of the revelation that substandard parts had been used with forged test results
was credit negative for KEPCO. The reactors are not expected to restart for another 4–6 months, until
the parts had been replaced, increasing costly natural-gas imports. This is the latest announcement of
inadequate parts’ being used in the reactor fleet.257
In most regions of the world the financial situation of utilities is precarious due to changing supply
technologies, increasing policy interventions, and new consumption patterns. This is reflected in thegenerally lower ratings of major utilities, the rising debt levels, falling income, and in most regions—although currently not North America—falling stock prices. In this uncertain environment, significant
new investment in the power sector is needed, $16.8 trillion according to the IEA258, in order toreplace retiring capacity or meet future predicted increases in demand.
At one time nuclear would have been seen as an important part of this mix, but increasingly it is being
rejected by the financial community as it is by its very nature an expensive investment, due to highconstruction costs and long lead times. Its history of cost over-runs and delays has also given it areputation as a highly risky investment. As a result, in the majority of countries, nuclear power canproceed only if many of these risks are taken away from the utilities and its financial backers and put
onto customers or taxpayers—see U.K. or U.S. sections for more details.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
256

TVO Credit Ratings http://www.tvo.fi/Credit percent20ratings, accessed 11 June 2013.
Moody’s, “Moody's: Stoppages at nuclear plants; credit negative for KEPCO”, 29 May 2013
258
IEA, “World Energy Outlook 2012”, International Energy Agency
257

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Fukushima – A Status Report
On 11 March 2011, a long and strong earthquake followed by a series of once-in-1,000-years-grade
tsunami waves devastated the east coast of Tohoku, the northeastern region of Honshu, Japan’s mainisland. The earthquake and tsunami hit 14 reactors in 4 nuclear power stations on the Pacific coast,
namely from north to south, Onagawa with 3 BWR units operated by Tohoku Electric Power Co.,
Fukushima Daiichi with 6 BWRs and Fukushima Daini with 4 BWRs259, both operated by Tokyo
Electric Power Co. (TEPCO), and Tokai Daini (1 BWR) operated by Japan Atomic Power Co.
(JAPCO). Units 1 to 4 of the six Fukushima Daiichi units were devastated, resulting in massive releaseof radioactivity into the environment. The other 10 reactors escaped meltdown and radioactive releaseby a series of lucky circumstances, but they were nevertheless damaged considerably. It was also mere
fortune that the Rokkasho reprocessing plant on the Pacific coast of Aomori, 300 km north of
Onagawa, escaped major damage; it did lose all external power supplies, but emergency generators
worked to keep liquid high-level waste from boiling and thus from releasing large additional quantities
of radiation.
Concerns over the health of firemen, site workers, and some general public inside and outside of the
exclusion zone and other scheduled zones are grave, as well as the economic consequences for
200,000 refugees, utilities, government and local authorities, but remain outside the scope of thischapter.260

Characteristics of the Fukushima DisasterOn-site Challenges: Earthquakes, Station Blackout, Flooding, Explosions
TEPCO’s two nuclear stations in Fukushima had a total of about 9 GW of electricity output (Daiichi
4.7 GW and Daini 4.4 GW). Daiichi and Daini are 12 km apart, both located on the Pacific coast of
Fukushima Prefecture more than 200 km away from the offshore epicenter of the 3.11 quake.261
The devastated four reactor units of Fukushima Daiichi are all GE Mark-I BWRs. Unit-1 is of
460 MW power output and has 400 fuel assemblies, while Unit-2, -3 and -4 are each of 784 MW with
548 fuel assemblies. All the units began operation in the 1970s.	
   Unit-3 has 32 MOX fuel assemblies
loaded in 2010, of a total of 548, as first step of a one-third-core MOX program (but no irradiatedMOX fuel currently in the spent fuel pool), while others had normal uranium fuel. At the time of themain shock of the mega-quake, three reactors (Units 1–3) were operating, while the other three(Units 4–6) were shut-down for maintenance, repair and refueling. Unit-4 was in the middle of coreshroud replacement work; all the fuel assemblies had been moved to the spent fuel pool.
Seismometer signals tripped the Unit 1–3 reactors on 11 March 2011 at 14:47 JST. All of the five
powerlines that had been transmitting electricity to and from Fukushima Daiichi were destroyed by theearthquake, which left the station without external power supply. Emergency diesel generators, two

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
259

Daiichi means “The First” and Daini “The Second”; thus the stations may also be referred to as Fukushima-I
and Fukushima-II, respectively.
260
The May 2012 WHO report (see http://whqlibdoc.who.int/publications/2012/9789241503662_eng.pdf,
accessed 18 June 2013) gives a rather optimistic forecast of the health risks, whereas the May 2013 report by theSpecial Rapporteurs to the UN Human Rights Council(www.ohchr.org/Documents/HRBodies/HRCouncil/RegularSession/Session23/A-HRC-23-41-Add3_en.pdf,
accessed 18 June 2013) recommends more precautions.
261
Another nuclear plant operated by TEPCO, Kashiwazaki-Kariwa, in Niigata Prefecture on the other side of
Honshu Island, has 7 BWRs with the combined output of about 8 GW, the world’s largest concentration of
power reactors. Kashiwazaki-Kariwa had been hit by a level 6.8 earthquake in July 2007. Only 4 of the 7 units of
Kashiwazaki-Kariwa were since restarted, but the March 2011 earthquake led again to the shutdown of all
reactors. As of June 2013, no TEPCO nuclear stations are running.
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each for all of the reactor-turbine units, automatically started. Less than an hour later, the units wereoverrun by water by a tsunami wave exceeding 13 meters and all the diesel generators were flooded.262
All of the diesel generators, circuit boards, and DC263 batteries stored in the basement of the turbine
building went underwater. The doors of the turbine buildings were at 10 m above sea level, but thetsunami rose higher. The total loss of electric power, or station blackout (SBO), resulted in successive
reactor core meltdowns and melt-through events. Large amounts of hydrogen gas were generated
inside the pressure vessel as hot steam reacted with the zirconium alloy of the fuel cladding. Thishydrogen exploded later, but how the gas moved out, and exactly where it deflagrated, remains
unexplained.
Table 5 shows the latest plant parameter figures of the four Fukushima Daiichi reactors in question.
Continuous cooling is also imperative at Units 1 to 4 spent fuel pools. The irradiated fuel rods in thesefour in-house pools would otherwise overheat. Failure of the cooling and excessive build-up of decay
heat could cause a zirconium fire, and then uncontrolled release of radioactivity into the atmosphere.
The Unit-4 spent fuel pool is generally considered most vulnerable because of damage to the building,which is no longer structurally sound, and the number of fuel rods stored and their relative hightemperature.
Table 5: Spring 2013 plant parameters of Fukushima Daiichi Units 1–4264
Fukushima
Daiichi Units

Radiation inside thereactor building(mSv/h)Unit 1
Unit 2
Unit 3
Unit 423 - 11,100
5 - 72,900
10 - 4,780
0.1 - 0.6

Temperature atbottom ofpressure vessel
(°C)
≈26
≈39
≈37
n/a

Quantity ofradioactive water(tons)

Temperature ofspent fuel pool(°C)

13,90022,80020,90015,900

≈24
≈22
≈20
≈28

	
 
Radioactive emissions into the atmosphere from the three units (1, 2 and 3) continues at a rate of
10 MBq/h of cesium (= 240 MBq/day)265. This does not include the radionuclides that flow into thewaste water and the unknown direct flow into the groundwater and Pacific Ocean.

Off-site Challenges: Evacuation, Decontamination
The vast scale of the economic loss, real-estate devaluation, primary-industries damage, environmental
hazards, and the enormous personal and community sufferings caused by the Fukushima accident ishard to grasp in its totality. As of April 2013, more than 150,000 people are still forced to remain
evacuated from their communities in the restricted zones. 266 Tens of thousands of other people,
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
262

The exact height of the 3/11 wave at the Fukushima Daiichi site is unknown. It scaled out the TEPCO’s
offshore wave gauges, whose limit was ±7.5m. Since the flood reached the Unit-5 turbine building, which was
13 m above the sea level and the highest among the 6 units, the wave height is estimated as more than 13 meters.
In 2008, TEPCO had calculated a maximal possible height of a tsunami wave at Fukushima Daiichi at 15.7 m,based on the Governmental study group’s prospect (July 2002) of a M-8 class earthquake-and-tsunami on theeastern Pacific coast of Japan (see NAIIC 2012: p.54, Section 1.2.1.2-e).
263
Direct current.
264
Temperatures (pressure vessel bottom and spent fuel pools) are as of 7 May 2013; other figures are from thepress release of 16 April 2013. See www.tepco.co.jp/en/nu/fukushima-np/index-e.html.
265
TEPCO press release, 26 April 2013. It is one-sixth of the earlier estimate made by the Government(60 MBq/h, technical document in Japanese, released by the Cabinet Secretariat, 16 December 2011; see
http://www.cas.go.jp/jp/genpatsujiko/pdf/111216e.pdf). TEPCO’s figure is based on dust sampling on-site andmonitors only Cs-134 and -137. The Government 2011 figure includes inert gas estimates. There has been a
considerable variance, with occasional spikes, of Cs-134 and -137 fallout monitored in Fukushima City (60–70 km offsite) in the past six months (regular announcement on the Fukushima Prefecture official website).
266
Fukushima Minpo (newspaper), 27 March and 18 April 2013.
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especially concerned mothers with small children, had to seek voluntary refuge away from their home
towns outside contaminated zones. Many of them still live in exile with poor official support. Roughly
130,000 compensation claims have been made by individuals, corporations, trade unions, and local
governments against TEPCO267 , of which 6,000 are handled by the statutory mediator, the Center for
Dispute Resolution for Compensating Nuclear Accident (the so-called Nuclear ADR).268
The Japanese Government designated 101 municipalities (city/town/village) in eight Prefectures as aScheduled Contamination Survey Zone, where an additional radiation dose of 1 to 20 millisievert per
year (mSv/y) is predicted. Areas where the additional dose is over 20 mSv/y are designated as aSpecial Decontamination Zone. In the Survey Zone, local governments are responsible, with national
government subsidies, to conduct decontamination and/or remediation work to decrease radiation dose
rates. In the Special Decontamination Zone, a 235-km2 area in 11 municipalities of Fukushima
Prefecture, the central government is in charge of radiation remediation projects.
So far only 5 percent of the Survey Zone and 4 percent of the Special Decontamination Zone havebeen worked on.269 In the 40 Fukushima municipalities designated as Survey Zone (1–20 mSv/y), only
12 percent of the houses, 17 percent of the roads, 60 percent of public buildings (including schools andplaygrounds) 270 , 75 percent of rice fields, and 53 percent of other farmlands have gone throughremediation work. 271 It is often the case that after premises are decontaminated they becomerecontaminated due to the wind and/or water flows from the surrounding environment. There are threemain reasons why the remediation projects are badly behind schedule: technical difficulties, lack ofwaste disposal arrangements, and shortage of manpower. The Government will have to review thewhole framework of the remediation projects, particularly in the Special Decontamination Zone. If theremediation effect is little more than the rate of natural decay, which is actually the case in a numberof work areas272 , then it is no use spending a huge budget at the expense of refugees’ support.
Health concerns are increasing. We decided to exclude this issue from this short overview considering
its importance, poor survey quality and complexity. The discussion of health concerns stemming fromthe Fukushima disaster vastly exceeds the scope of this report.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

267

Japan Federation of Bar Associations, 8 June 2013.
ADR stands for Alternative Dispute Resolution. In case this officially supported out-of-court mediation fails,
claimants can go to court, but that can be a further burden for them in time, cost, and energy.
269
Mainichi Shinbun, 4 March 2013; NHK News, 17 May 2013.
270
As to schools and childcare facilities, 98% of the premises have been worked on and the dose rates have been
substantially lowered (see Jiji, 7 June 2013, based on Ministry of Environment press release).
271
Fukushima Prefecture administration press release, as reported in the local newspaper, Fukushima Minpo, 4June 2013.
272
According to the monitoring results in the model areas of the official decontamination projects, an average of
25% reduction of gamma dose rate is reported after 15 months (December 2011–March 2013) of trials (Ministryof Environment press release, 7 June 2013). The figure means it is mainly due to the natural decay of Cs-134
plus weathering, rather than due to the human intervention. By comparison, the reduction rate was around 60%
in the period up to December 2011, which was mainly due to human efforts plus weathering. In other words,
although the early, urgent work of decontamination, such as shaving playground surface soils, had some effect,
further reduction turned out to be hard to achieve and rather unrealistic. To cite a typical case from Fukushima
City, the eastern hillside residential area of Watari, where the city-contracted (and sub-contracted) operators
slowly conduct remediation work, people still live in ambient exposure rates of 1 to 4 microsievert per hour(µSv/h) with a number of micro-hotspots of up to 150 µSv/h here and there, as monitored by Greenpeace Japan,
Friends of the Earth-Japan, local resident groups, and one of the authors and colleagues, during the period fromMay 2011 to May 2013.
268

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Current Status of Fukushima Daiichi 1–4
After six different professional investigations (see hereunder), the real story of why and how thedestruction of each reactor unit came about is still in the mist. This section reviews the current
conditions and the specific problems of each reactor units.

Unit-1
Meltdown in the Unit-1 reactor proceeded much sooner than the other units. The fuel mostly melted
through (thus the temperature at the pressure vessel bottom is now lower than other units; see Table 1)
and dropped down onto the secondary container floor. The molten fuel is probably eroding the thickconcrete base at the bottom of the container, although the depth of the erosion is hard to estimate. The
quick meltdown and melt-through seem to have been accelerated by the operators’ failure to keep theisolation condenser running properly, and by a loss of coolant accident (LOCA) caused by theearthquake shocks. 273
The radiation environment at Unit-1 is not so severe as at Unit-2, but the dose rate inside the Unit-1
container is more than twice as high as that of Unit-3 (see Table 5).
The Unit-1 building is currently covered with polyester sheets to minimize radioactive releases into
the atmosphere. However, TEPCO plans to remove the cover early next year so that the debris
scattered around on the top floor (Level-5) of the building can be removed and a crane to retrieve
irradiated fuel from the spent fuel pool can be installed above the building.274 The company says anew, larger sheet will be installed to cover both the building and the crane in 2017. In the meantime,
radioactive releases will inevitably increase.

Unit-2
Unlike the other three units, the building of Unit-2 was not severely damaged by explosions, but mostinvestigators agree that the radioactive release from this reactor was the worst (the largest in Bq). Thiswas because the blow-out panel in the wall of the Unit-2 collapsed from the force of the Unit-1
explosion, leaving a large opening in the Unit-2 building. The good news was that explosive hydrogenescaped from the hole; the bad news was that radioactive gas found an easy way out as well.
The Reactor Core Isolation Cooling (RCIC), which had activated just after the main shock on
11 March 2011, ceased to function on 14 March and meltdown started in the Unit-2 reactor.
Secondary containment pressure went as high as 750 kPa, but venting failed. On 15 March, thepressure was rapidly lost after the operators/workers heard an explosive sound somewhere around thetorus (suppression chamber in the bottom part of the container).
The location of the explosion, its cause and nature—hydrogen or nitrogen explosion and where the gas
came from—and the degrees of the damage in the torus and/or pipings are all unknown, and willremain so for some time given the high radiation environment (maximum of 72.9 Sv/h as monitored in
March 2013) in and near the container vessel impeding even a cursory human inspection. What is
known is that there is a large leak (supposedly a substantial rupture) somewhere and the cooling water
poured into the reactor vessel is constantly escaping.
The reactor temperature (39ºC at the bottom of the pressure vessel) is relatively and constantly higher
than at the other reactor units, indicating that the cooling is less effective in this reactor. It probably
reflects the condition of meltdown. The hot molten fuel may have gone deeper into the concrete floorof the container vessel, and pouring in water has a limited cooling effect. If that’s the case, it meansthat retrieving the fuel would be more difficult and would take longer. TEPCO’s decommissioning
roadmap shows that the company is planning on more time in the case of Unit-2 (2017–2023 for spent

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
273
274

Mitsuhiko Tanaka, 2013, Kagaku 83(4): 363.
TEPCO press release, 9 May 2013.

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fuel pool evacuation and 2020–2024 to begin with fuel debris recovery from the reactor containment)
than in the case of Unit-1 (2017 and 2020–22, respectively, for the same operations).275

Unit-3
Venting was carried out twice in Unit-3, but it could not prevent the explosion, which took placeoutside the containment seven hours after the second venting. As to the Unit-3 explosion, independent
nuclear expert Arnie Gundersen claims a possibility of small nuclear detonation due to moderated
prompt criticality in the spent fuel pool, probably due to distortion of fuel assembly racks in the poolcaused by the impact of the hydrogen explosion that occurred close to the spent fuel pool.276 So far,most other professional engineers remain doubtful or reject this scenario outright. However, findingsof fragments of fuel material outside the Unit-3 building and the recent retrieval of extremely
contaminated debris (540 mSv/h recorded at the surface) in the Level 5 (spent fuel pool floor) of the
Unit-3 building277 reflect the fact that the Unit-3 explosion was much more intense than that of Unit-1.
The detonation theory will be ultimately challenged and resolved when the fuel assembly racks andthe fuel rods are physically inspected years from now.
The temperature at the bottom of the Unit-3 reactor pressure vessel was around 36ºC in December
2012. It went down to 25ºC in late March 2013, but again it is around 37ºC in early June 2013. The
fluctuation is much larger than at Unit-1 (low twenties) and Unit-2 (upper thirties). TEPCO plans tostart retrieving fuel debris from the Unit-3 containment in 2021, one year later than Units-1 and -2,
while the fuel retrieval from the Unit-3 spent fuel pool is planned for 2015, two years sooner thanfrom pools at Units-1 and -2.278 As the explosion of Unit-3 was rather large, the conditions of debris
inside and outside the Unit-3 building are worse than in other units. This makes decommissioning
work particularly hazardous in Unit-3.

Unit-4At the time of the earthquake and tsunamiUnit-4 was not operational and was undergoing a periodic
inspection. All fuel had been taken out of the reactor vessel and moved to the spent fuel pool, where
older spent fuel assemblies were also stored. At approximately 6:10 am, 15 March 2011, the Unit-4
building exploded, blowing the upper-floor walls and the ceilings away, leaving the spent fuel pool
filled with 1,535 assemblies (1,331 irradiated ones and 204 fresh ones)279 in the open air without
containment, though debris fell into the pond. The cause and mechanism of this explosion are still
unclear. Unlike the earlier explosions at Unit-1 and -3, no video-recording is available; even the exact
time of the explosion remains uncertain. A likely explanation is that hydrogen came from Unit-3 via
the piping; there is also a probability that Unit-4 spent fuel pool temperature went high enough tocause radiolysis of the water, producing hydrogen gas.
What if the spent fuel pool gets cracked and loses its cooling water? What if the already severelydamaged (and, as it seems, slightly leaning) reactor building collapses and the spent fuel pool crashes
down, perhaps triggering a spent fuel fire? This could lead to a worst case scenario that was drawn up
in March 2011 by Prof. Kondo, Chairman of the Japan Atomic Energy Commission (JAEC), would
still apply. Evacuation of over 10 million residents in the wider Tokyo megalopolis within a 250-km
radius of Fukushima Daiichi, depending on wind direction, may be required. 280 Radioactivity of the
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
275

TEPCO press release, 10 June 2013.
Arnie Gundersen’s remark at the Session 1, the International Symposium on the Truth of the Fukushima
Nuclear Accident and the Myth of Nuclear Safety, held at the University of Tokyo, 29 August 2012, as recordedin the Proceedings [in Japanese] (published by Iwanami, November 2012): 16-17.
277
TEPCO press release, 4 May 2013.
278
TEPCO press release, 10 June 2013.
279
Two of the 204 unirradiated assemblies were retrieved in a test operation of July 2012, so the remaining
number of the fuel assemblies is 1,533.
280
Shunsuke Kondo, 25 March 2011, 15 slides as reported to the government. Archived atwww.asahi-net.or.jp/~pn8r-fjsk/saiakusinario.pdf, accessed 18 June 2013.
276

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Unit-4 spent fuel pool is more or less equivalent to three full reactor-loads; i.e. the quantity of theirradiated fuel rods kept in that single pool roughly equals those in Unit-1, -2 and -3 reactor cores
combined. Thus, full release from the Unit-4 spent fuel pool, without any containment or control,
could cause by far the most serious radiological disaster to date.
TEPCO claims that the Unit-4 building has been reinforced enough to survive further quakes, but
retrieving the heat-generating spent fuel from the pool is nonetheless imperative and as quickly as
possible. TEPCO puts a top priority to the construction of a crane-supporting iron framework over the
Unit-4 building. Retrieval of the assemblies is scheduled to begin in November 2013 and to becompleted by 2014.281

Wave or Shake?
So far, six projects of investigation into the Fukushima accident were carried out and five of thempublished (mostly in Japanese). They are in order of publication: (1) Ohmae project282, (2) RJIF283, (3)TEPCO284 , (4) NAIIC commissioned by the Diet (Parliament)285 , (5) the Government286 and (6) the
Atomic Energy Society of Japan (AESJ).287 The reports differ not only in their perspectives but also inmany of the details in their analysis of the accident sequences. This may not be surprising given thereality that most of the crucial devices, and the specific locations in the reactor systems where thedestruction and/or dysfunctions occurred, remain uninspected or even inaccessible due to the lethal
radioactive environment in and around the reactor containments.
The most important difference among the above reports is about whether the main cause of the
Fukushima Daiichi disaster was the earthquake shocks or the tsunami inundation. Only the NAIIC
report claims that ruptures in piping or destruction of generator(s) could have caused decisive failuresprior to the tsunami arriving. Other investigation reports are rather negative about that possibility andconsider the tsunami the cause. The quake/tsunami issue bears a key influence on the matter of thecountry’s safety regulations of nuclear facilities in general, and the controversy in particular ofwhether to restart other power reactors under the current aseismic codes.
Fukushima Daiichi lost all its external power sources as the transmission towers collapsed in theearthquake. Subsequently, the station lost all its onsite power generators, including those installed forthe case of emergency. This happened also at the Daini station, but one external powerline held up at
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

281

TEPCO, press release, 10 June 2013.
K. Ohmae, “The Last Conditions of Reboot: Final Report of the Investigation Project of the Fukushima
Daiichi Accident” [in Japanese], Shogakkan Publishers, 2012.
283
Rebuild Japan Initiative Foundation (RJIF), usually called Minkan Jikocho (Minkan means private sector and“jikocho” is short for Accident Investigation Committee) was chaired by Professor K. Kitazawa, former
President of the Japan Science and Technology Agency (JST), “The Independent Investigation Commission on
the Fukushima Nuclear Accident, Investigation Report” [in Japanese], RJIF, 1 March 2012, see
http://rebuildjpn.org/en/fukushima/ for an English summary, accessed 19 June 2013.
284
TEPCO, “Fukushima Nuclear Accidents Investigation Report”, 2012, see www.tepco.co.jp/en/press/corpcom/release/2012/1205638_1870.html, accessed 7 May 2013.
285
National Diet of Japan Fukushima Nuclear Accident Independent Investigation Commission (NAIIC), usuallycalled “Kokkai Jikocho” (kokkai means the Japanese Diet) was chaired by Emeritus Prof. K. Kurokawa ofTokyo University. NAIIC, “The Official Report of the Fukushima Nuclear Accident Independent Investigation
Commission”, The National Diet of Japan, 5 July 2012 (NAIIC 2012). English edition at
http://warp.da.ndl.go.jp/info:ndljp/pid/3856371/naiic.go.jp/en/report/, accessed 30 April 2013.
286
Investigation Committee on the Accident at Fukushima Nuclear Power Stations of Tokyo Electric Power
Company (ICANPS), usually called “Seifu Jikocho” (seifu is the national government) was chaired by Emeritus
Prof. Y. Hatamura of the University of Tokyo. ICANPS, Final Report on the Accident at Fukushima Nuclear
Power Stations of Tokyo Electric Power Company, 23 July 2012. English edition at
http://www.cas.go.jp/jp/seisaku/icanps/eng/final-report.html, accessed 30 April 2013.
287
Final report to appear by the end of 2013.
282

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Daini, narrowly enabling the operators to bring the reactors to cold shutdown, unlike at Daiichi after
its total station blackout. Apparently the Daiichi site’s onsite generators were lost due to theinundation. NAIIC investigators, however, see the possibility that at least some of the generators had
been destroyed by the earthquake, and that perhaps the Unit-1 reactor suffered a loss-of-coolant
accident due to pipe ruptures before the station blackout.
The nature of the earthquake oscillation experienced by the Daiichi station was rather abnormal in thatit continued for 180 seconds, twice as long as the basic design earthquake ground motion (Ss) for thereactor building. The length reflects the magnitude of what happened in the epicenter: the main shockof 3/11 came from the huge fault surface of 450 km longitudinal x 200 km latitudinal. It is highly
likely that the repeated load caused fatigue fractures in all corners of the buildings and installations of
the power stations—not only at Fukushima Daiichi, but also in other reactors that escaped meltdown.
Therefore full investigation of the degrees and extensions of the ruptures, fractures and other modes ofdestructions at those other plants seems imperative, though the Government and the power companies
are not open to this suggestion, perhaps because it could bear on both their suitability for potential
restart and on the adequacy of national nuclear seismic standards.
In the “wave or shake” controversy, the exact time of flooding of the emergency diesel generators is of
crucial importance. TEPCO says the first wave (4m high) arrived at 15:27 on 3/11, and the muchhigher second wave (scaling out the wave recorder limit of ±7.5m) arrived at 15:35. Both Seifu
Jikocho (Government) and Minkan Jikocho (private) studies adopted these figures. NAIIC (Kokkai
Jikocho), however, found that these were actually the times recorded 1.5 km offshore where the wave
meter was buoyed, and the big wave must have taken a further 2 to 2.5 minutes to reach the shoreline(i.e. at 15:37 to 15:37:30). It would take some more time for the tsunami to inundate the diesel
generators. According to the plant record, the respective time of the diesel generator power failure is
the following:
15:35 or 36 — System A, Unit-1
15:37 — System B, Unit-1
15:38 — Systems A and B, Unit-3

Thus apparently the System A of Unit-1 failed before the tsunami. It is most likely that it had stopped
due to the aftershocks before the inundation. It is also possible that the System B of Unit-1 and the twosystems of Unit-3 failed before the flooding. By this logic and evidence, TEPCO’s claim that station
blackout would not have taken place without the tsunami cannot be maintained.288
NAIIC investigators applied a series of failure-tree analysis (FTA) regarding the impacts of therepeated oscillations	 and reached a reasonable assumption that the rapid loss of coolant at the Unit-1
reactor, leading to its meltdown, was explicable as caused by a small-scale rupture (or ruptures)
somewhere in the reactor’s piping system, including the piping to the Reactor Core Isolation Cooling
Condenser (IC). Operators who were at the Level 4 of the Unit-1 reactor building on 3/11 testified intheir interviews with NAIIC that they had experienced water leakage at Level 4. Onsite inspection isessential to determine whether this water was from ruptured pipe(s) or from the damaged spent fuelpool at Level 5. NAIIC also interviewed a number of Unit-1 operators and plant workers to confirm
that the safety relief valve, an essential device to depressurize the reactor in trouble, did not open,
because nobody heard a loud noise indicating that the main steam had escaped the valve (thus making
the water injection easier and possibly avoiding meltdown). The malfunction of the safety relief valve
would support the small-scale rupture hypothesis.
The NAIIC investigation presents a strong argument that the loss of coolant accident at Unit 1, leading
to its meltdown quicker than other reactor units, had been caused by the earthquake strikes before thetsunami crippled the emergency generators. Onsite investigation, particularly in Level-3 to Level-5
floors of the Unit-1 building, is needed to specify how much and what kind of damage is found in
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
288

NAIIC 2012, ibid:227. (Section 2.2.3.4; English edition, Chapter 2, pp.80-81). See also p.17 of the English
summary of NAIIC 2012, http://warp.da.ndl.go.jp/info:ndljp/pid/3856371/naiic.go.jp/en/report/ (accessed 1 June2013).
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which parts of the building and installations. NAIIC’s repeated request for onsite inspection was
refused by TEPCO for safety reasons. TEPCO has so far disclosed only a very limited amount ofvideo recordings of the floors in question. On 13 March 2013, Hiroshi Kawauchi289 entered the Unit-1
reactor building and his video recording is now open for public inspection.290 The footage shows theLevel-4 devastation is much more than previously estimated; it is now fairly probable that, apart fromthe big explosion at Level-5, there was also a hydrogen explosion at Level-4 destroying the piping
systems connecting the reactor vessel and the isolation condenser.291
Notice also that the shake intensity at Unit-1 of Fukushima Daiichi was within the assumed range inthe reactor design, but it caused fatal damage to the unit. The Fukushima Daini reactor units—shaken
by the quake, flooded by the tsunami, and exposed to a station blackout—narrowly escaped thecatastrophe. It is important to understand these event sequences and learn their lessons.

On-site Challenges: Water, Waste, Radiation
Difficulties with Radioactive Water Management
Cooling of the reactor vessels continues at Units-1, -2 and -3. Since the reactor cores of all three units
are melted down and more or less melted through the vessels, the normal reactor cooling systems areof no use. Operators know where and how the water is injected, but they do not know exactly where it
then goes and how leakage occurs. The coolant (freshwater plus neutron-absorbing boron) is pumped
and sprayed into the main vessels (i.e. pressure vessel, though the pressure is long lost), then leaks into
the secondary containment through the holes and cracks at the bottom of the reactor vessels. After
hopefully cooling the melted nuclear fuel somewhere in the primary and secondary vessels (the forms
and distributions of the fuel debris being unknown), the water leaks out from unidentified ruptures of
the containments and overflows into the basements of the reactor buildings and the connected turbine
buildings. This drainage continuously washes out radionuclides from the destroyed reactors.
Nonetheless, the water injection must continue to prevent the fuel from overheating.
Operators collect the drained radioactive water from the basements and send it through filter systems
to decrease radioactivity and recirculate it back into the reactors. By May 2013, this water circuit was
4 km long, many sections of which were still composed of makeshift vinyl (chloroethylene) tubes
installed above-ground in 2011, rather than severe-duty steel pipes. Thus site workers are always busy
mending leaks and holes, caused for example by frost.
Mr. Ebisawa, who had served NAIIC as an expert reactor engineer, estimated the amount ofradioactivity that had seeped into the water that fills the basement of the reactor buildings (Unit-1, -2
and -3, as of 20 November 2012) as follows:292
Cesium-137:

276 PBq293 (i.e. 40 percent of the reactor core inventory)

Strontium-90:

23 to 33 PBq (i.e. 4.4 to 6.3 percent of the reactor core inventory).

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
289

Kawauchi is an ex-Member of Parliament and the former chairman of the House of Representatives Special
Committee on Promotion of Science, Technology and Innovation. This committee tried actively to inquire into
the Fukushima accident before the official parliamentary commission, NAIIC, was organized.
290
See http://youtu.be/y0GCj12RSO4 or http://youtu.be/QXcgajz87b0, both accessed on 30 May 2013.
291
On 31 May 2013, the Nuclear Regulatory Authority (NRA) personnel went inside the Unit-1 building toinspect the physical condition of the IC at Level-4. The dose rate is 20–30 mSv/h, so the inspectors’ stay had tobe limited to 15 minutes. Their report, with several hundred photographs, is yet to come. (Mainichi Shimbun
reports, 30 May and 4 June; NHK TV report, 5 June 2013.)
292
Toru Ebisawa, 2013, Bulletin of the Citizens’ Nuclear Information Center, 465: 12. J. Kanda gives an earlier
estimate of 160 PBq, as of May 2011, Ocean Policy Research Foundation, Kaiyo Hakusho 2012 [annual reportin Japanese], p. 45. Seizando-Shoten Publishing, 2012.
293
1 PBq = 1 petabecquerel or 1 million billion becquerels or 1015 nuclear distintegrations per second.
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These are far larger amounts than those released into the atmosphere in gaseous form: for example,
more than 27 times the amount of cesium-137 released into the air in the first three weeks294, or about
2.5 to 3.3 times, depending on the estimate, the total amount released into the environment from the
Chernobyl accident295.
The extreme radioactivity (several million Bq per cm3 prior to decontamination) of the outflow is aserious problem by itself, and to make the situation much worse, the volume of the contaminatedwater is continuously increasing. This is due to the influx of groundwater from the hillside into thereactor buildings through the broken walls. The groundwater influx (Units 1–3 combined) is estimatedat a rate of about 400 tons per day—more than the water pumped in to cool the three reactors (about
360 tons per day).296 TEPCO has been trying to control the influx by drilling extraction holes to thewest (uphill) of the reactor units, but their effect seems to be limited. TEPCO is asking the local
fishermen’s union to approve discharge of the drained water, only to meet a strong opposition fromboth the union and the general public.297
The excess of entering over exiting water results in increasing stocks of excess water, after minimal
decontamination, in the storage tanks that are now covering the Fukushima Daiichi station site. The
overall volume of radioactive water that cannot be used in the cooling circulation reached 380,000
tons in early May 2013 (290,000 tons in the storage tanks and the rest in the basement of thereactor/turbine buildings). If the current regime continues, TEPCO estimates that the amount will beover 600,000 tons in mid-2015. The company claims to have plans to install more tanks, up to the total
capacity of 700,000 tons, which however will be filled up in less than three years; as yet there is noplanning beyond that target.
In another makeshift attempt, TEPCO dug seven large (10,000-ton-class) sink ponds adjacent to thetanks, but a series of radioactive leakages was detected in March and April 2013. It was found out thatTEPCO had adopted conventional lining techniques usually applied to solid (non-liquid) industrial
waste, making leakage likely. Following criticism, TEPCO is now pumping the contaminated waterfrom the leaking ponds up to the new steel tanks. The utility said the transfer would be finished by theend of June 2013. However, leakage from those new tanks was already detected in late May 2013.
This is not surprising since those tanks are no more than temporary facilities; they are not properly
welded containers but simply steel plates rounded and fastened tightly with bolts. Most of thesemakeshift tanks will survive only a few years or less, prone to constant leaks and corrosion.
All these operations and repairs yield additional radiation exposure to the site workers. Also, the highradioactivity of the waste water stored in the increasing number of tanks results in a sharp rise of
gamma-ray dose rate (from 0.9 up to 7.8 mSv/y) at the power plant boundary.298 This means that thecompany’s radiation management target of 1 mSv/y at the site boundary will be exceeded.
In a desperate breakthrough hope, TEPCO started a 4-month test operation of a new multi-nuclide
removal equipment (called ALPS), which is intended to filter out 62 radionuclides other than tritium.
If this works, then the question is what to do with the ALPS-processed water, which may contain only
trace amounts of cesium, strontium, uranium, plutonium, etc, but does contain the full amount oftritium coming out of the reactor cores. Apparently TEPCO is considering a controlled release into thesea, which will be fiercely opposed by fishermen, the general public, and overseas neighbors. The
Fishery Union of Fukushima Prefecture already expressed its strong concern even to the proposed
bypass discharge of the hillside water (i.e. control extraction of groundwater before flowing into thereactor buildings), which contains only trace amounts of the radionuclides.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
294

The release of cesium-137 into the atmosphere during the period from 12 March to 31 March 2011 isestimated at around 10 PBq, see TEPCO press release, 24 May 2012). The total atmospheric release, mostly
iodine-131 and inert gases, is estimated at 480 PBq (MITI, February 2012) to 900 PBq (TEPCO, ibid).
295
Estimates range between 85 PBq (UNSCEAR, 1996) and 110 PBq (Ian Fairlie, et al, TORCH Report, 2006).
296
Groundwater influx is also the case at Unit-4, -5 and -6 buildings, but radioactive contamination of water ismuch less serious in those units.
297
Mainichi Shimbun, 31 May 2013; Reuters Japan, 4 June 2013.
298
TEPCO press release, 7 May 2013.
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Apart from the overflow from the cooling circulation described above, and apart from the initial largescale discharge of radioactive water into the sea in March–April 2011, the release of contaminatedwater to the sea at the power plant port is continuing, although at a decreased rate, and TEPCO has noeffective way to restrain it. The average release rate of Cs-137 was estimated to be 93 GBq per day insummer 2011 and 8.1 GBq per day in summer 2012.299 In June 2013, it was revealed that the
groundwater sampled from a monitoring well adjacent to the Unit-2 turbine building is contaminatedwith strontium and tritium, so the highly radioactive water that filled the unit basement has alreadymade its way to the aquifer, whence it can easily flow into the sea.300
One big difference between Chernobyl and Fukushima is the serious sea contamination.301 Highconcentrations of Cs-137 and Sr-90 in fish/mollusk/seaweed samples offshore have been reported
repeatedly, giving a crushing blow to the fishery, which was the main source of income not only of
Fukushima but also of Japan’s wider Tohoku (Northeast) region.
The Government has recently come up with a radically new engineering plan to cope with thegroundwater problems. The idea of freezing the groundwater, or “artificial tundra”, was proposed by
the construction giant Kajima Co., and was adopted by a Government committee of experts that
reviewed the water management at Fukushima Daiichi.302 Artificial tundra itself appears as a simple
and reasonable concept: a number of 20–30-meter-long pipes will be put vertically into the ground inline, and very-low-temperature antifreeze solution will be circulated in the pipes to freeze thegroundwater near the pipes, making an underground ice wall. It is an existing technology used insubway construction and mining to block the influx of groundwater. Such a system, however, would
consume huge amounts of electricity to maintain below-zero temperatures for a long period of time. It
would have to run for more than 10 years while the reactors need coolant circulation. There is also arisk of reversing the water flow, making the highly radioactive water seep out from the reactor
buildings to the aquifer. TEPCO is now considering the proposal, but does not seem as enthusiastic
about the idea as the Government does.

Contaminated Debris
The total of the station site debris (except the fuel debris) will reach 176,000 tons by the end of March2016. The solid waste, such as metals, concrete pieces, plastics, and combined materials will beseparated and piled or sealed according to their radioactivity. TEPCO secured a 20,000-ton storage
capacity for debris of 0.1–1.0 mSv/h grade, but the actual amount is likely to exceed this capacity inearly 2016. At the same time, the 34,000-ton storage capacity for contaminated debris of 1–30 mSv/h
grade will be filled up to 33,000 tons. Total available storage capacity for contaminated debris is lessthan 200,000 tons, which is estimated to be 90 percent saturated by March 2016. TEPCO is yet towork out how much debris will accumulate from the site decommissioning work beyond 2016.303 Poor
waste management planning may prove a serious obstacle on the difficult half-century-long road todecommissioning.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
299

J. Kanda, “Continuing 137Cs release to the sea from the Fukushima Dai-ichi Nuclear Power Plant through2012”, Biogeosciences Discussions, 10: 3577-3595, 2013. See www.biogeosciencesdiscuss.net/10/3577/2013/bgd-10-3577-2013.html.
300
The contamination was confirmed in late May 2013, but it took TEPCO more than two weeks to publicly
release the information, see TBS News, NHK News, Mainichi Shimbun, 19 June 2013. Also see
http://enformable.com/2013/06/tepco-confirms-fukushima-daiichi-groundwater-contaminated-with-strontiumand-tritium/, accessed 20 June 2013.
301
J. Kanda, “Continuing radioactive cesium release to the sea from the Fukushima Dai-ichi Nuclear Power
Plant” [in Japanese], in Kagaku 83(6):634-638, 2013.
302
Yomiuri Shimbun, 30 and 31 May 2013.
303
Kahoku Shimpo, 18 May 2013.
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Workers Exposure to Radiation
Through March 2013, officially a total of 26,942 workers (3,710 TEPCO employees plus
23,232 contractors and subcontractors) have worked at the Fukushima Daiichi site since the accident
started on 11 March 2011. Among those, at least 167 people received radiation doses over 100 mSv(internal and external), including 9 persons over 200 mSv, over the two years from March 2011 toMarch 2013. The maximum personal dose identified was 678.8 mSv. The average was 12.27 mSv perperson. Eighty percent of the workers received doses below 20 mSv.304
These figures exclude the contingent troops (firemen, policemen and the Self-Defence Force) thatentered or flew over the site in March 2011. The size and accuracy of the radiation dose estimations
for these emergency servicemen seem to vary wildly. Under the emergency conditions of March–April
2011, there were a number of cases in which the workers approached high radiation areas without aradiation manager, who usually escorts the workers to supervise their radiological protection andmonitor the dose rate of the work area. There were also frequent cases in which the workers did notcarry individual dosimeters because of the shortage of the dosimeters in the emergency.305 Thus theactual total dose could be considerably higher than the official figures given above.
Radiation-exposed workers’ legal dose limit is 100 mSv for five years, but 50 mSv in any one year.306
As a matter of fact, a number of workers who continuously work at Fukushima Daiichi easily receive
their the 5-year limit in less than a year, or the annual limit in only a few months. There are workers
who intentionally “forget” to put on their dosimeters in the hope of securing longer months of
employment. There were even cases where subcontractors put lead shielding around their dosimeters
to lower their recorded exposures so they could work longer.307 This criminal case might just be the tipof the iceberg. Unless certain compensation schemes or alternative non-exposure jobs are provided for
those who exceed dose limits earlier than their term of service, numerous subcontractors in need ofwork will commit clandestine tricks one way or another, doctoring their radiation exposure records.
Currently at the Fukushima Daiichi site, a daily average of 3,000 workers are engaged in radiationexposed operations. TEPCO employees are less than 7 percent of them; the rest are employed bycontractors, subcontractors, sub-subcontractors, … down to 9th-level-subcontractors. Recruitment of
new workers is becoming more and more difficult, while experienced workers, such as tower crane
operators, must leave the site once they have achieved the dose limits.

Summary and Prospects
The reactor units are still in instable conditions and the cooling system depends on the temporary soft
hoses that were laid in April-May 2011. Aftershocks are still continuing and the maxim possible M-8class quake is yet to come. Government and the utility say it would take 40 years (or probably more)
to retrieve the molten fuel from the three reactors. The question is whether the fragile, tightropewalking conditions on site can possibly be sustained for that length of time.
The serious challenges the Fukushima Daiichi site is facing include the following, but these are by nomeans exhaustive:(1) Cooling the molten fuel (corium), whose exact location is uncertain, for 5 to 10 years; and tokeep it from re-criticality under frequent aftershocks, big and small.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
304

TEPCO, “Status of radiation exposure dose of TEPCO's Fukushima Daiichi”, 30 April 2013.
Of the 5,000 dosimeters stockpiled in Fukushima Daiichi, only 320 survived the earthquake damage and theflood. TEPCO had to temporary suspend the rule that workers must carry individual dosimeter; the obligation
was not resumed before May 2011, see Jiji, 1 April 2011; Tokyo Shimbun, 28 April 2011; Kyodo, 28 April
2011; Yomiuri Shimbun, 30 April 2011.
306
In March 2011, the limit was temporary relaxed up to 250 mSv for emergency operations in Fukushima
Daiichi (not applicable in other sites). The 100 mSv limit was resumed in Fukushima in November 2011. The
extraordinary 250 mSv limit is still applicable to certain operations at Fukushima Daiichi.
307
Asahi Shimbun, 21 and 22 June 2012; Mainichi Shimbun, 21 and 22 June 2012; Yomiuri Shimbun, 23 June
2012.
305

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(2) Circulating the coolant in makeshift, provisional vinyl pipes with non-“rat-safe” powerboards308 and under the remaining threat of another flooding for years to come.
(3) Managing large quantities of radioactive waste water that is continuously building up in thebasements of the reactors and turbine buildings.
(4) Ensure that the wrecked reactor buildings with their spent fuel pools between fourth and fifth
floor withstand aftershocks, possibly M8-grade shakes.
(5) Conduct surveys to pinpoint where and how the reactor containments (including the torus) arecracked and/or ruptured so that they can be mended and filled with water in order to start
retrieving, if ever possible, the fuel debris.
(6) Reduce continued leakage of radioactivity into the sea and the atmosphere to an absolute
minimum, before any physical containment is re-established, hopefully in some five years.
(7) Carry through all these high-radiation-exposed operations under extreme shortage ofworkforce, as most of the skilled operators are rapidly reaching their lifetime dose limit.
On 10 June 2013, TEPCO revised its engineering road map 2015–2023 to start physically retrieving
the molten fuel debris out of the reactor containments of Unit-1, -2 and -3 from 2020 onwards.309
The State of Nuclear Emergency, declared by then Prime Minister Kan in March 2011, has not yet
been lifted. It was lifted for Fukushima Daini in November 2011, but as for Daiichi, the country is stillin an extraordinary situation beyond the law; therefore, the prior legal dose limit of additional 1 mSv/ycaused by nuclear industry activities remains suspended and large numbers of people, inside andoutside the exclusion zones, are told to accept the 20 mSv/y emergency limit without proper
justification and legalization.
	
  

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
308 “Rat stops spent fuel pool cooling system”, Nuke Info Tokyo 154:15, 2013, seewww.cnic.jp/english/newsletter/pdffiles/nit154.pdf, accessed on 5 June 2013. Hours-long failures of the
spent fuel pool cooling were caused repeatedly by rat invasion into the electricity circuit box. The
point is that the indispensable cooling systems still depend on the equipment that was temporarily
installed in the wake of meltdown and explosions and have not been replaced with permanent
installations due to the desperate shortage of workforce under high radiation. The power system has
still poor backups.
309

See www.tepco.co.jp/nu/fukushima-np/roadmap/images/t130610_04-j.pdf (accessed 11 June 2013).

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Nuclear Power vs. Renewable Energy
Three of the world’s largest four economies (China, Germany and Japan),
together representing a quarter of global GDP, are now running theireconomies with a higher share of renewables than of nuclear.
Christof Rühl
Chief Economist, BP
310
12 June 2013

To reduce or avoid dangerous climate change, the move towards a low- or zero-carbon and fossil-fuelindependent energy sector must be both rapid and global. Given the diversity of energy services—cooking, heating and cooling, lighting, communication, mobility, motor torque, etc.—there is no silver
bullet or single technology that will create a low-carbon energy future. Therefore a number of factors
will determine the relative roles and ranking of different technologies, notably: potential for rapid
global deployment, other non-fuel and CO2 resource constraints, compatibility with existing systems
and other technologies, public and political support, and the relative and projected economics. Many
analysts consider energy efficiency the top scorer on all these metrics, so it should generally be bought
before but together with renewables. However, aggregated statistics on technological (or even total)energy savings are not available—efficiency technologies and their effects are poorly tracked in mostcountries—so we focus here on the better-publicized and also important parallel progress in renewablesupplies, omitting a number of other potent competitors to central power stations including
cogeneration (combined-heat-and-power).

Investment
According to an assessment by Bloomberg New Energy Finance (BNEF), global investment in clean
energy—largely renewable energy, excluding large hydro, but also including a small volume ofinvestment into Carbon Capture and Storage (CCS)—was $268 billion in 2012, the second highest
ever level, down from $300 million in 2011, but still five times the 2004 total of $52 billion, as can beseen in Figure 18. The largest percentage of the funding was for asset finance of utility-scale
renewable energy projects, such as wind farms, solar parks, and biofuel plants. This received$148.6 billion, down from $180 billion in 2011. The next largest investment segment was for smallscale project investment, primarily rooftop solar PV, $80.2 billion, up from $76.5 billion in 2011311.
Figure 18 compares the annual investment decisions for the construction of new nuclear compared torenewable energy since 2004. In the absence of comprehensive, publicly available investment
estimates for nuclear power by year, the total investment costs have been included in the year in whichconstruction was started, rather than spreading out the investment over the construction period.
Furthermore, the nuclear investment figures do not include revised budgets if cost overruns occur.
Over this period the total investment in nuclear is nearly an order of magnitude lower than that forclean energy, which is descibed by BNEF as renewable energy, not including big hydro, and CCS.
China has been by far the largest investor in renewable energies in 2012 with over $65 billion. Somebig players reduced expenditures significantly over the previous year, including the U.S., Germany,
Italy and India. On the other hand, some countries had very large growth rates. South Africa boosted
spendings by a factor of two hundred to $5.5 billion, while Japan increased investements by threequarters (see Table 6).

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

310

Rühl, C., “Energy in 2012 – Adapting to a changing World”, Launch of the BP Statistical Review of World
Energy, 12 June 2013.
311
BNEF, “New Investment in Clean Energy Fell 11% in 2012”, Bloomberg New Energy Finance,
14 January 2013.
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The decline in global investment in renewable energy capacity has continued in 2013, and in the firstquarter of the year the figure is estimated at $40 billion, the lowest in any quarter since the first quarterof crisis year 2009.312 But this does not mean less renewable capacity is being installed. Why not?
While these investment volumes are important to watch, it is essential to consider how much can bebuilt per invested dollar. The costs of equipment are changing constantly and are generally declining.
Since 2008 the world market cost of photovoltaic (PV) modules have fallen by 80%—and 20% in2012 alone—while prices for wind turbines, a more mature technology, have fallen 29% since 2008313.
This is in contrast with nuclear power, where the costs have risen considerably. For example the EPR
under construction in France, Flamanville-3, was estimated to cost €4 billion in 2008, but by 2013 it
had risen to €8.5 billion (see Nuclear Economics Chapter for details). The trend is highly relevant,both for investor confidence and in relation to what the investment can actually buy in terms of
installed capacity.
Figure 18: Global Investment Decisions in Clean Energy and Nuclear Power 2004-12 ($ billion)

Source: BNEF 2013 and WNISR original research, 2013

Table 6: Renewable Energy Investment in Top 10 Countries 2011-2012 (in billion US$)314
Country
China
United States
Germany
Rest of EU*
Japan
Italy
U.K.
India
South Africa
Brazil2012 201165.1 54.1
35.6 56,8
22.8 31.3
16.3 17.7
16.3
9.3
14.7 30.1
8.3 10.0
6.9 10.2
5.5 0.03
5.3
7.8

Note: *Rest of EU is including all of the EU countries besides Germany, Italy and the U.K.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
312

Frankfurt School-UNEP Centre/BNEF, “Global Trends in Renewable Energy Investment 2013”, June 2013.
BNEF, “Bloomberg New Energy Finance Summit”, Michael Liebreich, 23 April 2013.
314
Note that earlier 2011 figures have been revised by BNEF, some considerably. China’s expenditures, forexample, were raised from $45.5 billion (as represented in WNISR 2012) to $54.1 billion. Sources, BNEF 2013,
according to PEW, “Who is Winning the Clean Energy Race?”, PEW Charitable Trust, April 2013.
313

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As documented hereunder, the 2011–12 drop in global renewable investment actually supported a
substantial increase in the amount of renewable capacity added, continuing years of consistently
strong growth, whereas nuclear net additions, as reported earlier, are continuing to fluctuate in recent
years between negative and mildly positive.

Installed Capacity
The commissioning of new electricity-generating facilities involves two major phases, predevelopment and construction. Both affect the speed of technology deployment. The pre-development
phase can include a wide range of activities such as conducting extensive consultations, obtaining thenecessary construction and operating licenses, including public consent, and creating the financing
package. In some cases, technology deployment may be sped up through the use of generic safetyassessments. Alternatively, pre-development may take longer than expected because of local site
conditions, lack of available skilled workforce, or new issues coming to light.
The IAEA estimates that starting a new nuclear program in a country without experience can takebetween 11 and 20 years, and the French safety authorities assume a minimum of 15 years to set up an
appropriate framework. Even where countries have nuclear experience, the IEA has estimated a predevelopment phase of approximately eight years for nuclear power.315
It is important to note the differences in construction of a wind farm, and many other renewableenergy schemes, compared to large fossil-fueled or nuclear power stations. The European Wind
Energy Association (EWEA) likens building a wind farm to the purchase of a fleet of trucks: theturbines are bought at an agreed fixed cost and on an established delivery schedule, and the electricalinfrastructure can be specified well in advance. Although some variable costs are associated with thecivil works, these are very small compared to the overall project cost.316 The construction time foronshore wind turbines is relatively quick, with smaller farms being completed in a few months, andmost well within a year. The contrast with nuclear power, and even with conventional fossil fuelpower plants, is significant.
These investments are resulting in grid connections and operation of new capacity, and this slowly
changes the electricity mix. Figure 19 shows the extent of solar, wind and nuclear capacity that has
been added to the global grid since 2000. What is clearly demonstrated is that nuclear power capacity
has remained largely constant over the past decade, whereas the two renewable energy sources, solar
and wind, are increasing steadily and rapidly. Globally the average annual growth rates during 2000–
2012 for onshore wind have been 27 percent and for solar PV 42 percent. This resulted in 2012 alone
in 32 GW317 of solar being added to the grid, 45 GW of wind318 versus a net addition of 1.2 GW ofnuclear319.
	
  

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

315

IEA, “Nuclear Power in the OECD”, Paris, 2001.
European Wind Energy Association (EWEA), “Wind Energy, The Facts: Volume 1, Technology”, Brussels,
2003.
317
CleanTechnica.com, ”Solar PV Installations Hit 32 GW In 2012, 35 GW Projected For 2013, According To
HIS”, 5 February 2013, see http://cleantechnica.com/2013/02/05/solar-pv-installations-hit-32-gw-in-2012-35gw-projected-for-2013-according-to-ihs/, accessed 8 May 2013.
318
GWEC, “Global Statistics for 2012”, Global Wind Energy Council, http://www.gwec.net/globalfigures/graphs/, accessed 8 May 2013.
319
IAEA. “Power Reactor Information System” (PRIS), International Atomic Energy Agency. The IAEA figure
has been adjusted by removing from the figures of the 6 remaining reactors at two Fukushima power plants inJapan, which we consider will not be restarted. But includes uprates according to PRIS.
316

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Figure 19: Nuclear, Wind and Solar Capacity Increases in the World 2000-2012 (MW)

Source: IAEA-PRIS, BP, 2013

Electricity Generation
Skeptics of renewable energy highlight the variable output of some technologies (windpower andphotovoltaics—but not all solar power, since solar-thermal-electric plants typically have built-in heatstorage so they can run into or through the night). A consequence of variability is the lower output per
installed MW over the year than that of traditional fossil-fueled or nuclear power stations. In fact,
obviously no power plant operates continually. Most nuclear plants have experienced extended
unplanned shutdown periods, many exceeding a year. Despite their specific variable characteristics,
wind and photovoltaic power are now becoming significant, both nationally and globally.
The continual deployment of modern renewable energy is reducing dependency on fossil fuels andreducing importers’ security-of-supply concerns. Furthermore, the development of renewables is
helping to reduce greenhouse gas emissions. According to the IEA, positive progress has been madeon the deployment of renewables, which are broadly on target to make the necessary contribution tomeet the two-Celsius-degree target set by the UNFCCC in the Cancún Agreement320 . In particularonshore wind is now able to compete “without special support in electricity markets endowed with
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

320

At the United Nations climate change conference in Cancún, Mexico, in December 2010, delegates agreed
that “climate change is one of the greatest challenges of our time and that all Parties share a vision for long-termcooperative action.” For the first time under the U.N. climate framework, participants acknowledged that “deepcuts in global greenhouse gas emissions are required according to science, and as documented in the Fourth
Assessment Report of the Intergovernmental Panel on Climate Change, with a view to reducing global
greenhouse gas emissions so as to hold the increase in global average temperature below 2°C above preindustrial levels.” - United Nations Framework Convention on Climate Change, “Outcome of the Work of the
Ad Hoc Working Group on Long-term Cooperative Action under the Convention,” Draft decision, COP 16(Cancún, Mexico: 2010), at http://unfccc.int/files/meetings/cop_16/application/pdf/cop16_lca.pdf.

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steady winds and supportive regulatory framework”.321 On the other hand, the IEA notes that nuclear
power is “below levels required to achieve the 2 degree scenario objectives. In addition, increasing
public opposition could make government ambitions for nuclear power’s contribution to their energy
supply harder to achieve”.
Figure 20: Annual Variation in Global Electricity Production from Nuclear and Selected
Renewables (TWh/y)

Source: BP 2013

China, EU, Germany, U.S.
In China, electricity demand has grown remarkably over the last decade, and as a result between 2000
and 2010 coal, which is by far the dominant source, increased its installed power capacity by around
460 GW—twice the total coal capacity currently in the EU.
While China is reknowned for its use of coal, half the world’s total, it has also become the world’s
leading producer and deployer of renewable energy. As can be seen in Figure 22, wind power has hada phenominal growth rate over the past decade, going from an installed capacity of less than 6 GW in
2007 to over 75 GW in 2012. Furthermore, it is not only in installed capacity that wind has achieved
record increases; its corresponding electricity production is also impressive. In fact, in 2012 windovertook nuclear power for the first time for the total amount of electricity produced in China. Overall
in 2012, China increased electricity production by 5.5 percent, of which the use of nuclear energy
increased by 12.6 percent, wind power by 35 percent, and solar PV by 400 percent322. What was also
remarkable in 2012 was the extent to which the expansion of wind power was even larger than that ofcoal. As thermal power use, nearly synonymous with coal, grew by only about 0.3 percent in China
during 2012, an addition of roughly 12 terawatt hours (TWh) more electricity, wind power production
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
321

IEA, “Tracking Clean Energy Progress – Energy Technology Perspectives 2012 excerpt as IEA input to the
Clean Energy Ministerial”, International Energy Agency, April 2013322
CEC “2012 China’s Power Industry Overview, China Electricity Council”, 22 February 2013,
http://www.cec.org.cn/; and REN21, “Renewables 2013 – Global Status Report”, June 2013, see
http://www.ren21.net/REN21Activities/GlobalStatusReport.aspx.
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expanded by about 26 TWh323. In other words, in 2012 China increased electricity production morethan twice as much (in absolute terms) from wind alone as from coal or nuclear power. In India, too,modern renewable energy sources (wind, solar, biomass) generated 51.2 TWh during the fiscal year
2011-2012324, about 5.5% of the total electricity generated in the country, as compared to nuclear
power that generated 3.5% of the total.325 Preliminary estimates for 2012-13 are 6.4% of the total fromrenewable energy and 3.7% from nuclear energy.
Figure 21: Installed Capacity in China from Nuclear, Solar and Wind

Source: BP 2013, PRIS and GWEC

	
  

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
323

Shua, L. “China’s Wind Power Production Increased More Than Coal Power Did for the First Time Ever in2012”, blog on Thinkprogress.org, 20 March 2013.
324
1 April 2011 to 31 March 2012.
325
These figures are approximate though they clearly capture the current and emerging picture. Different
agencies in India seem to report different figures and no single agency reports total electricity generation fromrenewables, nuclear, and all sources. There are slight discrepancies in the figures reported for each of thesequantities. The figures are from http://www.cea.nic.in/executive_summary.html andhttp://www.cea.nic.in/reports/articles/god/renewable_energy.pdf andhttp://pib.nic.in/newsite/pmreleases.aspx?mincode=28, accessed 7 July 2013.
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Figure 22: Annual Electricity Production in China from Nuclear, Wind and Solar

Source: BP 2013

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In the European Union, the introduction and implementation of the renewable energy directive isleading to its greater use, rising from 7.9 percent in 2004 to 13 percent in 2011 for energy as a whole.
In the electricity sector it is estimated that in 2012 renewables have contributed around 22 percent.
This increase in production is likely to continue, as in 2012, 37 percent of the new power capacity
added was solar PV and 27 percent of it was wind power326 . Figure 23 shows the changes ingenerating capacity in the EU since 2000. In addition to the growth in renewable energy there has been
an increased installation of gas power plants, in part due to their ability to “load follow” and therefore
complement the more variable production from some renewables and in part to replace the closure ofcoal and nuclear plants as they reach the end of the operating lives or due to their early retirement onenvironmental or economic grounds.
Figure 23: Net Electricity Generating Installations in the EU 2000–2012 GW

Source: EWEA 2013

	
  

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
326

EWEA, “Wind in Power, 2012 European statistics”, European Wind Energy Association, February 2013.

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In 2012, the combined installed renewable electricity capacity in Germany reached 76 GW327, that is
far more than the available French nuclear capacity (63.1 GW). Of course, French nuclear plants
generated 407 TWh, while German renewables generated “only” 136 TWh (gross) of electricity,
compared to 100 TWh (gross) provided by German nuclear plants or the equivalent to one third of
French nuclear power generation in 2012; but the German renewables growth rate remains verysignificant (+15.5 percent) while German nuclear generation dropped by 8 percent below 100 TWh forthe first time in three decades and French nuclear generation dropped by 3 percent.328
Total renewables output represents now 23 percent of the German power generation, up from
3 percent in 1991. The growth rate in recent years has been particularly impressive in the solar power
sector. Installed photovoltaic capacity increased by a factor of five since 2008 and solar power
generation by a factor of over six to reach 28 TWh in 2012.
Figure 24: German Power Generation of Nuclear and Renewables

Sources: AGEB 2013

	
  

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
327

Wind (31.3 GW) and solar plants (32.6 GW) represent 84 percent of the installed capacity; see BMU, “Daten
des BMU sur Entwicklung der erneuerbaren Energien in Deutschland im Jahr 2011 auf der Grundlage derAngaben der AGEE-Stat”, provisional, 8 March 2012.
328
French nuclear plants already generated more power in 2002 (415 TWh) than in 2012, while the German
renewables tripled production over the same period from 46 to 136 TWh.
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In the United States, much has been said about the importance of shale gas and how it has
fundamentally changed the energy sector. As can be seen in the figure below, the output from gas fired
power stations has increased by 374 TWh during 2002–2011, with the continuation of this trend
expected in 2012. This is largely at the expense of coal, which saw a decline of 170 TWh in output, adecrease of 10 percent from 2001 and from petroleum fuels, which saw a drop of 90 percent to just
16 TWh. Over this period nuclear power’s output increased slightly (by around 3 percent), due to theupgrading of a number of units. However, it is interesting to note that the combined increase in output
from hydro power and wind is 60 percent of that of natural gas; the highest growth rate was for wind
power, which increased its production from 6 TWh in 2011 to 120 TWh in 2011.
Furthermore, renewables are closing the gap on gas: in 2012, more wind capacity was added than any
other generating source, including gas, with U.S. wind capacity rising by 13 GW to a total of morethan 60 GW. The annual investment during 2008–2012 is now $18 billion, reaching $25 billion in
2012329. The dominance of renewables has continued in the first quarter of 2013 with renewableenergy sources (biomass, geothermal, solar, water, wind) accounting for 84 percent of all new
domestic electrical generating capacity.330 Indeed, in the first quarter of 2013, nearly half of total new
U.S. utility capacity additions was solar photovoltaics.
Figure 25: Increases in Electricity Production in the U.S. between 2001 and 2011

Source: U.S. EIA 2013

Future Costs
The need to move away from a global energy sector dependent on the use of unabated fossil fuels is asurgent as ever. In May 2013, it was announced that global concentrations of CO2 in the atmosphere
had reached 400 parts per million.331 While the trajectory of current emissions could, according to the
IEA, result in attmospheric concentrations that might lead to global temperature increases of 6 degrees
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

329

AWEA, “US Wind Industry Annual Market Report”, American Wind Energy Association, 2013
FERC, “Office of Energy Projects, Energy Infrastructure Update” for March 2013, Federal Energy
Regulatory Commission.
331
BBC, “Carbon Dioxide Passes Symbolic Mark”, 10 May 2013
330

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above pre-industrial levels. Therefore in order to try and avoid the most severe consequences ofclimate change, a rapid change in the direction of energy investment is required. As has been
demonstrated in the previous parts of this section, nuclear investment and deployment has beenoutstripped by renewable energy.
A survey of the major power and utility sectors undertaken by PricewaterhouseCoopers in 2012
showed the extent to which these sectors now see renewables as a major competition. Of thosesurveyed the majority felt that renewables would be able to compete with 80 percent plus thinking
onshore wind, biomass and all forms of solar will not need subsidies to compete by 2030. There is lessconfidence in offshore wind but, even so, 69 percent say it will be competitive by 2030. 66 percent
also think marine energy will be competitive by 2030.332
On the basis of current conditions there is no reason to believe that this trend will change, and in fact it
is likely to accelerate as the costs of renewable energy continue to fall, while as has been shown in theeconomics section, the costs of nuclear continue to rise. This extent of the changes between the two
sectors is seen in Europe when comparing the situation of solar PV in Germany and nuclear power in
the U.K.
In the U.K., as described in more detail in other parts of this report, the Government has been in
negotiations with French utility EdF for a guaranteed price of electricity for a fixed period of time.
The details of the protracted negotiations are confidential; press reports suggest that EdF is asking fora price guarantee of just under £100/MWh (€118/MWh) for a 40-year period. This electricity price isbased on an estimated construction cost of £12 billion (€14 billion) for two EPR 1.6 GW reactors at
Hinkley. As noted, EdF’s estimated cost of an EPR nuclear reactor in 2006 was around €3 billion.
This sharply contrasts with the rapid falls in the costs of PV and wind turbines in Germany. PV
installation costs in particular have plunged by over 70 percent in seven years. Total installed costs forGerman photovoltaics around mid-2012 had reached half the typical U.S. levels, even though bothcountries source essentially the same equipment, and most German installations were small andmidsize rooftop systems, while most U.S. installations were utility-scale groundmounted systems.
This changing unit cost is affecting the price guarantee requirements. The decreases in the German
feed-in tariffs for renewables are such that at present the feed-in tariffs for newly installed arrays inGermany are dropping by 1.8 percentage points per month. As of 30 June 2013, the highest price(feed-in-tariff level) is 15.35 €c/kWh for the smallest rooftop arrays with the lowest PV price,
dropping to 10.63 €c/kWh for the largest arrays. On the current rate of decline, by June 2014 thehighest price is expected to be €c11.71/kWh. While the exact details of the proposed strike price for
the Hinkley Point C reactor proposed in the U.K. have not been made public, it is suggested that theprice will be fixed (excluding inflation) for potentially up to 40 years at around £95/MWh; thiscorresponds to around €c11.1/kWh.333.
Thus as renewable costs continue their downward trajectory, the UK will be tied into a fixedguaranteed price for its electricity stretching over the next four decades. Not only will this have an
impact on the domestic consumer but raises questions over the impact on the economic
competitiveness of large-scale industrial users.	
  A recent study by Bloomberg New Energy Finance projects that by 2030, renewable energy
investments will increase by 2.5 to 4.5 times, with the “most likely” scenario an annual expenditure ofabout $630 billion (in nominal terms). The study results suggest that “we are beyond the tipping point
towards a cleaner energy future”.334
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

332

PwC, (2012) “The shape of power to come, Investment, affordability and security in an energy-hungry
world”, the 12th PricewaterhouseCoopers Annual Global Power and Utilities Survey, 2012.
333
Renewables International (2013), “Do the math!, The cost of German solar vs Nuclear”, 16 May 2013
334
HydroWorld.com, “Bloomberg: 70% of new global energy through 2030 will be renewable”, 1 May 2013,see http://www.hydroworld.com/articles/2013/05/bloomberg--70--of-new-global-energy-through-2030-will-berenewab.html, accessed 16 June 2013.
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Annexes
	
  
	
  
	
  
	
  
	
  
	
  
	
  
Annex	  1:	  Overview	
  by	
  Region	
  and	
  Country	
  

	
  

	
  

	
  

	
  

	
  

	
  	
  	
  	
  	
  	
  	
  	
  	
  Page	  85	
  Annex	  2:	  Reactor	
  Construction	
  Times	  2003-­‐2013	
  

127	
  

Annex	  3:	  Definition	
  of	
  Credit-­‐Rating	  by	
  the	
  Main	  Agencies	
  

128	
  

Annex	  4:	  About	  the	
  Authors	
  

129	
  

Annex	  5:	  Abbreviations	
  

131	
  

Annex	  6:	  Status	
  of	
  Nuclear	
  Power	
  in	
  the	  World	
  	
  

136	
  

Annex	  7:	  Nuclear	
  Reactors	
  in	
  the	  World	
  Listed	
  as	
  “Under	
  Construction”	
  

137	
  

	
  

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Annex 1. Overview by Region and Country
This annex provides an overview of nuclear energy worldwide by region and country. Unlessotherwise noted, data on the numbers of reactors operating and under construction (as of July 2013)
and nuclear’s share in electricity generation are from the International Atomic Energy Agency’s
Power Reactor Information System (PRIS) online database. Historical maximum figures, provided inparentheses, indicate the year that the nuclear share in the power generation of a given country was thehighest since 1986, the year of the Chernobyl disaster. Load factor figures are drawn from Nuclear
Engineering International, May 2013, unless otherwise noted.

AfricaSouth Africa has two French (Framatome/AREVA) built reactors. They are both located at theKoeberg site east of Cape Town, which supplied 12.4 TWh or 5.1 percent of the country’s electricity
in 2012 (the historical maximum was 7.4 percent in 1989). The reactors are the only operating nuclear
power plants on the African continent.
The state-owned South African utility Eskom launched an effort in 1998 to develop the Pebble Bed
Modular Reactor (PBMR), a helium-cooled graphite-moderated reactor based on earlier German
designs. What happened then has been summed up by the Energy Economist this way: “The project
was running about 25 years behind its original schedule, the estimated cost of a demonstration plant
had increased 30-fold and a design fit to submit to the regulator had still not been completed.”335 In
September 2010, the Government “[dropped the] final curtain on PBMR,” a few months after having
terminated all public support.336 Some $1.3 billion had been invested in the project, with more than 80
percent coming from the South African Government.337
The failure of the PBMR led Eskom to consider buying additional large Pressurized Water Reactors(PWR). In the longer term, it planned to build 20 gigawatts (GW) of nuclear plants by 2025. However,in addition to escalating cost projections, Eskom faced a challenge of a falling credit rating, reduced
by Moody’s in August 2008 to Baa2, the second-worst investment grade. In November 2008, Eskom
scrapped an international tender because the scale of investment was too high.
In February 2012 the Department of Energy published a Revised Strategic Plan that still contained a
9.6 GW target, or six units for nuclear power by 2030. Startup would be one unit every 18 months
beginning in 2022.338 The South African Government has repeatedly reiterated the 2030 target and
Deputy President Kgalema Motlanthe stated, most recently at the “Nuclear Africa 2013” conference,that the country “will continue to develop and promote nuclear energy”.339 However, he also noted:
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

335

Energy Economist, “Prospects for nuclear power in 2012”, Platts, March 2012.
“Government Drops Final Curtain on PBMR,” World Nuclear News (WNN), 20 September 2010. The
company PBMR, which in September 2010 still claimed on its website that “the South-African project is onschedule to be the first commercial scale HTR in the power generation field,” later fired all but nine staff, went
into “care and maintenance” mode to safeguard intellectual property, and shut down its website for good.
337
For an independent historical account of the PBMR, see David Fig, Nuclear Energy Rethink? The Rise andDemise of South-Africa’s Pebble Bed Modular Reactor, ISS Paper 210 (Pretoria: Institute for Security Studies,
April 2010).
338
DOE, “Revised Strategic Plan – 2011/120-02015/16”, February 2012.
339
Engineering News, “SA looks nearly set to start new nuclear power station build programme”, 5 April 2013,see http://www.engineeringnews.co.za/article/sa-looks-nearly-set-to-start-new-nuclear-power-station-buildingprogramme-2013-04-05, accessed 28 April 2013.
336

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“Admittedly, the use of nuclear energy to mitigate greenhouse gases remains controversial. We remaincommitted to invest in clean energy from multiple sources.”
While government support for nuclear power seems little influenced by the events in Fukushima, theconstruction industry warns that current projects are running late and over budget. Mile Sofijanic,
Managing Director at Concor Engineering: “If we follow the trend, could the NPP programme cost,
not R300-billion [USD33bn], but R750-billion [USD82bn]? That is not acceptable!” 340 One of theissues identified by Sofijanic: “We have a lack of skills. That is factually correct.”Russia’s Rosatom has high hopes for South Africa and offered a full package including extensive
human capacity-building and progressive increase of local input. “Localisation will at the initial stageof the project be at 30 percent of production, which will eventually peak at 65 percent”, for units sevenand eight, said Alexander Kirillov, head of Rosatom’s marketing office in South Africa.341 Apparently,
Russia’s President Vladimir Putin told his South African counterpart in March 2013 that they would“offer(ed) different funding options” for the nuclear new-build programme, should a Russian bid be
chosen.342
In June 2012, the Energy Minister stated that Government would make a decision on its nuclear futureby the end of the year. 343 By March 2013, the prospects were dim to get to the point even a year later,according to trade journal Nuclear Intelligence Weekly:
South Africa’s latest budget seems to leave little room for optimism for those hoping that the government
will decide this year to go forward with its proposed 9.6 GW of new nuclear power. The government
allocated 709.9 million rand ($78.4 million) for nuclear-related programs and subsidies, less than half the1.623 billion it allocated for clean energy programs and subsidies.344

This may reflect a long-awaited shift towards faster, simpler, lower-cost options. Anton Eberhard, aprofessor at the University of Cape Town’s Graduate School of Business and a member of the
National Planning Commission, concluded from recent modelling:
South Africa can achieve electricity supply security without investing in further nuclear power.
Alternative power sources are cheaper and they can also help us achieve our Copenhagen pledges toreduce carbon emissions.345

Eberhard also stressed that the Independent Power Producers (IPP) renewable energy procurement
program was “highly successful” and “raised R47bn [USD5bn] in its first round”. Meanwhile, theEnergy Minister’s Statement in “response to the UN Secretary General’s call for sustainable energy
for all (SE4ALL)” does not contain the term “nuclear”.346
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
340

Mile Sofijanic, Managing Director at Concor Engineering, quoted in Engineering News, “SA looks nearly set
to start new nuclear power station build programme”, 5 April 2013, see
http://www.engineeringnews.co.za/article/sa-looks-nearly-set-to-start-new-nuclear-power-station-buildingprogramme-2013-04-05, accessed 28 April 2013.
341
ROSATOM, “ROSATOM to promote its nuclear technology on the South African market within the
5th BRICS Summit”, 25 March 2013, see http://www.engineeringnews.co.za/article/sa-looks-nearly-set-to-startnew-nuclear-power-station-building-programme-2013-04-05, accessed 28 April 2013.
342
Engineering News, “Moscow willing to finance SA nuclear plants if Russian bid prevails”, 26 April 2013, see
http://www.engineeringnews.co.za/article/moscow-willing-to-finance-sa-nuclear-plants-if-russian-bid-prevails2013-04-26, accessed 28 April 2013.
343
Business Report, “Nuclear plans ready by year end – Peters”, Business Report, 5 June 2012.
344
NIW, 8 March 2013.
345
Business Day, “Nuclear power is neither necessary nor cost-effective”, 19 March 2013; see
http://www.bdlive.co.za/opinion/2013/03/19/nuclear-power-is-neither-necessary-nor-cost-effective, accessed 29
April 2013.
346
Dipuo Peters, “Remarks by the Minister of Energy on Response to the UN Secretary General’s call forsustainable energy for all (SE4ALL)”, New York, 22 April 2013, see
http://www.energy.gov.za/files/media/speeches/2013/RemarksByTheMinisterOfEnergySE4ALL_22042013.pdf,
accessed 28 April 2013.
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The Americas
Argentina operates two nuclear reactors that, as in 2011, provided 5.9 TWh or 4.7 percent of thecountry’s electricity in 2012 (down from a maximum of 19.8 percent in 1990).
Historically Argentina was one of the countries that embarked on an ambiguous nuclear program,officially for civil purposes but backed by a strong military lobby. (An advisor to President Galtieri
once said at a press conference that his country had even built a duplicate, unsafeguarded,
reprocessing plant. Argentina also reopened its uranium enrichment plant in 2010, and was revealedon 1 July 2013347 to have exported 80–100 tons of uranium oxide to Israel, presumably for its nuclear
weapons program.) Nevertheless, the two nuclear plants were supplied by foreign reactor builders:Atucha-1, which started operation in 1974, was supplied by Siemens, and the CANDU type reactor at
Embalse, which was supplied by the Canadian AECL. After 28 years of operation, the Embalse plantis supposed to get a major overhaul, including the replacement of hundreds of pressure tubes, tooperate for potentially 25 more years.348 Reportedly, contracts worth $440 million were signed inAugust 2011 with the main work to start by November 2013. Work is expected to take five years at a
total cost of $1.37 billion.349
Atucha-2 is officially listed as “under construction” since 1981. In 2004, the IAEA estimated that thestart-up of Atucha-2 would occur in 2005. Since then, the IAEA has kept adjusting the expected “firstgrid connection” date, which, as of 6 July 2013 is still given as 1 July 2013, exactly 32 years after
construction start. In June 2013, the Government announced that the project would be completed
within two months.350 That date came and went. The President “pre-started” the plant in a 2011
“inauguration” ceremony, but it apparently remains under construction two years later.
The presidents of Argentina and Brazil, Fernández de Kirchner and Lula da Silva-whose countries had
long been potential military nuclear rivals-, met in February 2008 and agreed to “develop a program ofpeaceful nuclear cooperation that will serve as [an] example in this world.”351 In early May 2009, Juliode Vido, Argentina’s Minister of Planning and Public Works, stated that planning for a fourth nuclear
reactor would be under way and that construction could start as early as within one year.352 It did not.
Neither a siting decision, nor a call for tender, has been reported to date.
After repeated delays construction of a prototype 27 MWe PWR, the domestically designed and built
CAREM25 (a type of pressurized-water Small Modular Reactor with the steam generators inside thepressure vessel), was scheduled to begin in the first half of 2013 (but was not reported) near the
Atucha site with fuel loading planned for the second half of 2017.353
The Argentinian public’s opposition to nuclear power was only reinforced by Fukushima. In a
September 2012 update of a 24-country IPSOS study, 71 percent of the Argentinians polled opposed
nuclear new-build, a score just below Italians, Germans and Mexicans.354

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

347

W. Burr & A. Cohen, “Israel’s Secret Uranium Buy,” Foreign Policy, 1 July 2013,www.foreignpolicy.com/articles/2013/07/01/israels_secret_uranium_buy
348“Argentina’s Embalse Nuclear Plant to Get 25-year Extension,” PowerGenWorldwide.com, 5 August 2010.
349
Research and Markets, “Nuclear Power Market in Argentina”, May 2012.
350
iEco, “Prometen que en dos meses inaugurarán Atucha II”, 27 June 2013.
351“Argentina and Brazil Team Up for Nuclear,” WNN, 25 February 2008. Both countries have a long way to go
to make their programs exemplary. Their industrial as well as their non-proliferation record has been far fromconvincing.
352“Argentina to Reinforce Nuclear Energy by Adding 700 MW and Building Fourth Nuclear Plant,”
Marketwire.com, 7 May 2009.
353
CNEA, “Proyecto ‘CAREM’”, undated, see
http://www.cnea.gov.ar/proyectos/carem/cronograma/cronograma.php, accessed 1 May 2013.
354
IPSOS 2012, op.cit.
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Brazil operates two nuclear reactors that provided the country with 15.2 TWh (the historic maximum)or 3.1 percent of its electricity in 2012 (down from a maximum of 4.3 percent in 2001). The record
electricity generation, which still contributes only modestly to the power supply in the country, is due
to an excellent load factor of 91 percent (+5 percent compared to 2011, 28 percent better than the
lifetime load factor).
As early as 1970, the first contract for the construction of a nuclear power plant, Angra-1, wasawarded to Westinghouse. The reactor went critical in 1981. In 1975, Brazil signed with Germany
what remains probably the largest single contract in the history of the world nuclear industry for theconstruction of eight 1.3 GW reactors over a 15-year period. However, due to an ever-increasing debt
burden and obvious interest in nuclear weapons by the Brazilian military, practically the entire
program was abandoned. Only the first reactor covered by the program, Angra-2, was finallyconnected to the grid in July 2000, 24 years after construction started.
The construction of Angra-3 was started in 1984 but abandoned in June 1991. However, in May 2010,
Brazil’s Nuclear Energy Commission issued a construction license and the IAEA indicated that a“new” construction start occurred on 1 June 2010. In early 2011, the Brazilian national developmentbank BNDES approved 6.1 billion Reias ($3.6 billion) for work on the reactor, mainly to be carriedout by AREVA.355 The IAEA now envisages commercial operation for 1 January 2016. Other sourcesindicate “commissioning” planned for July 2016.356
In January 2011, Brazil’s Energy Minister Edison Lobao stated that the Government planned toapprove the construction of four additional reactors “this year.”357 Right after 3/11, Lobao assured:“We have no need to revise anything, except for learning from what happened in Japan, and taking alook at future proceedings.” 358 In early May 2012, a top-level Brazilian Government official
announced that the country will not proceed with the previously stated plans to launch up to eight new
nuclear power plants. “The last plan, which runs through 2020, does not envisage any (new) nuclear
power station because there is no need for it”, the energy ministry’s executive secretary Marcio
Zimmermann stated. “Demand is met with hydro-electrical power and complementary energy sources
such as wind, thermal and natural gas.” According to press agency AFP, the official also announced
that over the coming decade the level of renewable energy would double from 8 to 16 percent.359
Public opinion is still helping the government to look for other solutions than nuclear. In the IPSOS’s
updated 24-country study support for nuclear energy increased by 10 percent but 63 percent of the
population polled remain opposed to nuclear energy in general.360
Canada operates 19 reactors, all of which are CANDU (CANadian Deuterium Uranium), providing
90 TWh or 15.3 percent of the country’s electricity in 2012 (identical to 2011, down from a maximumof 19.1 percent in 1994). Two reactors have been restarted in 2012 after 15 and 17 years shutdown
periods. On 28 December 2012, Gentilly-2, Québec’s only remaining nuclear reactor, was closed.
There have been significant delays in restarting six of originally eight reactors in long-term-shutdown(LTS). In December 2012, the LTS status of the two 40-year old Pickering-2 and -3 was “retroactively
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
355

However, it is surprising to note that AREVA’s 400-page Reference Document 2012 does not even containthe word “Angra”.
356
NIW, “Potential and Existing Global Nuclear Newbuild Projects Open to International Vendors”, 15 March
2013.
357
“Brazil to Approve Construction of Four Nuclear Power Plants in 2011,” www.neimagazine.com, 10 January
2011.
358
Buenos Aires Herald, “Brazil to continue nuclear energy investments despite Japan crisis”, 15 March 2012;see http://www.buenosairesherald.com/article/61644/-brazil-to-continue-nuclear-energy-investments-despitejapan-crisis, accessed, 25 May 2012.
359
WNISR, “Brazil Abandons New Build Plans”, 11 May 2012, see http://www.worldnuclearreport.org/BrazilAbandons-New-Build-Plans.
360
IPSOS 2012, op.cit.
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changed to Permanent Shutdown” in May 2007 and October 2008 respectively. In January 2010,
operator Ontario Power Generation (OPG, Ex-Ontario Hydro) requested a five-year license renewal
for the four Pickering-1 to -4361 reactors, but in July 2010 the Canadian Nuclear Safety Commission(CNSC) decided to limit the license to three years. For all remaining six Pickering units, the licenses
expired on 30 June 2013.362 However, these licenses were extended for two months (to August 2013)
in late June 2013.363 The two other units that had been in long-term shutdown, Bruce-1 and -2, werereconnected to the grid on 19 September and 16 October 2012 respectively.
In May 2012, the Government accepted the Environmental Impact Assessment report for theconstruction by OPG of up to four units at the Darlington site. On 17 August 2012, the CNSC issued a“Site Preparation Licence” for the Darlington project, “a first in over a quarter century”.364 The next
step in the licensing procedure is the submission by OPC of an application for a construction licensethat will undergo full public hearings.
The province of New Brunswick has abandoned the option of adding a second nuclear reactor at its
Point Lepreau site; meanwhile, a massive refurbishment project on the first unit was CAD1 billion
over its CAD1.4 billion budget and three years behind schedule. The unit was shut down in April 2008
and was restarted on 26 October 2012.365
In June 2011, the Canadian Government sold the commercial reactor division of Atomic Energy ofCanada (AECL) to CANDU Energy, a wholly owned subsidiary of engineering company SNC
Lavalin for CAD15 million plus royalty payments from potential future new-build and refurbishment
projects. There is no assurance that such projects will materalize.
In Mexico, two General Electric reactors operate at the Laguna Verde power plant, located in Alto
Lucero, Veracruz. The first unit was connected to the grid in 1989 and the second unit in 1994. In
2012, nuclear power produced 8.4 TWh or 4.7 percent of the country’s electricity (down from amaximum of 6.5 percent in 1995). An uprating project carried out by Iberdrola between 2007 andearly 2011 boosted the nameplate capacity of both units by 20 percent to reach 765 megawatts (MW)each. However, work continued until February 2013 while the plant remained officially in operation
but the average load-factor of the two reactors plunged from 84 percent in 2011 to 64 percent in 2012.
The power plant is owned and operated by the Federal Electricity Commission (Comisión Federal deElectricidad).
In March 2012, former Energy Minister Jordy Herrera stated: “We have to put the option of building
and expanding our nuclear plants on the table”.366 His successor, Pedro Joaquín Coldwell, who was
appointed in November 2012, in a speech to a recent OECD conference, stressed the “extraordinary
potential” of Mexico’s energy industry, “particularly in the renewable and fossil fuels sectors”.367 He
did not mention nuclear power at all.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
361

Also called Pickering A reactors
NEI, “Pickering A Gets 3-year Licence Extension,” www.neimagazine.com, 2 July 2010.
363	
  CNSC, “CNSC Extends Operating Licences for Pickering A and B Nuclear Generating Stations, 24 June
2013, see http://www.suretenucleaire.gc.ca/eng/mediacentre/releases/news_release.cfm?news_release_id=462,
accessed 24 June 2013.
364
OPG, “Joint Review Panel issues Licence to Prepare Site”, 17 August 2012, see
http://www.opg.com/nb/index3.asp, accessed 8 May 2013.
365
WNISR, “Canadian Nuclear Power at Full Capacity for the First Time in Nearly Two Decades”,
28 October 2012, see http://www.worldnuclearreport.org/Canadian-Nuclear-Power-at-Full.html.
366
NIW, “Lame Duck Energy Minister Proposes More Nuclear Power”, 16 March 2012.
367
Pedro Joaquín Coldwell, Mexico’s Energy Ministry, Presentation in the panel “Efficient Energy Policy”, atthe Mexico Forum 2013, organized by the OECD, 9 January 2013, see
http://www.energia.gob.mx/portal/Default.aspx?id=2363, accessed 9 May 2013.
362

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Also, public opinion remains a major headache for the nuclear industry in the country with 74 percent
opposing nuclear power in general, according to a September 2012 update of an IPSOS 24-country
survey.368

United States
The United States has more operating nuclear power plants than any other country in the world, with100 commercial reactors currently operating. This is the lowest number of operating reactors since
Chernobyl year 1986. The highest number with 108 operating units was reached in 1990.369 Four units
were closed in the first half of 2013, the first time reactors were shut down since 1998.
The U.S. reactor fleet provided 770.7 TWh in 2012, a 2.5 percent drop over the previous year and
4.5 percent less than in the record year 2010. The average load factor dropped by over 3 percent to83.2 percent compared to 2011.
The production decline is partially attributed to extended outages of four units that were down most of
the year and to a higher level of refueling outages. In 2010, only 49 units were refueled. There havebeen only three other times since 1995 that fewer than 60 units refueled during a given year (2001,
2004, 2007).370 Nuclear plants provided 19 percent of U.S. electricity in 2012 (down from a maximumof 22.5 percent in 1995).
First Reactor Closures in 15 Years
In February 2013, nuclear operator Progress Energy, now owned by Duke Energy, decided not tocomplete repairs and uprating of its 36-year old Crystal River reactor that had been offline since late2009. This was the first plant closure in the U.S. since 1998. The 825 MWe PWR in Florida had been
shut down for regular refueling, maintenance and steam generator replacement when significant
deterioration (delamination or cracks) in the concrete containment was identified. Repair was
evaluated as a possible option but by 2012 it was concluded that the “nature and potential scope of
repairs brought increased risks that could raise the cost dramatically and extend the schedule”.371
Trade journal Nucleonics Week reported that costs of repairing the containment could have ranged
between $1.5 billion and “the worst case”, new walls and dome, $3.4 billion.372 Work could havestretched between 35 months and 96 months, it was estimated. Under those conditions, Duke Energy’s
CEO Jim Rogers concluded: “We believe the decision to retire the nuclear plant is in the best overall
interests of our customers, investors, the state of Florida and our company.”373 Duke Energy intends to
put the plant into safe enclosure (SAFSTOR) in order to fully decommission it in 40-60 years.
On 7 May 2013, the second shutdown decision in 15 years in the U.S. led to the permanent closure of
the Kewaunee nuclear power plant in Wisconsin. The plant owner Dominion, “one of the nation’slargest producers and transporters of energy”374 had intended to sell the facility but failed to identify abuyer. The 39-year old 566 MWe single unit reactor was first connected to the grid on 8 April 1974.
The decision is particularly remarkable because “despite its operating license being extended for afurther 20 years until 2033, no buyer was found”, as the nuclear lobby publication World Nuclear
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

368

IPSOS, op.cit.
Some statistics indicate 111 units as the maximum. This is because 3 additional units were in long-termshutdown for many years, which we do not count here as “in operation” in 1990. They were restarted in 1991,
1995 and 2007. The 108 number was reached also in 1991, 1995 and 1996.
370
Nucleonics Week, “Fewer US units to refuel this year than in 2012”, 10 January 2013.
371
Duke Energy, “Crystal River Nuclear Plant to be retired; company evaluating sites for potential new gasfueled generation”, 5 February 2013, see http://www.duke-energy.com/news/releases/2013020501.asp, accessed
10 May 2013.
372
Nucleonics Week, “Decision to repair or retire Crystal River-3 may come in spring”, 10 January 2013.
373
Duke Energy, op.cit.
374
Self-presentation on the Dominion website, see https://www.dom.com/about/index.jsp, accessed
23 June 2013.
369

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News (WNN) notes.375 Indeed, the NRC had issued a lifetime extension only in February 2011376.
Dominion had bought Kewaunee in July 2005. Dominion has stated in the past that thedecommissioning fund of $392 million, transferred when it purchased the plant, would be sufficient tocover the costs. However, as in the case of Crystal River, the reactor will be placed in SAFSTOR.
On 7 June 2013 Southern California Edison (SCE) announced that despite spending over $500 million
on repairs and replacement power it would permanently close units 2 and 3 at the San Onofre Nuclear
Generating Station (SONGS) after losing a 16 month battle to restart. Unit 1 at the station was closed
in 1992. Californian Senator Barbara Boxer, Chairman of the Environment and Public Works
Committee, said of the decision: “This nuclear plant had a defective redesign and could no longer
operate as intended. Modifications to the San Onofre nuclear plant were unsafe and posed a danger tothe eight million people living within 50 miles of the plant”.377 When announcing the closure Ron
Litzinger, SCE’s President said: “We think that our decision to retire the units will eliminate
uncertainty and facilitate orderly planning for California’s energy future.”378
Aging Reactor Fleet
The last reactor in the US to be completed—in 1996—was Watts Bar-1, near Spring City, Tennessee.
In October 2007 the Tennessee Valley Authority (TVA) announced that it had chosen to complete thetwo-thirds-built 1.2 GW Watts Bar-2 reactor. 379 Questions persist about whether this will provefeasible, let alone economic. Questions persist about whether this will prove feasible, let alone
economic.
The lack of new reactor startups leads to the continuous aging of the fleet. Average age stands at
33.4 years (as of May 2013), amongst the highest in the world, with 22 units—every fifth reactor—
operating for at least 40 years (up to 44 years). Projects are being developed and implemented to allow
reactors to operate for potentially up to 60 years. As of June 2013, 72 of the 100 operating U.S. units
have received an extension, another 18 applications are under review by the NRC, and 9 havesubmitted letters of intent covering a period up to 2019.380
First Construction Starts in 35 Years
The George W. Bush administration’s National Energy Policy set a target of two new reactors to bebuilt by 2010, but this objective was not met. To reduce uncertainties about new construction, a twostage license process was developed. Designs of reactors can first receive generic approval, thenutilities need only seek a combined Construction and Operation License (COL) that does not involve
questioning of the reactors’ designs.
As of May 2013, the NRC had received 18 licensing applications for a total of 28 reactors. Thissituation did not change over the past year. (See detailed list in Annex 3 of WNISR 2012). All theapplications were submitted between July 2007 and June 2009. Of the 28 reactor projects, eight were
subsequently suspended indefinitely or cancelled and at least 16 were delayed.381
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

375

WNN, “Kewaunee enters retirement”, 7 May 2013, see http://www.world-nuclear-news.org/CKewaunee_enters_retirement-0705134.html, accessed 10 May 2013.
376
WNISR, “U.S. Nuclear Plant to Close After Failing to Attract a Buyer”, 25 October 2012,
http://www.worldnuclearreport.org/US-Nuclear-Plant-to-Close-After.html
377
NBC, “Socal Edison Retiring San Onofre Nuclear Generating Station”, 7 June 2013, see
http://www.nbcsandiego.com/news/local/San-Onofre-Nuclear-Plant-Closing-Retiring-SONGS-OceansideReactor-210565761.html#ixzz2VY1EBvlb, accessed 6 July 2013.
378
ENS-Newswire, “California’s Damaged San Onofre Nuclear Plant to Be Retired”, 7 June 2013, see http://ensnewswire.com/2013/06/07/californias-damaged-san-onofre-nuclear-plant-to-be-retired/, accessed 6 July 2013.
379
For details, see section on Watts Bar-2 in chapter “Unfulfilled Promises” in WNISR-2012,
http://www.worldnuclearreport.org/The-World-Nuclear-Industry-Status-54.html#unpro.
380
U.S. Nuclear Regulatory Commission (NRC), “Status of License Renewal Applications and Industry
Activities”, see www.nrc.gov/reactors/operating/licensing/renewal/applications.html, accessed 9 May 2013.
381
USNRC, “Combined License Applications for New Reactors”, see
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On 9 February 2012, for the first time in nearly three and a half decades, the NRC granted a COL for
Vogtle-3 and -4 units in Georgia. On 30 March 2012, South Carolina Electric & Gas (SCE&G)
received the second COL for units 2 and 3 at its Summer site. In an unprecedented move, Gregory B.
Jaczko, then Chairman of the NRC, voted against the opinion of the four other Commissioners, statingthat the decision was being taken “as if Fukushima never happened”.382 Jaczko subsequently resigned
from his NRC position and is currently writing a book about his experience.
SCANA Corporation, owner of SCE&G, announced the official construction start of theVirgil C. Summer Unit 2 on 11 March 2013, the second anniversary of the Fukushima disaster. On 15
March 2013, first concrete was poured for Vogtle-3. These were the first time in 40 years that a reactor
project was started that was subsequently connected to the grid – if indeed that ultimately occurs.
As of May 2013, the NRC had granted four Early Site Permits (ESP) and received two additional
applications that are under review.383 This situation has not evolved over the past two years. ESPs are
independent of the construction/operating license.384 Only the Vogtle project has received an ESP, a
COL and a certified design at this stage. The Summer reactors, which received the only other COL
and were to start up in 2016 and 2017, have been experiencing repeated delays. Both projects,
Summer and Vogtle, “face significant challenges in maintaining the project forecast at or below”
budget, the monitor stated.385 The Economist recently reported that Vogtle is “now perhaps 18 months
behind schedule and $737 million over budget. That does not include a further $900 million that is the
subject of legal dispute, plus the extra financing costs that will come with these overruns.”386
New-build Projects in Trouble
By the end of 2008, nuclear utilities had applied for $122 billion in loan guarantees, and in May 2009
the DOE short-listed four companies for the first group of loan guarantees:• Southern Nuclear Operating Co. for the two AP1000s at the Vogtle nuclear power plant;• South Carolina Electric & Gas for two AP1000s at the Summer site;• NRG Energy for two ABWRs at the South Texas Project site in Texas and• Constellation for one EPR at the Calvert Cliffs site in Maryland.

By then, the limit for coverage of loan guarantees had been increased from 80 percent of the debt to 80
percent of the total cost. In February 2010, Southern’s Vogtle project was the first to have been
awarded a conditional loan guarantee ($8.3 billion) for a nuclear power plant project worth anestimated $14 billion. The reactors were supposed to start operating by 2016 and 2017. As statedabove, the first units at the Vogtle and Summer sites are now under construction.
The other two projects are in trouble. Constellation Energy abandoned the application for a loan
guarantee for the Calvert Cliffs-3 project after discovering a “shockingly high estimate of the credit
subsidy cost” (11.6 percent or $880 million)-a fee legally required to recompense taxpayers for the fairmarket value of the risk they would undertake by issuing the guarantee.387 Constellation has since beenabsorbed by Exelon, and on 1 November 2012, the NRC issued an order terminating the adjudicatory
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
http://www.nrc.gov/reactors/new-reactors/col.html, accessed 9 May 2013.
382
MSNBC, “U.S. licenses first nuclear reactors since 1978”, 9 February 2012.
383
ESP granted: Clinton (Exelon), Grand Gulf (SERI), North Anna (Dominion), Vogtle (Southern). ESP underreview Victoria County Station (Exelon), PSEG Site (PSEG).
384
NRC, “Early Site Permit Applications for New Reactors,” see
www.nrc.gov/reactors/new-reactors/esp.html, accessed 23 June 2013.
385
Bloomberg, “Southern’s Nuclear Reactors May Be Delayed, Monitor Says”, 1 June 2012.
386
Economist, “Nuclear power – Fracked off”, 1 June 2013, see http://www.economist.com/news/unitedstates/21578690-thanks-cheap-natural-gas-americas-nuclear-renaissance-hold-fracked, accessed, 2 June 2013.
387
Michael J. Wallace, Chairman of Constellation Energy Nuclear Group, letter to Dan Poneman, DOE,
8 October 2010.
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proceeding on the combined license application for Calvert Cliffs 3.388 On 30 August 2012, the NRC
had given French state utility EDF 60 days to find a U.S. based partner for the project to build an EPR
at the Calvert Cliffs site in Maryland. Majority ownership, control or domination of a nuclear power
plant by a foreign entity is illegal in the U.S.389 EDF failed to identify a new partner after Constellation
had pulled out. EDF lost over $1 billion in this unsuccessful U.S. adventure.
The South Texas Project (STP) is facing the same problem as Calvert Cliffs 3. Nuclear merchant(unregulated) utility NRG, the majority shareholder announced in April 2011 that it was withdrawing
from the project, writing down a $481 million investment and excluding any further investment. NRG
CEO David Crane said that the Fukushima aftermath was “dramatically reducing the probability thatSTP 3 and 4 can be successfully developed in a timely fashion.”390 The proposal was to build two
Advanced Boiling Water Reactors (ABWR) at STP, through a company called Nuclear Innovation
North America (NINA). NINA was originally a joint venture between Toshiba American Nuclear
Energy Corporation (TANE) and NRG. However, after NRG pulled out of the project and according
to the NRC letter to NINA “that, although TANE owns about 10 percent of NINA, its overwhelming
financial contributions give it significantly more power than is reflected by this ownership stake”.391
According to Brett Jarmer, an attorney for a coalition of groups opposing the license, “federal law isclear that foreign controlled corporations are not eligible to apply for a license to build and operate
nuclear power plants. The evidence is that Toshiba is in control of the project and this precludes
obtaining an NRC license for South Texas Project 3 & 4”.392 Considering the fate of the Calvert Cliffs
project, it will be extremely difficult for Toshiba to identify a new U.S. investor.
In early May 2012, Progress Energy, later taken over by Duke Energy, announced that it was delaying
its Levy project in Florida for two AP1000 reactors by three years to start-up the first unit in 2024 andthe second 18 months later. The “shift in schedule will increase escalation and carrying costs and raise
the total estimated project to between $19 and $24 billion”, from a 2008 price tag of $17 billion, thecompany announced.393 On 3 May 2013, Duke Energy announced that it had withdrawn the 1998
license request for the construction and operation of two 1000 MWe reactors at the Shearon Harris
plant in North Carolina. The company informed the NRC that the plant was no longer needed due tosluggish demand growth forecasts. However, others contest the explanation and suggest that Duke
have consistently exaggerated demand growth projections and that the changes in the energy market
mean that utilities can no longer keep locking out competitors, especially rooftop solar.394
Gas prices in the U.S., due to the accelerated development on non-conventional gas, remain low andincrease the uncertainty over the economics of building new nuclear plants. “Let me state
unequivocally that I’ve never met a nuclear plant I didn’t like,” said John Rowe, former chairman and
CEO of Exelon Corporation, the largest nuclear operator in the U.S. with 22 nuclear power plants.
“Having said that, let me also state unequivocally that new ones don’t make any sense right now.”395
One year after John Rowe’s statement, renewables have spectacularly increased their role as a serious
competitor in the power market. In the first three months of 2013, of the 1,546 MWe newly connected

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

388

see WNISR, EDF’s US Calvert Cliffs 3 Project “Terminated”
see WNISR, Final Blow to EDF’s US Adventure?
390
WNN, “NRG Withdraws From Texan Project”, 20 April 2011.
391
WNN, “NINA falls foul of foreign ownership law”, 1 May 2013, see http://www.world-nuclearnews.org/NN-NINA_falls_foul_of_foreign_ownership_law-0105137.html, accessed 6 July 2013.
392
PR Newswire, “Foreign Ownership Could Halt Licensing Of South Texas Project Nuclear Reactors; NRC
Says NINA Doesn't Meet Their Requirements”, 1 May 2013
393
WNN, “Levy nuclear project moved back by three years”, 2 May 2012.
394
NC Warn / Marketwatch.com, “Demise Of New Harris Nukes Is An Important Public Victory Towards A
Clean Energy Revolution”, 3 May 2013, http://www.marketwatch.com/story/demise-of-new-harris-nukes-is-animportant-public-victory-towards-a-clean-energy-revolution-2013-05-03, accessed 6 July 2013.
395
Forbes, “Exelon’s ‘Nuclear Guy’: No New Nukes”, 29 March 2012.
389

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to the U.S. grid, 82 percent were renewables (and 47 of the 82 percent was solar), the rest natural gas
plants396 —no coal, no nuclear (see also the section Nuclear vs. Renewables).
Public opposition has also been growing over the past year, according to a March 2012 poll by ORC
International. While supporters of new-build stagnated at 46 percent, opponents increased their sharefrom 44 to 49 percent. At the same time, people were split over lifetime extensions with 49 percent infavor and 47 percent opposed. On the other side, 77 percent of the respondents favor the shift of loan
guarantees from nuclear to renewable energies.397“The long-term outlook for nuclear generation depends on lifetime of existing capacity”, is the title ofan extract of the Annual Energy Outlook 2013 of the U.S. Department of Energy (DOE).398 The title
suggests that even the long-term future of nuclear power is not mainly characterized by the number of
new-build projects but by the longevity and number of surviving plants. The DOE has built four
scenarios and concludes:
Projected reliance on nuclear power in 2040 varies across cases, providing between 10% and 20% of
projected total electricity generation with total capacity between 63 GW and 133 GW.

This compares with the current installed capacity of about 100 GW. In the Reference Case of its
Annual Energy Outlook 2013, DOE projects an increase in installed nuclear capacity of about 19 GW
to 2040, of which only 5.5 GW is new-build capacity and the rest would come from uprates. The DOE“assumes that the operating lives of most of the existing U.S. nuclear power plants will be extended atleast through 2040”.399 Many of the plants would have passed 60-years of operation by then an
astonishing assumption considering the characteristics of the recent Crystal River and Kewaunee
closures. This assumes that such elderly plants will remain economic to run and to keep fixing whenmost of them have trouble competing today and when a need for major repairs is often a reason to shutthem down immediately. Energy analyst Amory B. Lovins, analyzing recent industry operating-cost
data, comes to the conclusion: “For economic or other reasons, the gradual phase-out of unprofitable
nuclear power plants, already quietly under way, may accelerate.”400
While the new U.S. Secretary of Energy Ernest Moniz is considered a supporter of nuclear power, as
was his prececessor Steven Chu, Government support has remarkedly cooled off. In his February 2013
State of the Union speech to Congress, President Barack Obama “highlighted the potential for solar,
wind and even natural gas – but nuclear power received not a single mention”, complains theindustry’s World Nuclear News.401 It has simply been overtaken in the marketplace.

Asia
China
China started construction of its first commercial reactor only in 1985, but its nuclear sector isdeveloping fast, with 28 reactors under construction (40 percent of the world’s total). However,despite this potentially large planned increase as of July 2013, China has only 18 reactors (14 GWe) in
operation, which in 2012 provided 92.65 TWh or 2 percent of the country’s electricity, the lowest
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

396

Kenneth Bossong, “Renewables Provide 82% of New US Electrical Generating Capacity in 1Q2013”, see
http://www.renewableenergyworld.com/rea/news/article/2013/04/renewables-provide-82-of-new-us-electricalgenerating-capacity-in-1q2013, accessed 10 May 2013.
397
ORC International, “One Year After Fukushima – American Attitudes About Nuclear Power”, commissioned
by Civil Society Institute, March 2012.
398
USDOE-EIA, “The long-term outlook for nuclear generation depends on lifetime of existing capacity”,
25 April 2013, see http://www.eia.gov/todayinenergy/detail.cfm?id=10991, accessed 10 May 2013.
399
idem.
400
Amory B. Lovins, “The economics of a US civilian nuclear phase-out”, Bulletin of the Atomic Scientists,
1 March 2013, see http://bos.sagepub.com/content/69/2/44, accessed 12 May 2013.
401
WNN, “Obama neglects nuclear in state of the union”, 13 February 2013, see http://www.world-nuclearnews.org/EE-Obama_neglects_nuclear_in_state_of_the_union_130213a.html, accessed 17 May 2013.
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nuclear share of any country. The maximum of 2.2 percent was reached 10 years ago in 2003. All of
the units under construction are scheduled to come online before 2018 and would bring the total to 46
reactors (42 GWe).
During 2013 China plans to add 52 GW of non-fossil fueled generating capacity, comprising 21 GW
of hydro, 18 GW of wind, 10 GW of solar and 3 GW of nuclear power402 . By comparison the total
fossil fueled capacity expected to be introduced in 2013 is 40 GW.403 During the first six months of2013, construction did not start on any new nuclear power plant. Thus non-hydro renewables areclosing in on coal-fired plant construction, and their lines should cross shortly, as the government
recently raised its 2015 PV installed-capacity target to an astonishing 40 GW to soak up surplus
production capacity, mostly in China.
In 2010, a revision to the National Nuclear Power Middle and Long Term Development Plan 20052020, was under consideration in 2010, when some officials predicted that a likely target for 2020
would be 80 GW in operation together with a further 50 GW under construction.404 However, inJanuary 2011, the State Council Research Office (SCRO), which makes independent policy
recommendations to the State Council, suggested that the 2020 target should be restricted to 70 GW ofnuclear power in operation, with another 30 GW under construction, so as to ensure quality control inthe supply chain. It cautioned against the launch of new Gen-II projects, and emphasized the need fora greater deployment of Gen-III+ projects, notably AP1000s, and that going too fast could threaten thelong-term health of the sector.405
Safety concerns of the domestic designs were also highlighted in a cable from the U.S. embassy inBeijing from 2008, released by Wikileaks, which stated that the Gen-II CPR-1000 design were copies“of 60's era Westinghouse technology that can be built cheaply and quickly”406 —so by the time someof those reactors reached the end of their lives, their design would be a century old. (To be sure, thatcharacterization may have reflected eagerness to sell newer U.S. technologies instead.) Similar
concerns have been expressed by Tange Zede a member of the State Nuclear Power Technology Corp
(SNPTC) who reportedly said the CPR-1000 could not even meet the national safety standards issued
in 2004, let alone the most up-to-date international standards. Zede stated that “unless, the constructed
Gen-II reactors are renovated, they should not be allowed to load fuel and start operation” 407 .
Furthermore, the SCRO report advised that since goals to increase the localization of AP1000s has
proven difficult, efforts needed to be made to de-bottleneck the domestic supply chain for AP1000s. In
addition, the SCRO recommended that the National Nuclear Safety Administration, responsible for
implementing safety regulations, be removed from the authority of the China Atomic Energy
Authority, whose aim is to promote the nuclear industry408 .
Contrary to perceptions, Fukushima had a significant impact on nuclear development in China. On
14 March 2011, Xie Zhenhua, vice chairman of the National Development and Reform Commission,stated that “[e]valuation of nuclear safety and the monitoring of plants will be definitely
strengthened.”409 Then an account of a mid-March 2011 State Council meeting chaired by Premier
Wen Jiabao states: “We will temporarily suspend approval of nuclear power projects, including those
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
402

Other sources expect 5 GW of new nuclear capacity to start up in 2013, 10 GW in 2014 and 8 GW in 2015,
see Annex 7 for details.
403
NIW, Briefs-China, 8 March 2013.
404
Bo, Y, “China Nuclear Energy Development”, China Nuclear Energy Association, June 2012, published by
the International Atomic Energy Agency, http://www.iaea.org/nuclearenergy/nuclearknowledge/schools/NEMschool/2012/Japan/PDFs/week1/3-3_Yang_ChinaNuclearEnergyDevelopment.pdf
405
WNN, “Maintain nuclear perspective, China told”, 11 January 2011
406
Wikileaks, “Viewing cable 08Beijing3362, Effective Nuclear Advocacy in China”
http://www.wikileaks.org/cable/2008/08/08BEIJING3362.html
407
NIW, “Despite Inspections, Post Fukushima Impact on Newbuild is Minimal”, 30 January 2012
408
WNN, “Maintain nuclear perspective, China told”, 11 January 2011
409
Archana Chaudhary, “Nuclear Accident Forces China Policy Review as India Sees Safety Backlash,”Bloomberg.com, 14 March 2011.
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in the preliminary stages of development.... We must fully grasp the importance and urgency of
nuclear safety, and development of nuclear power must make safety the top priority.”410 As a result, a
new China National Plan for Nuclear Safety with short-, medium- and long-term actions was ordered
and approval for new plants remained suspended until it was approved.411
In May 2012, the State Council announced it had finished inspecting the country’s existing nuclear
plants, and gave preliminary approval to both a revised 2020 nuclear strategy and a post-Fukushimasafety plan. The revised 2020 nuclear strategy is expected to propose a target of 60-70GWe by2020 412 . The new much stricter standards for new nuclear construction—especially the call for
elimination of the potential for large radiation releases in units built beyond 2016—suggest thatutilities may abandon Gen II plants and switch to next-generation designs413 , which will delay
construction. Despite this, existing designs, were given construction approval at Fuqing 4 andYangjiang 4 in November 2012 as well as a High Temperature Gas reactor at Shidao Bay in December
2012. This raises concerns about how effective the new regime will be with critics saying that theindustry’s rules and guidelines are a decade out of date, and that there is no coherent legal system togovern the use of nuclear energy.414 But, as of early July 2013, no construction starts have occurredsince then.
Safety concerns of the current and future reactor fleet have been raised by Academician He Zuoxiu, aformer state nuclear physicist, who argues that the pace of nuclear development and the diversity ofreactor designs is leading to insufficient actual operating experience, as such he predicts that the “mostprobable” period for a nuclear accident in China is between 2020 and 2030. 415 He had earlier
compared China’s aggressive nuclear power plans with Mao’s disastrous “Great Leap Forward,” andurged building new reactors at a more measured pace, with strong attention to safety, and only on the
coast (a policy that has reportedly been quietly adopted) but with tsunami protection.416
Furthermore, public acceptance of new reactors can no longer be taken for granted -a factor of rapidly
increasing relevance in modern China. Historically, nuclear protests had mainly occurred in Hong
Kong against the Daya Bay facility (both before and after the transfer of sovereignty). However, after
Fukushima, greater public concern coupled with reactors being proposed in up to 16 provinces madewider public engagement on the issue likely. In particular, concerns have been raised over the safety
and public support for inland nuclear power plants. Despite considerable investment in the preparation
for construction projects at Taohuajiang, Pengze and Dafan remain suspended and it is now stated thatno further approval will be given for the construction of inland projects417 . The Pengze nuclear power
plant has been subject to on-going local opposition418, which is spreading to other projects in theregion419.
China’s importance to global new-build is not solely due to construction numbers but the types ofreactors now being built, based on the world’s major reactor vendors most advanced designs.
Westinghouse is building four AP1000 Generation III+ reactors at Sanmen and Haiyang. Construction
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

410

The Guardian “China Suspends Approval for Nuclear Power Plants” 16 March 2011.
WNA, “Nuclear Power in China”, May 2012, see http://www.world-nuclear.org/info/inf63.html, accessed 30
May 2013.
412
Reuters, “China Cabinet Approves Nuclear Safety Plan”, 31 May 2012, see
http://www.reuters.com/article/2012/05/31/china-nuclear-safety-idUSL4E8GV42Z20120531
accessed, 30 May 2013.
413
Zhou, Y, “China Responds to Fukushima”, Bulletin of Atomic Scientists, 28 June 2012
414
Wang Q, “Nuclear Safety Lies in Greater Transparency”, Nature, 28 February 2013
415
Zuoxiu H, “Chinese nuclear disaster “highly probable” by 2030”, China Dialogue, 19 March 2013
416
Hu Zuoxiu, “China must alter nuclear policy (1),” China Dialog, 12 Oct 2011,www.chinadialogue.net/article/show/single/en/4576, accessed 8 July 2013.
417
China.org.cn, “No restart for three inland nuclear power plants”, 26 February2013
418
Yoshioka K, “Fukushima disaster sparks opposition to nuclear plant in China”, 2 March 2012.
419
Zheng C, “Ex-officials battle plan to build Nuclear Project”, Caixin Online, 9 March 2013
http://english.caixin.com/2012-03-09/100366298_1.html
411

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began in April 2009 at Sanmen and at the time it was said that operation would begin in August
2013420, although delays of six to twelve months are reported421 . For the first unit at Sanmen, this issaid to be due to design changes post-Fukushima, while for the remaining three units due to supply
chain issues relating to increasing local content. In 2009, it was said they would cost $1,940/kW, but
the latest figures range from €2,300 to €2,600/kW422 , it is higher than the reported costs for the CRC
1000 at $1,800/kW423. It is suggested that the domestic content across the series of the four reactors
will increase from 30 percent to 70 percent. When purchasing the four reactors China acquired
domestic rights to much of the core AP1000 technology (but not the instrument and control
technology) and the right to sell overseas its own version of the AP1000 with capacities over 1350
MW. Work is underway on the construction of the first domestic hybrids, the CAP 1400, a cooperation between Westinghouse, the State Nuclear Power Technology Corporation (SNPTC) and
Shanghai Nuclear Engineering Research & Design Institute (SNERDI), with construction expected tostart in 2014424 .
In November 2007 AREVA announced the signing of a €8 billion ($11.6 billion) contract with the
China Guangdong Nuclear Power Group, (CGNPC) for the construction of two EPRs in Taishan in
Guangdong Province, and that it will provide “all the materials and services required to operatethem”425. It is said that the cost of the reactors in this deal was €3.5 billion426. At the start ofconstruction this was 40 percent below the starting price of construction of EPRs in Europe.427 The
power plant will be jointly owned by EdF (30 percent) and CGNPC (70 percent). At the time of thestart of construction, the first of these reactors was expected to be completed in October 2013. The
latest press statement suggests that unit 1 should begin operating in 2014, with unit 2 following in
2015428.
In April 2013 China and France signed a series of agreement to cement their relationship on nuclear
issues. This included co-operation on the further development of nuclear reactors and preliminary
agreements for the sale of equipment for an 800 tonne/year reprocessing facility.429
China has also been broadening its ambitions to export nuclear reactors. The most consistent example
is in Pakistan, where despite its being outside the regime of the Non-Proliferation Treaty (NPT), China
has supplied equipment for the two reactors at Chashma, the second of which only entered commercial
operation in May 2011. Construction of units 3 and 4 was said to have begun at the end of 2011 withthe engagement of China Zhongyuan Engineering as the general contractor and China Nuclear
Industry No 5 as the installer, with finance also coming from China and completion expected in 2016
and 2017.430 CGNPC has been in negotiations with Romania’s state-owned Nuclearelectrica to invest
in the completion of units 3 and 4 of the Cernavoda plant in Romania, since other potential partners,
including CEZ (Czech Republic), GDF of France, RWE of Germany and Iberdrola (Spain) havepulled out.431

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
420

WNN, “First Concrete at Sanmen”, 20 April 2009
NIW, “China, Behind the Sanmen-1 Delay”, 7 December 2012
422
NIW, “Wang Declares AP1000s Back on Track”, 23 March 2012
423
NIW, “AP-1000s Delayed by 6-12 Months SNPTC Says”, 17 January 2012
424
Nucleonics Week, “Westinghouse sees new Chinese AP1000 I&C contracts this year”, 14 February 2013
425
AREVA, “China: AREVA and CGNPC Sign the Biggest Contract Ever in the History of Nuclear Power andEnter into a Long-term Commitment. AREVA and CNNC Strengthen Their Links,” press release (Paris: 26
November 2007).
426
WNA, “Nuclear Power in China”, 21 March 2013
427
Wang Q, “Nuclear Safety Lies in Greater Transparency”, Nature, 28 February 2013
428
WNN, “First Fuel Produced for Chinese EPR”, 11 March 2013
429
WNN, “China Approaches Reprocessing Commitment”, 26 April 2013
430
WNN, “Chasma 3 gets its dome”, 22 March 2013
431
AFP, “China's Guangdong mulls investing in Romanian nuclear plant”, 31 October 2012
421

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In recent months, the Chinese industry has also reportedly connected with many other projects aroundthe world. The April 2012 visit of Turkish Prime Minister Erdogan to Beijing was used to discuss
China’s assistance for a proposed nuclear power station at Sinop.
In January 2013, CNNC and Nucleoeléctrica Argentina SA signed two nuclear agreements, anddiscussed further plans on the construction of fourth unit at the Atucha nuclear power plant.432 It is
unclear how many of these proposals will come to fruition, nor whether they would help China’s
domestic nuclear additions by spreading capital costs or perhaps hurt them by diverting scarcetechnical resources and attention.
As with most energy sectors, what happens in China about nuclear power has global impact. In many
quarters there is significant confidence that ambitious targets for domestic construction will be met,
but this should be tempered given the remaining strategic questions over nuclear safety standards,
engineering and skills bottlenecks, increasing environmental opposition, siting problems, and evenbasic economics. Despite China’s central planning system, its world-leading wind and solar
achievements and their steeply falling price must be expected to put increasing competitive pressure
on new-build nuclear prospects, just as in market economies if perhaps through different channels.
India operates 20 nuclear power reactors with a total capacity of 4.4 GW; the majority of these have acapacity of 220 MW per unit. In 2012, nuclear power provided a record 29.6 TWh that covered just
3.6 percent of India’s electricity, slightly below the record level of 3.7 percent already achieved in
2001/02 when nuclear generation was only around 17 TWh.
India lists seven units as under construction with a total of 4.8 GW. Most currently operating reactors
experienced construction delays, and operational targets have rarely been achieved. India’s lifetime
nuclear load factor is only 59.3 percent as of the end of 2012, the lowest of any country operating
more than two units.
India’s 1974 nuclear weapons test triggered the end of most official foreign nuclear cooperation,
including invaluable Canadian assistance. The nuclear weapons tests in 1998 came as a shock to theinternational community and triggered a new phase of instability in the region, including a subsequent
nuclear test series by Pakistan. Various (and different) international sanctions were imposed on thetwo countries.
This state of affairs started to change under U.S. Bush administration’s announcement in 2005 of whatbecame known as the U.S.-India deal. Following intense lobbying by the United States, supported by
France and Russia, the IAEA approved a “safeguards agreement” with India in August 2008, and on
6 September 2008 the Nuclear Suppliers Group (NSG), a 45-country group regulating internationalcommerce to prevent the proliferation of nuclear weapons, granted an exception to its own rules. Thus,
although India is a non-signatory of the NPT, has developed and maintains a nuclear weapons
program, and refuses full-scope safeguards,433 it is still permitted to receive nuclear assistance and tocarry out nuclear commerce with other nations. The reasons for this deviation from the previous
nonproliferation consensus appear to be geopolitical and commercial. France has abstained from any
criticism of India’s nuclear weapons program and has strongly encouraged the NSG to grant India
access to international cooperation. A French parliamentary report states:
Grateful for these diplomatic positions in its favour and conscious about the French technologicalexcellence in this sector, India has logically chosen to make France one of its principal partners.434

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
432

Powell H, “China/Latin America: Argentina and China sign further nuclear agreements”, Plusa Merica, 21
February 2013 http://www.pulsamerica.co.uk/2013/02/21/chinalatin-america-argentina-and-china-sign-furthernuclear-agreements/
433
Comprehensive inspection and verification that all nuclear materials and all nuclear facilities have been used
for declared purposes only.
434
Eric Woerth, “Rapport fait au nom de la Commission des Affaires Etrangères sur le Projet de Loi n°4021,
autorisant l’approbation de l’accord entre le Gouvernement de la République française et le Gouvernement de la
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However, the report also highlights “the problems generated by the law on civil responsibility” that
the Indian Parliament voted in September 2011, in particular because the supplier could be held liablefor potential accidents under some circumstances. Furthermore, a petition filed by prominent lawyer
Prashant Bhushan has requested the Indian Supreme Court to declare the liability legislation“unconstitutional and void ab initio” [meaning to be treated as invalid from the outset]. The outcome
could mean the application of “absolute liability” to nuclear plants. Vendors will then be faced with
the question “whether they are confident enough in the safety of their reactors to risk potential
bankruptcy”.435 In other words, in India, unlike virtually all Western countries, reactor owners or
operators may need to shoulder responsibility for any harm caused by major accidents at their plants,
rather than having their liability limited by special laws unique to their technology.
In addition, an August 2012 report by the Comptroller and Auditor General of India raises the issue ofthe independence of the Atomic Energy Regulatory Board (AERB). The report points to a number of
inadequacies of the nuclear regulatory system in India. Even the international nuclear lobby’s World
Nuclear News noted:
Other abnormalities in Indian regulation include the lack of a requirement for nuclear power plant owners
to have decommissioning plans and secured funds for the work.436

In December 2010, the Nuclear Power Corporation of India Ltd. (NPCIL) and AREVA signed anagreement—though not yet a commercial contract—for the construction of two EPRs (and potentiallyfour more) for a site in Jaitapur and a fuel supply for 25 years.437 The contract reportedly would be
worth some €7 billion ($10 billion) for two EPRs438, a surprisingly low figure considering that the
cost-estimate for the French and Finnish EPRs has escalated to €8.5 billion each. (See Economics
section.)Even before the agreement was signed, as on other sites, opposition against the Jaitapur project was
massive. The Fukushima events triggered a significant increase in opposition. Two Russian-built
reactors at Kudankulam were mostly completed before 3/11, “since when the sudden growth of apowerful local protest movement has effectively brought commissioning to a standstill”.439 The Indian
Government, however, appears intent on starting up the reactors, already years behind schedule. In
May 2013, India’s Supreme Court paved the way for the commissioning of the reactors, which had
been legally challenged by citizens’ groups, arguing that the plant is “in the largest interest of thenation particularly the State of Tamil Nadu”.440 Meanwhile the state of West Bengal has scrapped
another project for up to six Russian reactors at the coastal site of Haripur.441
The current five year plan counts on doubling the currently installed capacity and starting constructionof a further 19 units. Princeton University’s M.V. Ramana concludes a milestone historical assessmentof the Indian program with a question and answer:
Is a rapid and large-scale expansion of nuclear power in India, along the lines projected by the
Department of Atomic Energy (DAE), feasible? The answer that emerges in the course of our excursion
through the history of how the nuclear project has materialized in the country is that is is very unlikely

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
République de l’Inde relatif à la répartition des droits de propriété intellectuelle dans les accords dedéveloppement des utilisations pacifiques de l’énergie nucléaire”, Assemblée Nationale, 18 January 2012.
435
Suvrat Raju, M.V. Ramana, “A New Twist in the Saga of India’s Liability Law”, NIW, April 2012.
436
WNN, “India’s nuclear regulation must improve”, 24 August 2012, see http://www.world-nuclearnews.org/RS_Indias_nuclear_regulation_must_improve_2408121.html, accessed 12 May 2013.
437
AREVA, “India: Agreements Between AREVA and NPCIL for the Supply of Two EPR Reactors and Fuelfor 25 Years,” press release, 6 December 2010.
438“India Signs $9.3 Billion Deal for Areva to Build Two Nuclear Power Plants,” Bloomberg.com,
6 December 2010.
439
WNN, “Cabinet clears way for Kudankulam”, 19 March 2012, see http://www.world-nuclear-news.org/NNCabinet_clears_way_for_Kudankulam-1903127.html, accessed 30 May 2012.
440
WNN, “Kudankulam’s public interest ruling”, 7 May 2013, see http://www.world-nuclear-news.org/NNKundankulams_public_interest_ruling_0705137.html, accessed 14 May 2013.
441
Nucleonics Week, “West Bengal eliminates Haripur as second VVER site: reports”, 25 August 2011.
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and probably impossible. The principal reasons, among many, for this conclusion are the technicalimplausibility of the DAE’s plans, its inability as an organization to learn lessons from its earlier failures,and local opposition.442

Trade journal Nuclear Intelligence Weekly put it more bluntly: “There’s no reason to believe that thecountry can keep this schedule, of course.” Indeed, Indian nuclear planning has been always overly
optimistic, not to say unrealistic. In 1984 a target of 10 GW was set for the year 2000. Almost 30 years
later, not even half of that capacity has been installed. Projections for the future seem even moreastounding (see Table 7).
Table 7: Nuclear Power in India: Planning, Projection or Fantasy?
Indian Forecasting

Capacity„planned“in 1984 for 2000

10 GW

in 2005 for 2012

11 GW

in 2012 for 2017

10 GW

in 2012 for 2023

27 GW

in 2012 for 2032

63 GW

in 2009 for 2050

470 GW©	
  M ycle Schneider Consulting

Capacity
installed
2.7 GW
in ca. 15 years
4.8 GW
in ca. 30 years
10 GW maxin ca. 35 years+12.7 GW
in ca. 10 years?
+58 GW
in ca. 20 years?
x 100
in 40 years?

Sharerealized
27%
43%
?
?
?
?

Sources:	
  various,	
  assembled	
  by	
  MSC	  	
  In contrast, Indian entrepreneurs—largely in the vibrant private sector rather than large state-owned
enterprises and agencies—have proven adept at rapidly scaling competitive, modular, short-lead-time,
renewable technologies. India added 2.3 GW of wind turbines in 2012 (the fourth largest addition in
the world) and now has an installed capacity of wind power of 18.4 GW, compared to 4.8 GW ofnuclear capacity with the contribution of the wind sector to electricity supply having overtaken that ofnuclear power in 2012.

Japan
In Japan nuclear power in 2012 provided about 17 TWh or 2 percent of total electricity compared to18 percent in 2011, 29 percent in 2010 and the historic maximum of 36 percent in 1998.
This result, is obviously a consequence of the tragic events of 11 March 2011 known in Japan andoverseas as 3/11. The triple disaster earthquake-tsunami-nuclear accident that hit Japan on that day
had a profound impact on the nation’s and the world’s environment, economy and energy policy.
In October 2011 the Cabinet office released an energy white paper that dropped the paragraph on the
expansion of nuclear power and instead called for the reduction on the reliance on nuclear power.
Furthermore, the paper stated that the Government “regrets its past energy policy and will review itwith no sacred cows”. 443
Under Japanese law, every nuclear power plant has to be shut down at least every 13 months forinspection and maintenance. As of 26 March 2012, Japan’s main island Honshu was no longer using
nuclear power, when unit 6 at Kashiwazaki-kariwa shut down for refueling, maintenance andinspection. Tomari-3 in Hokkaido was the last unit to go offline in Japan and as of 5 May 2012, all 54
Japanese nuclear power reactors were closed. However, in July 2012, two units at the Ohi plant in the
Fukui Prefecture were restarted, but they remain the only reactors in operation across the country.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

442

M.V. Ramana, “The Power of Promise – Examining Nuclear Energy in India”, Penguin-Viking, 2012,366 pages.
443
Bloomberg, “Nuclear Promotion Dropped in Japan Energy Policy After Fukushima”, 27 October 2011.
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Officially, the Japanese Government declared only four of the Fukushima Daiichi units “permanently
shut down”, the other 50 units remaining “operational” and two units “under construction” in theinternational statistics. It is virtually impossible to imagine that all reactors will return to operation.
However, once the reactors are declared permanently closed, they become liabilities on the balance
sheets of the utilities. Therefore, changing their status will have a profound impact not only on theelectricity generation but on the economic viability of the companies, potentially leading to theirbankruptcy. Japan is still absorbing former NRC Commissioner Peter Bradford’s remark about thefinancial risk revealed by the Three Mile Island accident: “Wall Street learned that a group of licensed
operators no worse than any other could transform a billion-dollar asset into a two billion dollar cleanup in ninety minutes.” 444 At Fukushima, the accident was triggered by natural disaster, but thefinancial reversal was analogous—just one or two orders of magnitude bigger.
On 14 September 2012 the Japanese Government announced that it had adopted an “Innovative
Strategy for Energy and the Environment”, for a zero nuclear power future by the 2030s445. However,
due to lack of clarity, the Government statement immediately gave way to speculations as to theschedule for the shutdowns, and the future of the plutonium fuel program and of the reactors underconstruction.
To further confuse the issue, a statement by the Prime Minster said that “it is rather irresponsible to
make a decisive judgment on the unforeseeable future. We must start with a strategy that has both asecure direction and the flexibility to cope with changes in the situation, without wavering from thebasic policy and also not excessively restricting future decisions”446 .
No reactors can restart until they have conformed to the new guidelines issued by the Nuclear
Regulatory Authority (NRA), which are expected to enter into force in July 2013. The new guidelines
make it compulsory for operators to protect against radiation leaking to the environment through areview of existing reactors and their protection against external natural hazards such as tsunamis andearthquakes. This includes a more indepth review of the seismic conditions for the plants, which may
permanently exclude the restart of some reactors. Secondly, the reactors must be retrofitted to
implement additional measures for severe accident management, such as the prevention of hydrogen
explosions447. The safety reviews are expected to take at least six months and therefore no significant
electricity production from nuclear power will be achieved before 2014, and even then it is likely to be
initially only from the more modern PWR designs448 . It remains unclear to what extent the NRA will
accept restarts while upgrading is under way. The change of government from the nuclear-skeptical
Prime Minister Naoto Kan (who served during the accident) to the nuclear-friendly Yoshihiko Noda to
the nuclear-enthusiastic Shinzo Abe has influence but is far from decisive when many provincial
Governors and most of their constituents oppose nuclear restart.
The Japanese Government is facing unprecedented opposition to nuclear power in the country.
Opinion polls indicate large majorities in favor of a nuclear phase out. Furthermore, opposition seems
to be growing. The update of the IPSOS Mori’s post Fukushima global opinion poll found thatbetween April 2011 and September 2012 a further 10 percent of the popoulation went against nuclear
power.449 Massive demonstrations of unprecedented scale have flooded the streets of Japan’s cities. At
a public event in Osaka on 29 June 2013 in advance of Upper House elections the ruling LDP’s
Secretary General Shigeru Ishiba was the only lawmaker out of nine to vote “No” to the question
about favoring moving towards a non-nuclear future for Japan (see Photo 1).
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

444

Peter A. Bradford, 24 March 2009, see
http://www.nirs.org/reactorwatch/accidents/bradfordtestimony32409tmi.pdf,
445
Government of Japan, “Innovative Strategy for Energy and the Environment, The Energy and Environment
Council, Government of Japan, 14 September 2012.
446
Prime Minister Yoshihiko Noda, Energy and Environment Council, 14 September 2012.
447
Deutsche Welle, “Tough rules for Japanese Nuclear Plants”, 24 June 2013.
448
Jefferies, “Japanese Trading Companies Japanese Nuclear Reactors & New Safety Standards”, 24 June 2013
449
IPSOS 2012, op.cit.
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Japanese media, once docile and quietly consored, have turned increasingly critical not only on themismanagement of the Fukushima disaster, but also the political pressure that has been brought to bear
to restart the nuclear reactors. In a stinging editorial the Director of the Asahi Shimbun Editorial Board
stated on 29 June 2013:
The nation likely does not have the ability to cope with another accident of a similar scale.
If that is the case, the only alternative will be to reduce the number of nuclear plants as quickly as
possible while making safety standards stricter and implementing measures to prepare for the likelihoodof another accident.
That is the brutally frank reality Japan now faces.

Following a meeting between the new Japanese Prime Minister Shinzo Abe and French President
Francois Hollande to cooperate on the development of a nuclear fuel cycle and the export of nuclear
power technology, an editorial in the Japan Times stated: “Mr. Abe’s decision to move forward withthe development of nuclear power technology represents his cynical disregard for the victims of the
Fukushima nuclear crisis”.450
Photo 1: LDP Only Japanese Party to Vote Against Nuclear-Free Japan

Source: Asahi Shimbun, 30 June 2013.

Numerous measures were taken between March and September 2011 to reduce electricity demand.
Their estimated costs ranged from a few yen to a few hundred yen per kWh, in other words from very
cheap to ridiculously high. Now, “METI is studying a ‘Nega-Watt Trade’ and other innovative
programs” and an in-depth revision of the Energy Conservation Law is under preparation.451 Japan’s
target is to cut electricity demand by at least 10 percent by 2030. That target is, according to the Japan

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

450
451

Japan Times, “Cease promoting nuclear power”, 11 June 2013.
IEEJ, “Japan Energy Brief”, n°18, March 2012.

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Times “a moderate one that could be exceeded if the government supports and enacts its policies morethoroughly”452 .
In the meantime, fossil fuel imports have increased significantly, in particular a 20 percent in the useof Liquified Natural Gas (LNG) over the past two years. This increase, coupled with increases in othercountries in the region, such as China, resulted in a significantly higher regional price of gas, which
affected Japanese balance of payments. In April 2013, as a result of higher fuel prices and a weaker
Yen, the price per tonne of LNG reached €816, a level not seen since September 2008.453
In the meantime, the government introduced feed-in tariffs for renewable energy that are significantly
higher than those in Germany or any other country. The tariffs became effective on 1 July 2012 andled to the rapid investment in renewable energy in Japan (chiefly solar, as wind is more constrained byartificial utility rules). In 2012, according to Bloomberg New Energy Finance, the total investment inclean energy in Japan reached $16.3 billion, nearly double the previous year. These investments are
essential if Japan is to increase its use sufficiently to meet the 20 percent target by 2020. But there are
already growing signs that the local demonstration of competitive renewables is starting to splinter thebusiness community’s previously nearly-solid front in support of the old nuclear-centric policy.454
One of the key issues for the future of the power sector in Japan will be its reform and in particular theliberalisation of the market. This was to be a three stage process starting with the creation of an
independent body to oversee supply and demand, followed by the liberalisation of the retail market
and then the separation of retail and power generation, by 2020. However, in June 2013 the bill to
introduce the first stage of the process was abandoned in the Upper House of Parliament.455
Pakistan operates three reactors that provided 5.3 TWh and 5.3 percent of the country’s electricity in2012, both historic maxima. The nuclear load factor has been close to 89 percent. The third unit,
supplied by China, came on line only three days after 3/11. During Chinese Prime Minister Wen
Jiabao’s visit to Pakistan in December 2010, it was reported that China might build another two 650
MWe reactors in the country.456 The Pakistan Atomic Energy Commission (PAEC) indicated a target
capacity of 8.8 GW with 10 installed units by 2030.457 Construction of two 315 MWe units started in2011 at the Chasnupp site with the engagement of China Zhongyuan Engineering as the generalcontractor and China Nuclear Industry No. 5 as the installer, with finance also coming from China.
According to press reports458 , the Finance Ministry has released a modest $4.8 million (465 million
Pakistani rupees) for a fesibility and design study into a second reactor for the Karachi site. The firstunit at the site, KANUPP, a 125 MW CANDU heavy water reactor, was first connected to the grid in
October 1971 and is one of the oldest operating reactors in the world.
In the 1980s, Pakistan developed a complex system to access illegally various components for its
weapons program on the international black market, including from diverse European sources.459
Immediately following India’s nuclear weapons tests in 1998, Pakistan also exploded several nuclear
devices. International nuclear assistance has been practically impossible, given that Pakistan, like
India, has not signed the NPT and does not accept full-scope safeguards, and is currently unlikely to
be granted the same exception as India to the NSG’s export rules. Some Pakistani experts bitterlycomplain about the “simply unfair” differential treatment under the international non-proliferation
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

452

Japan Times, “Renewable energy policy”, 13 May 2013, see
http://www.japantimes.co.jp/opinion/2013/05/13/editorials/renewable-energy-policy/, accessed 30 June 2013.
453
Bloomberg, “Japan Pays Record Price for LNG Imports in April as Yen Weakens”, 31 May 2013.
454
A.B. Lovins, “Asia’s Accelerating Energy Revolution”, 26 March 2013,
http://blog.rmi.org/blog_2013_03_26_2013_Asias_Accelerating_Energy_Revolution
455
Kyodo, “Japan's drive to reform power sector hits snag amid political feud”, 26 June 2013
456
“Nuclear Energy on Agenda as Chinese Premier Visits Pakistan,” Spero News, 17 December 2010.
457“Ten Nuclear Power Plants Planned,” Dawn.com, 12 January 2011.
458
NIW, 14 September 2012, p.10.
459
See Mycle Schneider, “Nucléaire: Paris, plaque tournante du trafic pakistanais,” Politis (Paris), 1989.
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regime and consider that “participation in the NSG is essential if Pakistan is to be able to acquire theequipment and expertise needed to build the nuclear plants that will fill this power gap”.460
On the other hand, according to Pakistan’s Alternative Energy Development Board, the country has
vaste potential resources in wind energy, estimated at 350 GW. Several hundred megawatts of windprojects are currently under development.461 In January 2013, the Korean Solar Energy Company
launched a large 1 GW solar project in Beluchistan that is supposed to help ease power shortages in
the region.
On the Korean Peninsula, the Republic of Korea (South Korea) operates 23 reactors that provided
143.6 TWh (2.4 percent less than in record year 2011) or 30.4 percent of the country’s electricity in2012 (down from a maximum of 53.3 percent in 1987). In addition, four reactors are listed as underconstruction. The first Shin-Uljin unit officially started construction on 10 July 2012. South Korea’s
reactors have shown excellent performance in the past, and held the fourth position of lifetime loadfactors with 86.4percent by the end of 2012. However, due to component and quality control issues,
the annual load factor dropped by almost 10 percent in 2012 to 80.7 percent.
Less than a month after 3/11, the Korea Electric Power Corporation (KEPCO) presented plans todouble installed nuclear capacity to close to 43 GW by 2030 and bring the nuclear share in the power
generation to 59 percent.462 However, observers see a “dramatic political shift against nuclear power inthe year since Fukushima”.463 The Mayor of Seoul, for example, initiated a program to “save away”
the equivalent amount of energy generated by one nuclear reactor. According to an updated 24country study by IPSOS, general support of nuclear power recovered significantly (+18 percent), but
by September 2012 still 51 percent of Korean people polled opposed nuclear energy.464
The newly elected Korean Government under President Park Geun-hye, who came into office inDecember 2012, attempts to support the nuclear industry and to restore public trust after a series ofscandals. In April 2012, the CEO of Korea Hydro & Nuclear Power (KHNP) was forced to resign overthe cover-up of two significant incidents, a 12-minute station blackout at Kori-1 with two emergency
diesels failing to start up on 9 February 2012 and another diesel failure at Yonggwang-2 on
28 March 2012. Both events had not been disclosed for several weeks. 465 In November 2012, a
massive quality control scandal broke and up to 74 investigators inquired about tens of thousands ofitems at the country’s nuclear power plants. In January 2013, the Nuclear Safety and Security
Commission (NSSC) announced:
Over the past 10 years, 13,794 units of 561 items with falsified quality certificates have been supplied to
KHNP, and 6,949 units of 341 items were found installed curently in the nuclear power plants. Almost all
5,258 safety-related items supplied with falsified documents were replaced under witness of site
investigators.466

A total of 20 suppliers and 215 cases of quality record falsification had been identified. In May 2013,
the scandal widened into safety-class control-command cables. After an anonymous report had tipped
off the NSSC, it was confirmed that test reports had been forged and that the test in fact failed underloss-off-coolant-accident conditions. Two operating reactors, Shin-Kori-2 and Shin-Wolsong-1, were
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
460

Zahir Kazmi, “Letter from Pakistan : How an unfair non-proliferation regime undermines nuclear security”,
Bulletin of the Atomic Scientists, 30 August 2012; see http://www.thebulletin.org/web-edition/op-eds/letterpakistan-how-unfair-non-proliferation-regime-undermines-nuclear-security, accessed 15 May 2013.
461
GWEC, “Global Wind Energy Outlook 2012”, November 2012.
462
Ki Hak Kim, “Fueling the Sustainable Future”, 6 April 2011.
463
NIW, “South Korea: Growing Nuclear Skepticism”, 23 March 2012
464
IPSOS, op.cit.
465
NIW, “Kim Out at KHNP Over Reporting Lapses”, 20 April 2012.
466
NSSC, “NSSC to Announce Investigation Results and Preventive Action Plans”, 9 January 2013, see
http://www.nssc.go.kr/nssc/english/release/list.jsp?mode=view&article_no=3750&pager.offset=0&board_no=50
1, accessed 1 June 2013.
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shut down, and the maintenance period of Shin-Kori-1 was extended in order to replace the faulty
cables. Shin-Kori-3 and -4 as well as Shin-Wolsong-2, all three under construction, also had “forged”
quality-control documents and need to replace the incriminated cables.467
In December 2009, South Korea succeeded in securing its first major overseas nuclear deal,“snatching” a multi-billion dollar contract with the United Arab Emirates (UAE) from the world’s
largest builder AREVA, backed by French state utility EDF, for building of four 1.4 GW reactors. In
the meantime, however, cost estimates have soared and financing negotiations have been delayed (seesection on UAE in chapter Potential Newcomer).
Taiwan operates six reactors that provided a record 38.7 TWh or 18.4 percent of the country’s
electricity in 2012 (down from a maximum of 41 percent in 1988). Two 1.3 GW Advanced Boiling
Water Reactors (ABWR) have been listed as under construction at Lungmen, near Taipei, since 1998
and 1999 respectively. Their startup has been delayed many times and they are many years behindschedule. According to the Atomic Energy Council, by April 2013, the first unit was “nearly finished”
and operator Taipower was presently carrying out “on-site testing of operating procedures and systems
functions”.468 In March 2012, the Atomic Energy Minister raised doubt over the safety of the plant.469
In May 2012, media reports gave 2014-15 as the current planned start-up date. Another source has
indicated startup of the first unit “no earlier than March next year”, in 2014, “if there are no further
problems”. 470 The plant is estimated to have cost USD 9.6 billion so far. According to the Minister of
Economic Affairs, the project costs Taipower an estimated NT$400–600 million (USD10–15 million)
for each month of delay.471
Taiwan’s nuclear program has a certain number of very specific problems. The nuclear plants arelocated in areas with high population density, high seismicity and tsunami risks. In addition, with theabsence of a long-term waste strategy, the spent fuel pools are filling up and, in spite of re-racking anddense-packing, the first pools are expected to be full by 2014.472 “The confidence of residents are [sic]feeble on nuclear safety issue”, admitted Taipower Vice-President Hsu Hwai-Chiung in July 2011.
“The license renewal of NPPs will be suspended until National Energy Policies are clear in near
future.”473
The Taiwanese public is increasingly critical towards the country’s nuclear power program and on
9 March 2013 over 200,000 people demonstrated in various cities against the startup of the Lungmen
plant. An opinion survey released in late March 2013 indicated a 73 percent majority in favor of a halt
to the Lungmen plant. On 26 April 2013, the ruling party introduced a bill in the legislature toorganize a national referendum over the future of the Lungmen project. What appears to be an
exemplary exercise of democracy is seen by many as a manouver to get a silent majority for the
project’s completion. The referendum legislation requires a quorum of at least 50 percent to make theoutcome binding, a score difficult to achieve nationwide.
In November 2011, the Government presented a new energy strategy to “steadily reduce nuclear
dependency, create a low-carbon green energy environment and gradually move towards a nuclear	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

467

NSSC, “NSSC Confirms Fake Test Reports of Safety-Class Control Cables”, 29 May 2013, see
http://www.nssc.go.kr/nssc/english/release/list.jsp?mode=view&article_no=3884&pager.offset=0&board_no=50
1, accessed 1 June 2013.
468
Nucleonics Week, “Lungmen critic gives legislators plan for reinspection, oversight”, 2 May 2013.
469
Asia Pulse, “Minister Casts Doubt on Viability of 4th Taiwan Nuclear Plant”, PennEnergy, 15 March 2012.
470
Nucleonics Week, “Lungmen critic gives legislators plan for reinspection, oversight”, 2 May 2013.
471
Focus Taiwan News Channel, “Start Date for Commercial Operation of Nuclear Power Plant Postponed,”
6 January 2011, at http://focustaiwan.tw/ShowNews/WebNews_Detail.aspx?ID=201101060017&Type=aECO.
472
Le Monde, “Taïwan, l’apprenti sorcier du nucléaire”, 8 February 2012.
473
Hsu Hwai-Chiung, “The Impacts on Taipower Nuclear Power Plants after Fukushima Accident”, Taipower,
27 July 2011.
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free homeland”.474 The document released by the Ministry of Economic Affairs’ Bureau of Energy
also announced the shutdown of its oldest reactors at Chinshan (grid connection 1977 and 1978) assoon as the Lungmen reactors come online and the non-renewal of operating licenses beyond a 40year lifetime. That would mean the shutdown of the operating units between 2016 and 2025.

European Union (EU27) and Switzerland
The European Union 27 member states (EU27) have gone through three nuclear construction waves,
two small ones in the 1960s and the 1970s plus a large one in the 1980s (mainly in France). The region
has not had any significant building activity since the 1990s. (See Figure 26.)
In July 2013, 14 of the 27 countries in the enlarged EU operated 131 reactors—about one-third of theworld total—12 fewer than before the Fukushima events and one-quarter below the historic maximumof 177 units in 1989. (See Figure 27.) The vast majority of the facilities, 112 or 85.5 percent, arelocated in eight of the western countries, and only 19 are in the six newer member states with nuclear
power.
In 2012, nuclear power produced 27 percent of the commercial electricity in the EU, down from
31 percent in 2003.475 Nearly half (48 percent) of the nuclear electricity in the EU27 was generated by
one country, France.
Figure 26: Nuclear Reactors Startups and Shutdowns in the EU27, 1956–2013

Source: IAEA-PRIS, MSC, June 2013

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
474

Bureau of Energy, “Ensure Nuclear Security—Steadily Reduce Nuclear Dependency—Create a Low-carbon
Green Energy Environment & Gradually Move Towards a Nuclear-free Homeland”, Ministry of Economic
Affairs, 3 November 2011.
475
EURELECTRIC, “Key Statistics – Edition 2013”, 7 June 2013.
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Figure 27: Nuclear Reactors and Net Operating Capacity in the EU27, 1956–2013

Source: IAEA-PRIS, MSC, June 2013

With the lack of new reactor construction, the average age of the EU’s reactors now stands at 29 years(see Figure 28).
Figure 28: Age Pyramid of the 131 Nuclear Reactors Operated in the EU

Sources: IAEA-PRIS, MSC, July 2013

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Western Europe
In Western Europe (EU15), as elsewhere, the public generally overestimates the significance ofelectricity in the overall energy picture, as well as the role of nuclear power. Electricity currently
accounts for only about one-fifth of the EU15’s commercial primary energy consumption.
As of July 2013, the EU15 was home to 112 operating nuclear power reactors, or 45 units fewer thanin the peak years of 1988/89.
Two reactors are currently under construction in the older member states EU15, one in Finland and
one in France. These are the first building sites in the region since construction began on the French
Civaux-2 unit in 1991. Apart from the French exception and the Sizewell-B reactor in the U.K.
(ordered in 1987), until the reactor project in Finland, no new reactor order had been placed inWestern Europe since 1980.
The following provides a short overview by country (in alphabetical order).
Belgium operates seven reactors and has the world’s third highest share of nuclear in its power mix, at
51 percent in 2012 (down from a maximum of 67.2 percent in 1986). The nuclear plants achieved theirbest productivity level generating 46.7 TWh in 1999 compared to 38.5 TWh in 2012. In 2002, thecountry passed nuclear phase-out legislation that required the shutdown of nuclear plants after
40 years of operation, meaning that (based on their start-up dates) plants would be shut down between
2015 and 2025. On 13 October 2009, the Government issued a 10-page general policy statement that
included one reference to nuclear power: “The government has decided to postpone by 10 years thefirst sequence of the phase-out of nuclear power.”476 However, that government was voted out in June
2010, just prior to voting on supporting legislation to delay the phaseout. Following Fukushima andthe establishment of a new Government the still existing phase-out legislation was left in place and nolegislative initiative has been taken to overturn it, even if the operator GDF-Suez is lobbying hard to
postpone via an extension of “at least 10 years”.477
In the summer of 2012, the operator identified unprecedented numbers of crack indications in thepressure vessels of Doel-3 and Tihange-2 with respectively over 8,000 and 2,000 previously
undetected defects. After several months of analysis including international experts, the Belgian safety
authority FANC asked the operator to carry out a specific test program prior to any restart decision.
However, in late January 2013, AIB-Vinçotte, an international quality-control company based in
Belgium, working on behalf of the Belgian safety authority, stated that “some uncertainty about the
representativity of the test program for the actual reactor pressure vessel shells cannot be excluded”.478
The safety authority’s own subsidiary BEL-V concluded at the same time479 :Indeed there exists no validated procedure neither for evaluating flaws having the morphology andorientation of the hydrogen-induced flaws nor for evaluating thousands of those defects with interactions
between themselves (clustered flaws) because such a situation has never been met (and, as a result,
accepted) in an operating safety-related pressure component like the reactor pressure vessel for which
break exclusion is assumed.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
476

Prime Minister of Belgium, “Déclaration du gouvernement relative à sa politique générale,” 13 October 2009,at http://archive.vanrompuy.belgium.be/files/Statepremier.pdf.
477
Gérard Mestrallet, et al., “Nuclear in Belgium: recent developments”, GDF Suez, 4 November 2011.
478
AIB-Vinçotte, “Synthesis Report Doel165”, 28 January 2013.
479
BEL-V, “Safety Evaluation Report – Flaw indications in the RPVs of Doel 3 and Tihange 2”,
31 January 2013.
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An independent assessment480 equally concluded that “FANC should obtain—before authorizing therestart of the affected reactors—absolute certainty that the flaws will not lead to the failure of thereactor pressure vessel. This is obviously not the case at present and will not be the case even if thecomplementary tests should prove positive”.
However, on 17 May 2013, FANC issued a statement saying that it “considers it safe to restart theDoel 3 and Tihange 2 reactor units”.481 The units restarted in spite of the serious concerns by
independent scientists and reached full capacity respectively on 9 and 11 June 2013. The underlying
issue has not gone away.
Finland currently operates four units that supplied 22.1 TWh or 32.6 percent of its electricity in 2012
(down from a maximum of 38.4 percent in 1986). Finland’s load factor has been constantly amongst
the top five nuclear countries. Although it dropped in 2012 by 3.3 percent, with an annual average of
90.7 percent, it is still number four in the world.
In December 2003, Finland became the first country to order a new nuclear reactor in Western Europe
in 15 years. AREVA NP, then comprising 66 percent AREVA and 34 percent Siemens482, is building a
1.6 GWe EPR under a fixed-price turn-key contract with the utility TVO—an arrangement that
AREVA top managers have admitted in private talks they would “never do again”. The project was
financed essentially on the balance sheets of the country’s leading firms and municipalities under aunique arrangement that makes these customers liable to pay the plant’s indefinite capital costs for anindefinite period, whether or not they get the electricity—a Capex “fixed price” but “take-or-pay
contract”.
Construction started in August 2005 at Olkiluoto on the Finnish west coast. Close to eight years later,
the project is about seven years behind schedule and now 280 percent over budget (see also
Economics section). The plant is currently expected to start up in 2016 and the cost estimate has beenraised to €8.5 billion. It remains unclear who will cover the additional cost: the vendors and TVO
blame each other and are in litigation. “TVO is not pleased with the situation and repeating challenges
with the project scheduling” and admits that “the plant completion may be further delayed”.483
According to TVO, about 75 percent of the installation work has been completed.
From the beginning, the Olkiluoto-3 (OL3) project was plagued with countless management andquality-control issues. Not only did it prove difficult to carry out concreting and welding to technicalspecifications, but the use of sub-contractors and workers from several dozen nationalities madecommunication and oversight extremely complex.
The Finnish regulator STUK has still not yet validated the EPR’s Instrumentation and Control (I&C)
system. TVO stated in February 2013 that “the I&C design has not proceeded as planned” and could
cause further delays.
The repeated construction delays of OL3 are a blow not only to power planning by the utility and to
the 60 large customers involved in the project consortium, but also for the Finnish Government.
In late February 2013, TVO’s Board of Directors proposed a new shareholder loan commitment of€300 million to its shareholders in order to cope with financing costs and maintain a minimum
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

480

Ilse Tweer, “Flawed Reactor Pressure Vessels in Belgian Nuclear Plants Doel-3 and Tihange-2”, March 2013;see http://www.greensefa.eu/fileadmin/dam/Documents/Studies/Flawed%20Reactor%20Pressure%20Vessels.pdf, accessed
1 June 2013.
481
FANC, “FANC experts give positive opinion on restart of Doel 3 & Tihange 2 reactor units”, 17 May 2013,see http://www.fanc.fgov.be/GED/00000000/3400/3430.pdf, accessed 1 June 2013.
482
Siemens quit the consortium in March 2011 and announced in September 2011 that is was abandoning thenuclear sector entirely.
483
TVO, “Information about the start-up of Olkiluoto 3 nuclear power plant unit”, press release,
11 February 2013, see http://www.tvo.fi/news/32, accessed 1 June 2013.
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25 percent share of shareholders capital or loan. 484 Credit rating agency Fitch neverthelessdowngraded TVO from BBB+ to BBB in late May 2013485 - see Table 4 for more details.
OL3 was part of the government’s strategy to achieve its target of a zero-percent increase of 1990
emissions under the Kyoto Protocol. The lack of an operational OL3 will force Finland to use
emissions trading to compensate for the GHG’s produced in the country.
The problems produced by the OL3 project have not prevented TVO from filing an application, in
April 2008, for a decision-in-principle to develop “OL4”, a 1–1.8 GWe reactor to start construction in2012 and enter operation “in the late 2010s”.486 The decision was ratified by the Finnish Parliament on
1 July 2010. But already significant delays have emerged. In late March 2012, TVO invited fivereactor vendors—AREVA, GE Hitachi (GEH), Korea Hydro and Nuclear Power (KHNP), Mitsubishi
and Toshiba—to submit bids, which were transmitted in January 2013. A license application isplanned for mid-2015 and start-up “around 2020.”487
In parallel, Fortum Power is planning a similar project, known as Loviisa-3. In addition, in
January 2009, the company Fennovoima Oy submitted an application to the Ministry of Employment
and the Economy for a decision-in-principle on a new plant at one of three locations—Ruotsinpyhtää,
Simo, or Pyhäjoki—which has first been narrowed down to the latter site and to being an EPR or
ABWR. Startup was planned for 2020. Bids were received on 31 January 2012 from AREVA andToshiba. 488 In August 2012, a group of minority stakeholders left the Fennovoima consortium,
followed by E.ON, which sold its 34 percent share in April 2013 to Voimaosakeyhtiö SF, aconsortium of 60 companies and municipalities, that already held the remaining 66 percent.
Fennovoima ended the formal tender process in February 2013, inviting Toshiba to direct negotiations
over a 1300 MW ABWR design and effectively dropping the EPR from the competition. In addition,in April 2013, to the general surprise of AREVA and Toshiba, Fennovoima invited Rosatom to direct
negotiations over its 1200 MW PWR AES-2006. Fennovoima stated that it will select the plant
supplier “during 2013”. 489 However, while Toshiba and AREVA were explicitly mentioned ingovernment and parliament planning authorizations, this is not the case with Rosatom. Greenpeace has
already announced it will challenge the decision in court, “if the government shows any signs ofapproving a Rosatom deal under the current criteria”.490
France is the worldwide exception in the nuclear power sector. In 1974, the Government launched theworld’s largest public nuclear power program in response to the oil crisis in 1973. After four decadesof unchanged support for nuclear power the new Government under President François Hollande haspromised a significant shift in energy policy.
In 2012, France’s 58 reactors491 produced 407.4 TWh or 74.8 percent of the country’s electricity, adrop of almost 3 percent. Nuclear generation and its share in France’s power mix reached theirmaximum in 2005, with respectively 431.2 TWh and 78.5 percent. The annual load factor dropped
another 2.3 percent to 73.6 percent, compared to countries that exceed 90 percent.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

484

TVO, “TVO Board of Directors proposes new shareholder loan commitment to its shareholders”,
27 February 2013, see http://www.tvo.fi/news/39, accessed 1 June 2013.
485
FitchRatings, “Fitch Downgrades Teollisuuden Voima Oyj to ‘BBB’, Outlook Stable”, 24 May 2013.
486
TVO, “Construction of a Nuclear Power Plant Unit at Olkiluoto – General Description – OL4,”
www.tvo.fi/www/page/2840/, August 2008.
487
WNN, “Bidding starts for Olkiluoto-4”, 26 March 2012, see http://www.world-nuclear-news.org/NNBidding_starts_for_Olkiluoto_4-2603124.html, accessed 2 June 2012.
488
Fennovoima, “Fennovoima received bids for nuclear power plant”, press release, 31 January 2012.
489
Rosatom, “Fennovoima invites ROSATOM to direct negotiations”, press release, 5 April 2013, see
http://www.rosatom.ru/en/presscentre/news/2df4ec804f260b62bd2afd2c0ad82648, accessed 1 June 2013.
490
Nucleonics Week, “Fennovoima, considering smaller reactor, opens negotiations with Rosatom”,
11 April 2013.
491
All pressurized water reactors, 34 x 900 MW, 20 x 1300 MW. and 4 x 1400 MW.
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France has a significant base load overcapacity that has led to the “dumping” of electricity onneighboring countries and stimulated the development of highly inefficient thermal applications ofelectricity. A historical winter peak-load of 102 GW in February 2012, (up from 97 GW in
December 2010) is to be compared with an installed capacity of 128.7 GW492. However, during thecoldest days in February 2012, France imported up to 13 GW of power, of which Germany
contributed about 3 GW (see also the following section on Germany).
France’s seasonal peak electricity load has increased rapidly since the mid-1980s, due mainly to thewidespread introduction of electric space and water heating in an effort to absorb the nuclear surplus –an issue anticipated by critics in the 1970s. Over 30 percent of French households now heat withelectricity, the most wasteful form of heat generation because it results in the loss of most of the
primary energy during transformation, transport, and distribution. The difference between the lowest
load day in summer and the highest load day in winter is now over 70 GW. A drop of 1C° in outside
temperature is equivalent to an increase in capacity of 2.3 GW. Short-term peak load cannot be met
with nuclear power but rather by either fossil fuel plants or expensive peak-load power imports.
Considering its existing nuclear overcapacity’s and the average age of its reactors (28.4 years in mid2013), France should not need to build any new units for a long time. In addition, the nuclear share in
the power mix is too high; lifetimes of operating units are planned to be extended; the shutdown of thegaseous diffusion uranium enrichment plant will save huge amounts of electricity493, and several
nuclear plants should be made redundant through efficiency.
If the French Government and EDF opt to proceed with construction of a new unit, then this is not torelief capacity constraints but because the nuclear industry faces a serious problem of maintaining
competence in the field.
In December 2007, EDF started construction of Flamanville-3. The FL3 site encountered qualitycontrol problems with basic concrete and welding similar to those at the Olkiluoto-3 (OL3) project inFinland, which had started two-and-a-half years earlier. As in Finland, the extensive employment offoreign workers exacerbated communication and social problems.494 It took until April 2012 for the
French safety authority to judge satisfactory the instrumentation and control (I&C) system solution
proposed by EDF for FL3. The project is now at least four years late and not expected to start
commercial operation before 2016. The price tag has more than doubled since construction start andhas been increased to €8.5 billion in December 2012, €2 billion more than in 2011—a “terrible
publicity”, as trade journal Usine Nouvelle noted. 495 In addition, the Italian partner ENEL that held
12.5 percent of the project decided to quit the project. EDF is obliged to buy back ENEL’s shares foran estimated €690 million.
Beyond the EPR building problems, the two state-owned companies EDF and AREVA continue tofight over several strategic issues: follow-up agreements on reprocessed uranium conversion, uranium
enrichment, reprocessing and plutonium fuel fabrication, as well as the overall industrial strategy.
Even before the Fukushima accident, but especially after 3/11, there have been major difficulties withlarge investment projects—in Italy, the United Kingdom, and the United States—and all are taking atoll on the balance sheet and credit rating of France’s major nuclear companies. While EDF
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

492

Capacity increased by 1,865 MW net in 2012, mainly from solar (+1,012 MW or +40 percent), wind(+757 MW) and natural gas (+981) additions, which largely compensated for the shutdown of just under
1,000 MW of oil and coal plants. Source: RTE, “Bilan électrique 2012”, January 2013.
493
The EURODIF plant at Tricastin consumed the production of up to three reactors and is scheduled for shutdown by the end of 2012.
494
The French Nuclear Safety Authority (ASN) notes in an inspection report that a translator, one of only two
French speaking individuals in a team of steel workers, “had difficulties to understand the questions” theinspectors asked, per ASN, “Letter to the Director of the FL3 Construction Project,” 29 December 2010.
495
Usine Nouvelle, “EDF a évité de pire sur l’EPR de Flamanville”, 7 December 2013, see
http://www.usinenouvelle.com/article/edf-a-evite-le-pire-sur-l-epr-de-flamanville.N187560, accessed
1 June 2013.
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accumulated a huge debt burden that increased through 2012 by €8 billion to €41.5 billion net($54 billion), AREVA lost €2.5 billion in 2011 and another €100 million in 2012. AREVA’s debt
increased by €400 million—equivalent to an additional provision for OL3—to almost €4 billion.496 In
December 2011, Standard & Poor’s downgraded AREVA to ‘BBB-’ rating as well as its stand-alone
credit profile of ‘bb-’.”497 It has not changed since. AREVA’s share price had plunged in 2012 by up
to 88 percent of its peak 2007 value, while EDF shares had lost up to 85 percent of their value over thesame period, hitting the bottom in January 2013. In December 2012, Moody’s downgraded EDF’s
perspective from stable to negative.498
France also operates many other nuclear facilities, including uranium conversion and enrichment, fuelfabrication, and plutonium facilities. France and the United Kingdom are the only countries in the EUthat engage in reprocessing, or separating plutonium from spent fuel. The U.K. has announced it willabandon reprocessing in the near future. France’s two La Hague facilities are licensed to process
1,700 tonnes of fuel per year; however, all significant foreign clients have finished their contracts andhave stopped plutonium separation. The La Hague operator AREVA NC therefore depends entirely on
the domestic client EDF for future business, yet reprocessing’s high cost burdens financially stressed
EDF.
The current Government under President Hollande constitutes without any doubt a major rupture not
only with his predecessor Nicolas Sarkozy, but also with previous administrations. For the first timesince 1974, a French Government has announced plans for the closure of the oldest operating reactors(Fessenheim-1 and -2, connected to the grid in 1977), the abandoning of a new-build project (Penly-3)
and the systematic reduction of the share of nuclear generated electricity (from about 75 to 50 percent
by 2025). Currently a major national energy debate is ongoing that will lead to framework legislation
to be submitted to the National Assembly before the end of 2013.499
Four days after 3/11, Germany’s conservative and pro-nuclear Government decided to shut down 8 ofits fleet of 17 reactors. Originally for a three-month period, the closure of almost half of the German
reactors turned out to be permanent. Nuclear power plants generated 94.1 TWh net in 2012—a drop of
29 percent compared to pre-3/11 year 2010—and provided 16.1 percent of the electricity (gross) in the
country (1.5 percent less than in 2011 and down from the historic maximum of 30.8 percent in1997)500.
On 14 March 2011, Chancellor Angela Merkel abruptly announced putting plant life extension planson hold and initiated a major re-shift of the country’s nuclear policy. On 6 June 2011 the Government
passed far-reaching energy transition legislation, including a revision (the 13th) of the Nuclear Law(Atomgesetz). The legislation passed the Bundestag on 31 July 2011 almost by consensus, and cameinto force on 6 August 2011. Key characteristics include:• The operating licenses will expires once the production credit is used up and at the latest
according to Table 5. This meant that the eight units that had been shut down after 3/11 losttheir operating license with the coming into force of the legislation.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

496

AREVA, “Résultats annuels 2012”, 28 February 2013.
According to Standard & Poor’s (S&P) credit rating categories, BBB- is the lowest S&P investment grade. If
S&P did downgrade AREVA by one additional notch, it would slip into the junk bond category. S&P points outthat AREVA’s current rating incorporates three notches of uplift above the company's SACP [Stand-Alone
Credit Profile] for “extraordinary state support”. In other words, AREVA’s SACP of bb- is already “junk” andjust one notch off “highly speculative”.
498
EDF, “Reference Document 2012”, 5 April 2013.
499
For background see Mycle Schneider, “France's great energy debate", see
http://bos.sagepub.com/content/69/1/27.abstract, 9 p. and Mycle Schneider, “Nuclear power and the Frenchenergy transition: It’s the economics, stupid”, see http://bos.sagepub.com/content/69/1/18.abstract, 9 p.; Bulletinof the Atomic Scientists, January-February 2013, the site has a paywall, accessed 2 June 2013.
500
These figures are from AGEB, “Bruttostromerzeugung in Deutschland von 1990 bis 2012 nach
Energieträgern”, February 2013.
497

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• The production credit can be transferred from older to newer plants.
The legislative package included seven other laws ranging from energy efficiency (€3 billion per year
for buildings) and increase in the use of renewable energy (with a new target of a 35 percent share ofelectricity by 2020) to natural gas as well as the large-scale extension of the grid system.
The German nuclear phase-out decision has generated widespread interest from other countries andhas led to a number of unfounded claims, such as that ‘Germany would have to replace nuclear
electricity through increased coal consumption or nuclear power imports from France’. In fact,
Germany made notable progress in energy efficiency, and gross electricity consumption decreased by
1.4 percent in 2011 and another 1.3 percent in 2012, while renewable energy generation increased by
32 percent over the same period and represented 22 percent in the power mix in 2012. However, cheap
coal prices on the world market led to perverse effects: while production from natural gas plants
dropped by almost 20 percent over the past two years, lignite plants boosted production by 9 percent
over the same period and coal plants in 2012 reached the same production level as pre-3/11 year 2010.
These effects, however, are expected to be brief and temporary.501
Table 5: Closure Dates for German Nuclear Reactors 2011-2022
Reactor Name
(type, net capacity)
Biblis-A (PWR, 1167 MW)
Biblis-B (PWR, 1240 MW)
Brunsbüttel (BWR, 771 MW)
Isar-1 (BWR, 878 MW)
Krümmel (BWR, 1346 MW)
Neckarwestheim-1 (PWR, 785 MW)
Philippsburg-1 (BWR, 890 MW)
Unterweser (BWR, 1345 MW)
Grafenrheinfeld (PWR, 1275 MW)
Gundremmingen-B (BWR, 1284 MW)
Philippsburg-2 (PWR, 1402 MW)
Brokdorf (PWR, 1410 MW)
Grohnde (PWR, 1360 MW)
Gundremmingen-C (BWR, 1288 MW)
Isar-2 (PWR, 1410 MW)
Emsland (PWR, 1329 MW)
Neckarwestheim-2 (PWR, 1310 MW)

Owner/Operator
RWE
RWE
KKW Brunsbüttel502
E.ON
KKW Krümmel503
EnBW
EnBW
E.ON
E.ON
KKW Gundremmingen504
EnBW
E.ON/Vattenfall505
E.ON
KKW Gundremmingen
E.ON
KKW Lippe-Ems506
EnBW

End of license(latest closure date)

6 August 201131 December 201531 December 201731 December 201931 December 2021
31 December 2022

First Grid
Connection
1974
1976
1976
1977
1983
1976
1979
1978
1981
1984
1984
1986
1984
1984
1988
1988
1989

Notes:	
  PWR=Pressurized	
  Water	
  Reactor;	
  BWR=Boiling	
  Water	
  Reactor	
  Sources: Atomgesetz, 31 July 2011, Atomforum Kernenergie May 2011; IAEA-PRIS 2012

The key driver behind the increase in hard coal and lignite burning is the price signal on the European
power exchange market, not the nuclear phase-out. Europe has a large structural overcapacity, so in
the absence of a significant carbon price, there has been an increasing incentive to operate existing
lignite and coal fired power plants – especially in 2012 when an unusually cold winter helped drive up
competing natural-gas prices. Germany does not have any capacity problems, on the contrary, thecountry never exported more than in 2012 with 23 TWh net, a 3.7 fold increase over the previous year,
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
501

A.B. Lovins, “Germany’s renewables revolution”, 17 April 2013,
http://blog.rmi.org/blog_2013_04_17_germanys_renewables_revolution, and blog on the disinformation
campaign about Germany’s Energiewende, http://blog.rmi.org, in press, July 2013
502
Vattenfall 66,67%, E.ON 33,33%503	
  Vattenfall 50%, E.ON 50%	  504
RWE 75%, E.ON 25%
505
E.ON 80%, Vattenfall 20%
506
RWE 87,5%, E.ON 12,5%
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and due to its highly competitive wholesale prices, (which renewable power has sharply reduced in thepast few years), Germany is the only country that consistently exports electricity to France.
The Fukushima events and the political reaction accelerated industrial strategic shifts. Electronics
giant Siemens, which built all of Germany’s nuclear plants and exported more, announced in
September 2011 that, after having left AREVA NP, the joint consortium with AREVA, it would quit
the nuclear sector entirely. Siemens Chairman Peter Löscher declared that “we will not enter into theoverall responsibility or the financing of the construction of nuclear power plants anymore. This
chapter is closed for us. Siemens will be a motor for the German energy transition (Energiewende)”.507
In addition, Siemens entered into a “strategic alliance” with Boeing in the U.S. for the development
and implementation of micro-grids. German utilities RWE and E.ON also pulled out of nuclear
projects in various countries, including in the Bulgaria, Finland, the Netherlands and the U.K.
The Netherlands operates a single, 40-year-old 480 MW PWR that provided 3.7 TWh or 4.4 percentof the country’s power in 2012 (down from a maximum of 6.2 percent in 1986). For comparison,
renewables, mainly biomass and wind, accounted for over 10 percent in power generation in 2012.508
In June 2006, the operator and the Government reached an agreement to allow operation of the reactor
until 2033.509
On 23 January 2012, the utility DELTA announced it was putting off decision on nuclear new-build“for a few years” and that there would be “no second nuclear power at Borssele for the time being”.
The company provided the following reasons for its decision: “The financial crisis, combined with thesubstantial investment needed for a second nuclear power plant, current investment conditions,overcapacity in the electricity market and low energy prices.”510
In early 2004, Borssele operator EPZ extended a reprocessing contract with AREVA NC. This is acurious decision considering that there are no possibilities in the Netherlands of using separated
plutonium. Therefore, EPZ has paid the French utility EDF to get rid of the plutonium. However, more
recently EPZ has applied for a license to load MOX fuel into the Borssele reactor, which was granted
in June 2011.511 The reasons for the change in plutonium management remain unknown. In France, theextracted plutonium has zero book value and negative market value.
Spain operates seven reactors, an eighth unit was shut down at the end of 2012. Nuclear plants
provided 58.7 TWh or 20.5 percent of the country’s electricity in 2012 (maximum of 38.4 percent in1989). Beyond the de-facto moratorium that has been in place for many years, the previous PremierJose Luis Zapatero announced at his swearing-in ceremony in April 2004 that his government would“gradually abandon” nuclear energy, while increasing funding for renewable energy. The first unit
(José Cabrera) was shut down at the end of 2006. Zapatero confirmed the nuclear phase-out goal
following his reelection in 2008, and then Industry Minister Miguel Sebastian has stated, “there will
be no new nuclear plants.”512
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
507

Der Spiegel, “Kapitel abgeschlossen”, 17 September 2011. One month earlier, Siemens had announced that it
had entered a “strategic alliance” with the U.S. company Boeing to develop micro-grids to boost efficiency andthe use of renewable energies. Source: Siemens, Press Release, 8 August 2011.
508
Statstics Netherlands, “More renewable electricity generated”, 26 February 2013, see http://www.cbs.nl/enGB/menu/themas/industrie-energie/publicaties/artikelen/archief/2013/2013-3785-wm.htm, accessed
2 June 2013.
509
WNA, “Nuclear Power in the Netherlands,” www.world-nuclear.org/info/inf107.html, accessed 2 June 2013.
510
DELTA, “DELTA puts off decision for a few years, no second nuclear plant at Borssele for the time being”,
press release, 23 January 2012
511
Ministry of Economic Affairs, Ministry of Foreign Affairs, 4th National Report of the Netherlands, September
2011, prepared for the Fourth Review Conference of the Joint Convention on the Safety of Spent FuelManagement and on the Safety of Radioactive Waste Management, May 2012.
512“Spain Insists on Energy Saving, Not Nuclear Plants,” Reuters, 21 January 2009.
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Spain has, however, been implementing both uprating and lifetime extensions for existing facilities.
Licenses for the operating units would have run out between 2010 and 2018; however, in 2009 theGovernment extended the operating license of the then 40-year old Garoña plant to 2013, and in 2010
it granted the 30-year old Almaraz-1 plant a 10-year extension and a capacity increase of 7 percent.
The 28-year old Almaraz-2 plant also will be uprated.513 In February 2011, the Spanish parliament
amended the Sustainable Energy Law, deleting from the text a reference to a 40-year lifetime
limitation and leaving nuclear share and lifetime to be determined by the government.514
Nevertheless, on 16 December 2012, Garoña was shut down definitively. The operator Nuclenor had
calculated that further operation of the 446 MW plant would not be economic. Not only would
Nuclenor have to invest about €120 million to upgrade the 42-year old plant, but it would also have to
face a new tax of €153 million in 2013 following an energy tax reform that was overdue in Spain.
Spain is one of only three countries that increased opposition to nuclear energy since April 2011,
according to a September 2012 update of a 24-country study by IPSOS: 63 percent of those polled
oppose nuclear power, 6 percent more than in the previous study.515
The added capacity from Spain’s nuclear uprating (64 MW at Almaraz so far) remains negligible
compared to the country’s surge in renewables. With an installed renewable electricity capacity of
34 GW (end of 2012), almost five times larger than its nuclear capacity, Spain is number four in theworld.516 Spain is also number four in the world in installed wind capacity, number six in installed PV
capacity and a leader in concentrated solar power plants with over 2,500 MW installed, with over
800 MW added in 2012 alone.517 Renewables have met over 30 percent of the Spanish electricity
demand for the past three years and over half in spring 2013.
Sweden operates 10 reactors that provided 61.5 TWh or 38.1 percent of the country’s electricity in2012 (down from a maximum of 52.4 percent in 1996). Sweden’s per capita power consumption isamong the highest in the world, due primarily to the widespread and inefficient thermal use ofelectricity. In recent years, however, Sweden has had negative growth rates in residential electricity
consumption.518
Sweden decided in a 1980 referendum to phase out nuclear power by 2010. The referendum took place
at a time when only six out of a planned 12 reactors were operating; the other six were still underconstruction. It was therefore effectively a “program limitation” rather than a “phase-out” referendum.
Sweden retained the 2010 phase-out date until the middle of the 1990s, but an active debate on the
country’s nuclear future continued and led to a new inter-party deal to start the phase-out earlier butabandon the 2010 deadline. The first reactor (Barsebäck-1) was shut down in 1999 and the second one(Barsebäck-2) went off line in 2005.
On 5 February 2009, the parties of Sweden’s conservative coalition government signed an agreement
on energy and climate policy that defines ambitious renewable energy and energy efficiency targets
and calls for the scrapping of the Nuclear Phase-Out Act. In June 2010, the parliament voted by a tightmargin (174/172) to abandon the phase-out legislation.519 As a result, new plants could again bebuilt—but only if an existing plant is shut down, meaning that the maximum number of operating
units will not exceed the current ten. This puts Sweden many years away from potential new
construction. Trade journal Nuclear Intelligence Weekly notes: “In 2012 Vattenfall asked the regulator

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

513

“Spain Approves Increase in Nuclear Power Output, Expansion Says,” Bloomberg.com, 4 January 2011.
“No Limits for Spanish Reactors,” WNN, 17 February 2011.
515
IPSOS, op.cit.
516
PEW, “Who is Winning the Clean Energy Race?”, PEW Charitable Trust, April 2013.
517
PEI, “What are the future prospects for utility-scale CSP?”, May 2013.
518
JRC, “Energy Efficiency Status Report 2012”, 2012.
519“Swedish Government Overturns Nuclear Ban,” www.neimagazine.com, 21 June 2010.
514

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for more clarity regarding the newbuild process, but 2025 is the earliest date for any new units.”520 In
the meantime utility Vattenfall envisages to extend lifetimes of five of its seven units at Forsmark andRinghals to 60 years. The objective for Ringhals-1 and -2 is a 50-year lifetime.521
Operators have pushed uprating projects to over 30 percent: at Oskarshamn-2 a 38 percent capacity
increase is under way while a 33 percent uprate has been implemented at Oskarshamn-3 with a twoyear delay. Work at Oskarshamn-2 is also seriously delayed and not now expected to be completed
before April 2014.522
Swedish public opinion remains split over general nuclear power acceptance. A 2012-update to a 24country survey gives proponents a scant 52 percent majority.523
The United Kingdom operates 16 reactors as of 1 July 2013. Nuclear plants provided 64 TWh or
18.1 percent of the country’s electricity in 2012 (down from a maximum of 26.9 percent in 1997). The
first-generation Magnox reactors, with 11 stations, have all been retired, except for one at Wylfa,
which is to close by the end of 2014.524 The seven second-generation stations, the Advanced Gascooled Reactors (AGR), are also at or near the end of their design life, although the owners now plan
to extend their life by seven years to 40 years with retirements only in 2016–29. The newest plant,
Sizewell-B, is the United Kingdom’s only PWR and was completed in 1995.
The industry has a long history of economic and technical problems. (See the chapter Economics of
Nuclear Power), right up through the past decade: In 2004 the government prevented privately owned
nuclear generator British Energy from going into liquidation. While the state-owned nuclear fuel andtechnology company BNFL was also effectively bankrupt because it could not meet its liabilities, theGovernment split up the company, passing the physical assets (and its costly decommissioning
obligations) to a new agency, the Nuclear Decommissioning Authority (NDA), while the capabilities
were privatized.
The NDA is now responsible for decommissioning all Britain’s civil nuclear facilities except those
owned by British Energy, a discounted liability525 estimated in 2013 to be in excess of £58 billion ($90
billion)526, up from less than £34 billion ($53 billion) in 2007. The NDA inherited negligible funds forthis task, relying partly (and increasingly) on government grants and partly on income from thefacilities still in operation, including one remaining Magnox reactor, the THORP reprocessing plant,
and the Sellafield MOX Plant (SMP) a plutonium fuel manufacturing plant. Both of the latter
facilities, however, have been plagued by very serious technical problems that have kept theiroperation significantly below expectations, if they were operating at all. An internal Government
report on the SMP, released in June 2013, revealed that the plant had cost the taxpayer £2.2 billion(US3.4 billion) and that it was “not fit for purpose”527 . Both plants are to be retired.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
520

NIW, “Potential and Existing Global Nuclear Newbuild Projects Open to International Vendors”,
15 March 2013.
521
Vattenfall, “Vattenfall plans to provide nuclear power for up to 60 years”, press release, 22 May 2013, see
http://www.vattenfall.com/en/pressreleasedetailhidden.htm?newsid=943A721F600C4F72AF3AC1D4F96C601A, accessed 2 June 2013.
522
OKG, “Early Indication of Delays in Modernisation of Oskarshamn 2”, 23 April 2013, see
http://www.okg.se/en/Media/News/Early-Indication-of-Delays-in-Modernisation-of-Oskarshamn-2/, accessed
2 June 2013.
523
IPSOS, op.cit.
524
Magnox, “Fact and figures”, see http://www.magnoxsites.co.uk/our-sites/wylfa/facts-and-figures, viewed
5 June 2013.
525
The recent Nuclear Decommissioning Authority Annual Reports only give discounted figures. In the 2007/08
report the discounted £40.7 billion turn into an undiscounted £63 billion.
526
Nuclear Decommissioning Authority, ”Annual Report and Accounts 2012/13”, 2013.
527
Independent, “Revealed: £2bn cost of failed Sellafield plant”. 9 June 2013.
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In 2008, the Labour Government of Gordon Brown started to organize the framework of a new-build
program. In July 2011, the Government released the National Policy Statement (NPS) for Nuclear
Power Generation.528 The eight “potentially suitable” sites considered in the document for deployment“before the end of 2025” are exclusively current or past nuclear power plant sites in England or Wales.
529
Northern Ireland and Scotland530 are not included.
EDF Energy, wholly owned by French state utility EDF and currently the only remaining utility with aconcrete investment plan, was given planning permission to build two reactors at Hinkley Point inApril 2013. In February 2013 Centrica withdrew from the Hinkley project saying that “since our initialinvestment [in 2008], the anticipated project costs in new nuclear have increased and the construction
timetable has extended by a number of years531 ." However, the Government remains in negotiation
with EDF over the electricity price guarantee for the project which is estimated to cost £14 billion for
two EPRs (see Economics of Nuclear Power)532. It is unclear when these negotiations will reach aconclusion and what impact EU State Aid approval will have. Recent reports suggest that final
European Commission approval of the Government’s Contract for Difference (CFD) scheme will takeat least 18 months, if granted at all, and as of July 2013 the review process had not even begun533.
Therefore, even if EDF and the U.K. Government reach an agreement on the strike price, construction
would only begin before January 2015, if EDF had confidence in the final outcome of the State Aidreview. Independent analysts suggest such confidence may not prove justified.
Two other consortia are considering investment in new nuclear in the U.K.. Horizon nuclear wasbought by Hitachi from E.ON and RWE for an estimated price of £700 million (USD 1 billion). The
company has submitted its ABWR for technical review, whilst making it clear that its continuation in
the project will depend on the outcome of the EDF negotiations with the Government 534 . The
remaining consortium, Nugen, is now a 50:50 partnership between Iberdrola and GDf-Suez after the
British utility SSE pulled out in 2011. The consortium is planning to make an investment decision
around 2015.
The only non-EU Western European country that operates nuclear power plants is Switzerland. It
operates five reactors that generated 24.5 TWh and covered 35.9 percent of the country’s electricity
consumption in 2012 (down from a maximum of 44.4 percent in 1996). Until after 3/11, the nuclear
phase-out option never gained a sufficient majority, but the “Swiss-style” referenda have maintainedan effective moratorium on any new project over long periods of time. A local referendum on
13 February 2011 saw a slim 51/49 percent majority for future replacement of the 40-year old
Mühleberg reactor that is expected to shut down by 2022. That same day, a cantonal referendum on a
proposed geological repository in Nidwalden turned into a fiasco for its proponents, with 80 percent ofvoters refusing the nuclear waste disposal project.535
However, Fukushima had a significant impact in Switzerland. Only three days after 3/11, theGovernment suspended the procedures around license requests for new-build. Opinion polls a week
later showed that support for new-build nuclear power had plunged by 34 points, from 55 percent to

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
528

DECC, “National Policy Statement for Nuclear Power Generation”, July 2011.
Bradwell, Hartlepool, Heysham, Hinkley Point, Oldbury, Sizewell, Sellfield, and Wylfa.
530
The Scottish government is opposed to new build and said it would not allow replacement of the Torness andHunterston plants once they will be shut down (likely in 2016 and 2023, respectively). Only 18 percent of theScottish people supported new build in a pre-Fukushima poll, The Scotsman, “Only 18% of Scots Say ‘Yes’ to
New Nuclear Power Stations”, 27 September 2010.
531
Guardian, “Centrica withdraws from new UK nuclear projects”, 4 February 2013.
532
See also numerous items in the Essential News section on the web www.WorldNuclearReport.org.
533
ICIS, “European approval of UK’s CFD subsidies may set-back launch – DECC”, 21 June 2013.
534
Telegraph, “Hitachi reluctant about UK nuclear reactor plan”, 14 April 2013.
535“Bern Says Yes to Nuclear Power Plant,” swissinfo.ch, 13 February 2011.
529

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21 percent in two months.536 On 8 June 2011, the Swiss parliament voted in favor of the phase-out of
nuclear power in the country at the end of the projected lifetime of the last operating reactor in 2034.
Since then, a number of initiatives have attempted to modify the schedule, seeking either to accelerateor to slow down the process. While there seems to be a durable consensus in the country that any newbuild initiative is off the table, the Government has initiated a process called Energy Strategy 2050
that does not fix any precise shutdown dates and aims to keep the existing reactors operating “as longas they are safe”. The Strategy includes measures to reduce energy consumption and to boost
renewable energies. The Government intends to articulate its Energy Strategy 2050 as “indirect
counter proposal” to the “Nuclear Phase-out Initiative” (Sortir du nucléaire) launched in early 2013.537
Various environmental, clean energy and anti-nuclear groups have initiated a campaign to limit the
lifetime of the nuclear plants to 40 years and thus shut down the last reactor by 2029. A national
petition drive was launched in late May 2013.538

Central and Eastern Europe
In Bulgaria, nuclear power provided 14.9 TWh or 31.6 percent of the country’s electricity in 2012
(down from a maximum of 47.3 percent in 2002), with generation occurring at the remaining two unitsof the Kozloduy plant. Around 14 percent of the electricity produced in Bulgaria is exported. In
reaction to an agreement during the 1992 G7 summit, implemented as part of Bulgaria’s accession to
the EU, the Bulgarian Government agreed to close the four VVER 440-230 designed units at
Kozloduy, two of which were closed in 2002 and two in 2006, as they were deemed unsafe. Bulgaria
has received €870 million ($1.14 billion) from the EU as compensation for the closure, fordecommissioning, waste management and alternative energy sources. Despite this considerable grant,
it is estimated that there remains a €579 million shortfall in the budget to decommission the units andthe Government does not have a commitment to meet this shortfall. “The absence of sufficient funding
arrangements puts the completion of the decommissioning processes at risk.”539
Construction of a reactor at the Belene site began in 1985 but was suspended following the politicalchanges in 1989 and formally stopped in 1992, due in part to concerns about the geological stability ofthe site. In 2004, a call for tender for completion of the 2 GW of nuclear capacity was made and sevenfirms initially expressed interest. In October 2006, Russia’s ASE consortium, which involves the
French nuclear constructor AREVA, Germany’s Siemens, and Bulgarian firms, was awarded thecontract, valued at the time at €4 billion ($5.8 billion). However, the deal failed to materialize as theWestern partners pulled out. This led in November 2010 to a new memorandum of understanding(MoU) with the Russian state energy company Rosatom to re-establish the Belene Power Company
with 51 percent initially being held by NEK. The most recent consortium proposed to start
construction by October 2011. But in September 2011 the Russian company responsible for the exportof reactors (AtomStroyExport) and the state utility (NEK) extended their pre-construction agreement
until March 2012.
The Belene story took another twist in March 2012 when the project was officially cancelled by thePrime Minister. He stated “We just can't afford to pay the total cost of the project, which will reach
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
536

AREVA, “Impact of Fukushima event on nuclear power sector – Preliminary assessment”, 25 March 2011.
Schweizerische Eidgenossenschaft, Bundesrat, “Bundesrat legt Energiestrategie 2050 als indirekten
Gegenvorschlag zur Atomausstiegsinitiative vor”, 15 March 2013, see
http://www.news.admin.ch/message/index.html?lang=de&msg-id=48168, accessed 5 June 2013.
538
Schweizerische Energiestiftung, “40 Jahre sind genug – Jetzt Petition unterzeichnen”, 22 May 2013, see
http://www.energiestiftung.ch/aktuell/archive/2013/05/22/40-jahre-sind-genug-jetzt-petition-unterzeichnen.html,
accessed 5 June 2013.
539
European Court of Auditors, “EU Financial Assistance For The Decommissioning Of Nuclear Plants In
Bulgaria, Lithuania And Slovakia: Achievements And Future Challenges”, Special report No 16, 2011
http://bookshop.europa.eu/en/eu-financial-assistance-for-the-decommissioning-of-nuclear-plants-in-bulgarialithuania-and-slovakia-pbQJAB11014/
537

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some 10 billion euros. And there is no way we can make future generations pay.”540 Atomstroyexport
announced on 11 September 2012 that it has increased its claim against NEK to €1 billion for losses
connected with the cancelled Belene project.541
However, soon after the announcement, the Cabinet decided to allow construction of a 7th andpotentially an 8th nuclear reactor at Kozloduy, although the Government made clear it will notparticipate in the project but will leave it to the private market. In January 2013 the CEO of theKozloduy power plant said that negotiations were ongoing with a number of companies and that a newreactor could be in operation by 2022.542
A referendum was held in January 2013 in which a majority called for the continuation in the use of
nuclear power, although the turnout at 21 percent was far under the 60 percent required to make thereferendum binding, but rather required the Parliament to vote on the issue.543 This vote took place inMarch 2013, permanently ending the Belene project. The options for new developments in Kozloduy
was left open, but remain unlikely.
The Czech Republic has six Russian-designed reactors in operation at two sites, Dukovany andTemelín. The former houses four VVER 440-213 reactors, and the latter two VVER 1000-320 units.
Between them, they produced a record 28.6 TWh, 35.3 percent of the country’s electricity in 2012.
Temelín was the focus of considerable controversy since a decision was taken to restart construction in
the mid-1990s after being halted in 1989. The two reactors were eventually started in 2000 and 2002,
with financial assistance from the U.S. Export-Import Bank and I&C technology supplied byWestinghouse.
In July 2008, CEZ announced a plan to build two more reactors at Temelín, with construction to startin 2013 and commissioning of the first unit in 2020. In March 2010, CEZ announced that discussions
had begun with three vendor groups prior to the bid submission: a consortium led by Westinghouse, aconsortium of Škoda JS, Atomstroyexport, and OKB Gidropress; and France’s AREVA. 544 In
February 2011, the final delivery date was shifted to 2025.545 In October 2011 CEZ asked for tenders
from three companies (AREVA, Westinghouse and Atomstroyexport with Skoda) for a turnkey
contract for the construction of two units plus nine years’ worth of fuel. In October 2012, AREVA was
excluded from taking any further part in the process as it was said to have failed to meet thecommercial and technical requirements. AREVA is appealing the decision. However, the other bidders
also have problems and CEZ requested that both the remaining consortium improve their bids in allareas.546 In July 2013 CEZ announced that negotiations with the consortium would continue until atleast October 2013.547
The financing of any future new-build in Czech Republic, as in the U.K. and other EU countries, isfaced with the basic problem that the current market price for electricity falls below the break-evenpoint for nuclear new-build. In this case, the Finance Minister has stated the electricity from newreactors at Temelin would cost €60-65/MWh, well above the current market price of €40. 548
Consequently, CEZ is looking for a Contract for Difference, along similar lines to the U.K., which
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

540

Reuters, “UPDATE 2-Bulgaria abandons Belene nuclear plant plans”, 28 March 2012,
http://www.reuters.com/article/2012/03/28/bulgaria-nuclear-idUSL6E8ES7A420120328, accessed 5 June 2013.
541
NIW, “Russia Fires €1 Billion Claim for Belene Losses After Westinghouse Entry”, 14 September 2012.
542
Novinite.com, “CEO of Bulgaria’s Kozloduy NPP: Unit 7 may be Functional by 2020-22”, 28 January 2013.
543
BBC, “Bulgaria nuclear vote 'invalidated by low turnout'”, 27 January 2013.
544
WNA, “Nuclear Power in Czech Republic,” January 2013. http://www.world-nuclear.org/info/CountryProfiles/Countries-A-F/Czech-Republic/#.UW_xnaI3vX4
545
Reuters, “Czech CEZ Puts off Temelin Expansion Deadline to 2025,” 18 February 2011.
546
Bloomberg, “CEZ Says Temelin Atomic Plant Bidders Must Improve Offers”, 25 March 2013
547
Wall Street Journal Europe, “CEZ Postpones Deadline for Decision on Temelin Nuclear Tender”, 2 July
2013.
548
Prague Daily Monitor, “Kuba: Decision on Temelín can't be based solely on power prices”, 17 April 2013
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leads to a Government guaranteed electricity price for a fixed, multi-decade, period (see Economics
section for more information).
The Dukovany plants have operated since the first half of the 1980s and have been the subject ofengineering changes to extend the life of the reactors while simultaneously expanding their output by
about 15 percent. The operators envisage that the units will continue operating until 2025.
Hungary has only one nuclear power plant at Paks, which houses four VVER 440-213 reactors thatprovided 14.8 TWh or 45.9 percent of the country’s electricity in 2012 (down from a maximum of
51.4 percent in 1990). The reactors started commercial operation in the early 1980s and have been thesubject of engineering works to enable their operation for up to 50 years accompanied by a 20 percent
increase in capacity. In April 2003, the site’s second reactor experienced the country’s worst-evernuclear accident, rated on the international scale as a “serious incident” (INES Level 3), which
resulted in evacuation of the main reactor hall and the venting of radioactivity to the outsideenvironment. The reactor was out of operation for 18 months. Despite this, in December 2012 the
Hungarian Atomic Energy Authority completed a review, set to enable the first unit, which started
operating in 1982, to operate until 2032. Similar approvals are expected for the other units.549
In March 2009, the Hungarian parliament approved a government decision-in-principle to build
additional reactors at Paks.550 The proposed additional units (5 and 6) “will not generate extra power
but make up for the output of the phased-out blocks.”551 Russian assistance seems to be the preferred
option, and Hungary’s foreign minister has indicated that expansion of the Paks plant would be part ofa “package deal” on outstanding economic issues with Russia.552 Prime Minister Viktor Orban said in
December 2011 that the goal is to have nuclear power provide 60 percent of the country’s electricity
needs, compared with around 40 percent now.553 Nevertheless, Hungary has started preparations for atender procedure that also should include other designs. It furthermore started a transboundary
environmental impact assessment that notified all EU member states, Ukraine and Switzerland. In
June 2012 it announced that it hoped that a reactor design would be chosen by 2014-15 withconstruction to start by 2017-18. A separate company has been set up to build the new units, which
could enable an equity investor of up to 50 percent554. Meanwhile, according to a post-Fukushima
survey, in April 2011, a 62 percent majority of Hungarians opposes new-build and a surprising
80 percent consider nuclear’s viability “limited and soon obsolete”.555 In a September 2012 updated
edition to the survey, opposition to nuclear power shrank but still held a 53 percent majority.556
Romania’s Cernavoda nuclear power plant hosts Europe’s only CANDU (Canadian-designed heavy
water) reactors. The plant project was initiated under the regime of Nicolae Ceausescu in the 1970s
and was initially proposed to house five units. Construction began in 1980 on all the reactors, in partusing funding from the Canadian Export Development Corporation, but this was scaled back in theearly 1990s to focus on unit 1. The unit was completed in 1996 at an estimated cost of around $USD
2.2 billion, nearly a decade late. The second unit, also completed with foreign financial assistance (aC$140 million [$USD 146 million] Canadian loan and a €223 million [$324 million] Euratom loan)
was connected to the grid in August 2007. The two reactors generated 10.6 TWh or 19.4 percent of
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

549

World Nuclear news, “New Lease of Life for Paks”, 8 January 2013
John Shepherd, “Hungary’s Parliament Paves Way to Build New Reactor Unit,” NucNet, 31 March 2009.
551
Caboodle.hu “Hungary Mulls Plans to Build New Nuclear Blocks.”, 14 January 2011.
552
Realdeal.hu “Hungary, Russia Seek to Resolve All Outstanding Issues in One Package, Says FM”, 21 January
2011.
553
Bloomberg ”Hungary Targets Expansion of Nuclear Energy Use”, 15 December 2011
http://www.businessweek.com/ap/financialnews/D9RL10OO1.htm
554
Nuclear Intelligence Weekly, “Hungary: Newbuild Company Launched”, 10 August 2012
555
IPSOS-2011, op.cit.
556
IPSOS-2012, op.cit.
550

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Romania’s electricity in 2012 (down from 20.6 percent in 2009). In 2012, Romania had the highest
load factor in the world with 92.8 percent.
Plans are being actively developed to complete two additional units at the power plant. In November
2008, an investment agreement was signed between SNN and ENEL of Italy, CEZ of the Czech
Republic, GDF Suez of France, and RWE Power of Germany (with each having 9.15 percent) as wellas Iberdrola of Spain and ArcelorMittal Galati of Romania (with both having 6.2 percent).
Commissioning of unit 3 was due initially in October 2014 and unit 4 in mid-2015; however, this has
since been revised, with the first unit not expected to be completed until 2016 at the earliest. In
January 2011, two months before Fukushima, CEZ sold its shares to Nuclearelectrica, and GDF Suez,
RWE, and Iberdrola also withdrew from the project, explaining: “Economic and market uncertainties
surrounding this project, related for the most part to the present financial crisis, are not reconcilable
now with the capital requirements of a new nuclear power project.”557
In late 2012, the Government sent letters to CEZ, GDF SUEZ, RWE and Iberdrola inviting them backinto the project, but there has been no reported response to the request. Despite this the Government
believes that it can still complete the project and has given the project until the end of 2013 to findfinancial partners. As Minister of Economy Varujan Vosganian stated, “We do not have enough funds
to finance the construction of the reactors 3 and 4.”558 According to the Curierul National, the latest
feasibility study conducted by Ernst & Young shows that the investment required to build reactors 3
and 4 is €7.67 billion - almost double the estimates of 2008 of €4 billion.559 It has been suggested that
China Guangdong Nuclear Power Group (CGN) is in talks to purchase 40 percent of an equity stake inthe two new reactors.560
In Slovakia, the state utility Slovak Electric (SE) operates all four nuclear power plants at two sites:
Bohunice, which houses two VVER 440 units, and Mochovce, which has two similar reactors. In
2012, these provided 14.4 TWh or 53.8 percent of the country’s electricity production (down from amaximum of 57.4 percent in 2003). Of the three other reactors that once existed at Bohunice, the first,
A1, was closed after two meltdown accidents in the late 1970s. Two older VVER 440-230 reactors
were closed in 2006 and 2008 as part of the 1992 G7 agreement and the EU-accession partnershipagreement. The two remaining operational units were the subject of both uprating (from 440 MW to
505 MW each) and upgrading (extending their operating lives to 40 years), which would enable thestation to operate until 2025.561
In October 2004, the Italian national utility ENEL acquired a 66 percent stake in SE and, as part of its
bid, proposed to invest nearly €2 billion ($2.9 billion) in new nuclear generating capacity, including
completion of the third and fourth blocks of Mochovce. In February 2007, SE announced that it wasproceeding with this initiative and that ENEL had agreed to invest the lower amount of €1.8 billion($2.6 billion). In July 2008, the European Commission gave a conditioned opinion on the Mochovce 3
and 4 project, noting that the reactor did not have the “full containment” structure used in the mostrecent nuclear power plants planned or under way in Europe and requesting that the investor andnational authorities implement additional features to withstand a potential impact from a small
aircraft.562

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

557

GDF-Suez, RWE, and Iberdrola, “GDF-Suez, RWE and Iberdrola Have Decided Not to Continue toParticipate in the Cernavoda Nuclear Project in Romania,” press release, 20 January 2011.
558
The Diplomat Bucharest, “Power play: the sorry saga of Romania's energy projects”, February 2013
559
Curierul National, “Nuclearelectrica dry before listing”, google translate of original article, 4 April 2013 see;
http://www.curierulnational.ro/Eveniment/2013-04-04/Nuclearelectrica,+uscata+inainte+de+listare
560
Nuclear Intelligence Weekly, Briefs-Romania, 2 November 2012
561
TheDaily.sk, “SE Switches on Two Upgraded Nuclear Power Units,” 11 October 2010.
562
European Commission, “Commission Issues Its Opinion on Units 3 and 4 of the Slovak Nuclear Power Plant
of Mochovce,” IP/08/1143 (Brussels: 5 July 2008).
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Construction at Mochovce restarted on 3 December 2008. The units were expected to commence
operation in 2012 and 2013. Initially €2.775 billion was allocated to the completion of the project.563 It
is now expected that unit three will be completed in 2014 and unit 4 in 2015, with a revised total
budget of €3.8 billion.564
In Slovenia, the Krsko nuclear power plant was the world’s first reactor to be owned jointly by two
countries, Croatia and Slovenia. The reactor, a 688 MW Westinghouse PWR, was connected to thegrid in 1981 and is due to operate until 2021. The output, 5.2 TWh in 2012, is shared between the twocountries and covered 36 percent of Slovenia’s power consumption that year (down from a maximumof 57.4 percent in 2003). Discussions remain ongoing for the construction of a second reactor at thesite; a decision has been delayed several times in both countries.
In April 2013 the newly appointed Infrastructure Minister, Samo Omerzel, said that he wanted tofocus on completing work on the thermal and hydro power stations and would reconsider thecompletion of a second reactor at Krsko.565
The Slovenian state-owned utility, GEN Energija, was reported to be in turmoil in March 2013 after ajudge overturned the board’s decision to dismiss its Director General, Martin Novsak. The reason forhis dismissal was that he concealed a report from IRSN, the Technical Support Organization (TSO) of
the French Nuclear Safety Authorities that advised against construction of a second unit on the
grounds of seismic concerns. In a letter to GEN Energija, IRSN Director General Jacques Repussard
states that “this new and serious finding does not allow concluding in a favorable manner as regards
the suitability of the Krsko II sites for the implementation of a new nuclear power plant”.566 In
addition, Repussard states: “IRSN considers that it is of utmost importance that the possible
implications on the safety of the existing plant of this fault capability, as well as its potential structural
relationship to nearby faults, be addressed without delay.” In a response dated 26 February 2013, GEN
Energija argues that IRSN’s conclusions on site suitability “might be premature” and that GEN “iscurrently conducting a comprehensive field investigation to develop a greater understanding offeatures on Libna Hill”, the incriminated fault line close to the Krsko site.567

Former Soviet Union
Armenia has one remaining reactor at the Medzamor (Armenia-2) nuclear power plant, which issituated within 30 kilometres of the capital Yerevan and provided 2.1 TWh or 26.6 percent (downfrom 45 percent in 2009) of the country’s electricity in 2012. The reactor is an early Soviet design, a
VVER 440-230, and in 1995, a U.S. Department of Energy document stated: “In the event of a serious
accident… the reactor’s lack of a containment and proximity to Yerevan could wreak havoc with thelives of millions.”568
In December 1988, Armenia suffered a major earthquake that killed some 25,000 people and led to therapid closure of the reactors in March 1989. During the early 1990s and following the collapse of theformer Soviet Union, a territorial dispute between Armenia and Azerbaijan resulted in an energy
blockade against Armenia that led to significant power shortages, resulting in the Government’s
decision in 1993 to re-open unit 2, the younger of the two units.
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

563

WNA, “Nuclear Power in Slovakia”, April 2013, http://www.world-nuclear.org/info/CountryProfiles/Countries-O-S/Slovakia/#.UXeiuaI3vX4564
The Slovak Spectator, “Mochovce to be completed in 2014/15”, 8 April 2013
565
ANSA Med, “Slovenia: minister, Krsko nuclear plant plan to be reviewed”, 3 April 2013
566
IRSN, DG Jacques Repussard, letter to GEN Energija DG Martin Novsak, dated 9 January 2013.
567
GEN Energija, DG Martin Novsak, letter to IRSN DG Jacques Repussard, dated 26 February 2013.
568
DOE, Office on Energy Intelligence, Most Dangerous Reactors: A Worldwide Compendium of Reactor Risk
(Washington, DC: May 1995).
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The closure of Medzamor is linked, by the Government to the construction of a new nuclear power
plant.569 The EU is critical of this linkage stating: “In the EU’s view it remains doubtful whether suchaction is needed in order to generate sufficient replacement capacity. The country has developed
enough alternative energy sources to replace the 400 Megawatt currently stemming from Medzamor.
Current Armenian ideas go however towards export of energy.”570 In October 2012, the Armenia
Government announced that it would operate the Medzamor unit until 2026. This led to Turkishauthorities calling for the immediate closure of the power station.571
The new reactor is planned to be a 1000 MW unit with negotiations continuing with the Russianauthorities, including the signing of an inter-government agreement in August 2010. However, theGovernment has yet to attract funding for the project that was estimated by a U.S.-funded feasibility
study to cost at as much as $5 billion572 and commissioning is now not expected until 2020 at theearliest.
Russia has one of the most aggressive nuclear power construction programs in the world with10 reactors under construction and suggestions of deals imminent for further projects all over theworld. However, a more careful review shows an industry that has historically over-promised and has
failed to meet its domestic targets and deliver on declared international sales.
In 2012, nuclear power provided 161.1 TWh or 17.8 percent of Russian electricity, the same level as
the record year of 2009. However, across the country there is significant regional variation with forexample nuclear power providing 30 percent in the European part of the country. Russia is one of the
few countries in which nuclear power’s contribution has been increasing, although slowly as twenty
years ago it provided 12 percent. There are 33 reactors in operation, four first-generation VVER 440230s and 11 RBMKs (the Chernobyl type), four are small (11 MW) BWRs used for cogeneration in
Siberia, one is a fast breeder the BN-600, and 13 are second-generation light water reactors (twoVVER 440-213s and 11 VVER 1000s).
The life extension of the RBMK reactors is an important issue as the regulator (Rostekhnadzor) issued
the licenses for lifetime extension nuclear units without public hearing and without environmental
impact assessment. However, there are on-going aging problems with the first unit at Leningrad which
was mothballed in the first part of 2013, while it is decided how to address the swelling in the graphite
moderator.573
During 2012 construction started on one reactor, the Baltic-1, a VVER 1200, near Kaliningrad, thefirst new construction start for nearly two years. The project is subject to international opposition as
the Environmental Impact Assessment does not comply with Russian norms and has not beenadequately discussed with neighboring countries. 574 In May 2013, construction of Baltic-1 was“reported halted”575, “as the possibility to export its power appears less certain”, due to lower-thanexpected demand and thus lack of investments in transmission infrastructure.576 It was later reported
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

569

Asbarez “IAEA Head Inspects Medzamor Nuclear Plant”, 18 April 2012 http://asbarez.com/102433/iaeahead-inspects-medzamor-nuclear-plant/
570
European Commission, “European Neighbourhood and Partnership Instrument, Armenia, Country Strategy
Paper, 2007-2013.” European Neighbourhood Policy
571
USAID, “Turkey renews demands for ‘immediate closure’ of Armenian nuke plant”, 5 November 2012,
USAID web site, http://www.armesri.am/News.html
572
USAID, “Government extends service life of Metsamor NPP for another ten years”, 19 October 2012,
USAID web site, http://www.armesri.am/News.html
573
Nucleonics Week, “Russian regulator gives Smolensk-1 Operating Life Extension to 2022”, 17 January 2013574
15min.it, “Russian experts join criticism of Kaliningrad nuclear facility”, 19 September 2012
575
Bellona, “Baltic NPP debacle: Construction reported halted, possibly mothballed”, 30 May 2013, see
http://www.bellona.org/articles/articles_2013/baltic_npp_debacle, accessed 23 June 2013.
576
WNN, “Grid concerns for Baltic project”, 11 June 2013, see http://www.world-nuclearnews.org/NN_Grid_concerns_for_Baltic_project_1106131.html, accessed 11 June 2013.
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that “construction was frozen for two years”, 577 while the project remains “under construction”
according to IAEA statistics.
The VVER 1200 is the most widely adopted reactor design in Russia, with four others underconstruction and a number of further units planned. However, to date, none are operational and they
have been subject to construction delays. The two units at Novovoronezh, when commissioned in2009 were expected to start up in 2012 and 2013578, but are now expected in 2014 and 2016.579 There
are two more reactors at Leningrad II, where the first unit is expected to be commissioned in 2014
with the second unit is now only expected in 2016, two years late.580 Controversy remains over thecooling for the reactors which will extract water from the Baltic Sea; a request to change the design
was supported by the St. Petersburg and Leningrad Oblast Legislative Assemblies.
Included in the IAEA’s list of new-builds are three units that were started in the 1980s. These include
two earlier VVER reactors at Rostov (due for completion in 2014 and 2017) and an RBMK at Kursk,
the latter of which Rosatom (the State nuclear energy corporation) abandoned in February 2012.
Also under-construction is the Beloyarsky-4 (BN-800) a fast breeder reactor. Construction of thereactor first started in 1985, but was stopped following Chernobyl. At the time of the restart of theconstruction, it was said that much of the infrastructure was already completed581 and that it would becompleted in 2012. It is now expected to be completed in 2014 or 2015. The project is said to havebeen delayed by lack of funds. Also included in the construction list are two 35 MWe so-called
floating reactors, (KLT-40S), which will be housed on a single vessel. These were ordered in February
2009 and expected to be delivered to the customer at the end of 2012582, but are now expected only in2014. Critics of the project point out that the risk of accidents on a floating nuclear plant is greatly
increased because it is even more susceptible to the elements, subject to threats of piracy and if
deployed widely will increase the risks of nuclear material proliferation.583
More than most countries a key issue for Russia will be the aging of its nuclear fleet. Currently, theworking life of a reactor is considered to be 30 years and 17 of Russia's nuclear reactors are 30 ormore years old.584 To counter this, plans were announced in 2010 for life extensions of the oldest
reactors, which would include extending the life span and expanding the capacity of the VVER 440s
and RBMK reactors by 15 years and the VVER-1000 for 25 years.
For decades, the nuclear sectors in Russia and the former Soviet Union have promised that it would
increase its electricity production. In 1992, Minatom announced plans to double nuclear energy

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  

577

15 Min.lt, “Rosatom orders conservation of unfinished nuclear power plant at Kaliningrad”, 4 June 2013, see
http://www.15min.lt/en/article/world/rosatom-orders-conservation-of-of-unfinished-nuclear-power-plant-inkaliningrad-529-341922, accessed 6 July 2013.
578
WNN, “Construction starts at second Novovoronezh-II unit”, 14 July 2009 http://www.world-nuclearnews.org/NN-Construction_starts_at_second_Novovoronezh_II_unit-1407094.html
579
WNA, “Nuclear Power in Russia”, February 2013 http://www.world-nuclear.org/info/CountryProfiles/Countries-O-S/Russia--Nuclear-Power/#.UULxO6LwnX4
580
WNN, “Construction starts at Leningrad II”, 27 October 2009, http://www.world-nuclear-news.org/NNConstruction_starts_at_Leningrad_II-2710084.html
581
NucNet, “Beloyarsky-4 Construction On Schedule, Says Russia”, 15 December 2006
http://www.analys.se/lankar/Internat/NucNet/internatNucRew50_06.htm, accessed 7 June 2013.
582
NEI “KLT-40S nuclear barge project still afloat”, 9 March 2010, see
http://www.neimagazine.com/features/featureklt-40s-nuclear-barge-project-still-afloat/, accessed 11 March 2013
583
NTI, “Floating nuclear reactors could fall prey to terrorist, experts say”, 13 August 2010, Global Security
Newswire, see http://www.nti.org/gsn/article/floating-nuclear-reactors-could-fall-prey-to-terrorists-experts-say/,accessed 11 March 2013
584
IEA, “Russia”, US Energy Information Administration, 18 September 2012,
http://www.eia.gov/countries/cab.cfm?fips=RS, accessed 7 June 2013.
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capacity by 2010585, but instead it increased by only 40 percent.586 In June 2010 the Government
revised its latest target which would see 43 GW of nuclear capacity by 2030, implying a near doublingof the existing capacity. Rosatom’s long-term strategy for 2050 envisages nuclear providing 4550 percent of electricity by 2050 and 70-80 percent by the end of the century.587 Sergei Kiriyenko, thechief of Rosatom, said that by 2030 it wants to build 38 reactors in Russia and 28 abroad, mainly inEurope and Asia.588
Russia has exported reactors in the past, including to Iran (where Russian engineers completed theBushehr plant), India and China. In addition, most of the plants in Central and Eastern Europe werebuilt using Soviet designs. The most concrete plans for new-build are in similar areas, including in
China, India and Ukraine, where six reactors are being built. Less defined plans are said to be forArgentina, Bangladesh, Belarus, Czech Republic, Jordan, Syria, Turkey, Vietnam, andVenezuela.589,590 (For an assessment of these projects, see national country reports and the Newcomer
section). However, with the majority of these proposed sales to countries that currently don’t have any
nuclear power programs, there are no prospects for rapid construction and a high probability that they
won’t go beyond paper proposals.
Ukraine has 15 reactors in operation with an installed capacity of 13 GW, which provided 84.8 TWhor 46.2 percent of the country’s electricity in 2012 (down from a maximum of 51.1 percent in 2004).
In addition to the operating reactors, the country has four closed reactors at Chernobyl and two
reactors under-construction at Khmelnitski.
Chernobyl was the site of the world’s worst nuclear accident, in 1986, when unit four suffered amassive explosion and fire which lead to radioactive contamination across the Eurasian continent.
However, it did not result in the immediate closure of the stations. Instead the remaining units wererestarted and unit 2 operated until it suffered a further fire in 1991. Unit 1 was then closed in 1996 andin December 2000 as part of an international agreement to finance measures to build a sarcophagus
around unit 4 and undertake remedial work near the station. As of the end of 2010, a total of$990 million had been pledged by national governments and the European Commission to theChernobyl Shelter Fund. This, along with a project build an interim spent fuel store, will require an
additional €740 million.591
Since the Chernobyl accident, construction has not started on any new reactors, although a number ofprojects which were started before 1986 have been completed. The most recent was in 2004, the 2ndunit at Khmelnitsky. Consequently, the average age of reactors in Ukraine is now 25 years. As with
Russia, in Ukraine many of the reactors are now approaching the end of their 30-year design life andthey will either have to close or undergo life extension programs. In March 2013, the European Bankfor Reconstruction and Development (EBRD) awarded the state-owned nuclear operator, Energoatom,a €300 million loan for an upgrading program at all the country’s reactors. The total cost of the
program is expected to be €1.45 billion, with further funding, also of around €300 million, to come
	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
585

Federal Research Division, “Russia Country Studies”, Library of the US Congress, http://countrystudies.us/,accessed March 2013
586
BP, “BP Statistical Review of World Energy” 2012
587
Nuclear News, “Russia speeds up nuclear investment”, 22 November 2012, see http://www.world-nuclearnews.org/NP_Russia_speeds_up_nuclear_investment_2211121.html, accessed 7 June 2013.
588
Enformable, “Putin dubs 20 year construction of nuclear power plant ‘renaissance’ of atomic energy”,
12 December 2011, see http://enformable.com/2011/12/putin-dubs-20-year-construction-of-nuclear-power-plantrenaissance-of-atomic-energy/, accessed 7 June 2013.
589
PowerMag, “Russia’s Nuclear Mission”, 1 August 2010, http://www.powermag.com/nuclear/RussiasNuclear-Mission_2867_p4.html, accessed 7 June 2013.
590
WNA, “Nuclear Power in Russia”, February 2013, http://www.world-nuclear.org/info/CountryProfiles/Countries-O-S/Russia--Nuclear-Power/#.UUghJhfwnX4591
EBRD, “Chernobyl 25 years on: New Safe Confinement and Spent Fuel Storage”, European Bank for
Reconstruction and Development, http://www.ebrd.com/downloads/research/factsheets/chernobyl25.pdf, 2011
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from the EU through the Euratom loan facility592 . The project is expected to be completed by 2017.
Energoatom claims that the upgrading program “will impact only the future scope of works
concerning the lifecycle extension of the operating power units, but will not influence the decision oflife extension”593. This is an artificial separation as the upgrading program is not economic without
extending the operating lives and many of the reactors would have to close before the upgrading
program was complete.
In October 2008, Atomstroyexport, of Russia, was said to have been awarded the contract from thecompletion of the 3rd and 4th units at Khmelnitsky, at a cost of $5-6 billion594. In February 2011,
Russia and Ukraine signed an intergovernmental agreement to resume work on the third and fourth
units. Russia is to finance the design, construction, and commissioning of the two reactors, as well as
any services and goods the country supplies. In September 2012 the Verkhovaya Rada (Parliament) of
Ukraine adopted in the first reading the draft laws on the construction of the third and fourth reactors,
with 80 percent of the financing expected to come from Russia and the remainder coming fromEnergoatom. Critics of the project highlighted that Ukraine is already a net exporter of electricity.595
Ukraine is rapidly increasing its electricity exports, with a 50 percent increase in 2011 over theprevious year596 and a similar increase in 2012. Electricity exports from Ukraine in 2012 in monetary
terms were estimated at $574.8 million, with exports to Belarus totaling $231.4 million, to Moldova$52.7 million, Hungary $224.3 million, Poland $50.7 million, Romania $9.9 million, and Slovakia$5.8 million597 . The EBRD claims that their nuclear project will enable Ukraine to increase its exports
and that the project should ”allow Ukraine greater flexibility to trade with the EU”.598

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
592

EBRD, “Nuclear Power Plant Safety Upgrade Programme”, European Bank for Reconstruction andDevelopment, accessed March 2013, http://www.ebrd.com/english/pages/project/psd/2011/42086.shtml
593
Energoatom, “Ecological Assessment Report, main report”, 31 January 2012
http://www.energoatom.kiev.ua/atachs/EARMR310112.pdf
594
Moscow News, “Russia signs deal with Ukraine on finishing Khmelnitsky nuclear power plant”, 9 June 2010
595
Little Skylark, “Verkhovna Rada Decided To Finish The Khmelnitsky NPP”, 6 September 2012,
http://littleskylark.com/blog/verkhovna-rada-decided-to-finish-the-khmelnitsky-npp/, accessed 7 June 2013.
596
WNU, “Ukraine Increases Electricity Export by 73%”, 27 August 2012, see http://wnuukraine.com/news/economy-business/?id=2074, accessed 7 June 2013.
597
Interfax, “Ukraine boosts electricity exports 39.3% in Jan and Feb”, 13 March 2013,
http://en.interfax.com.ua/news/economic/144358.html#.UUhfAxfwnX4, accessed 7 June 2013.
598
EBRD, “Nuclear Power Plant Safety Upgrade Programme”, European Bank for Reconstruction andDevelopment, http://www.ebrd.com/english/pages/project/psd/2011/42086.shtml, accessed 7 June 2013.
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Annex 2: Reactor Construction Times 2003-2013
Construction Times (in years)
Startups between 2003 and July 2013
Country Units Mean Time Min
Max

China
India
S. KoreaJapan
RussiaUkraineIranPakistan
Romania
Total

11
6
5
4
3
2
1
1
1
34

5.9
6.7
4.4
4.4
23.8
18.8
36.3
5.3
24.1
9.4

4.4
5.1
4.0
3.8
19.2
18.2
36.3
5.3
24.1
3.8

11.2
8.8
5.3
5.1
26.8
19.5
36.3
5.3
24.1
26.8

Sources: IAEA-PRIS, MSC, 2013

	
  

	
  

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Annex 3: Definition of Credit Rating by the Main Agencies	
  Moody's
S&P
Fitch
Long-term Short-term Long-term Short-term Long-term Short-term
Aaa
AAA
AAA
Prime
Aa1
AA+
AA+
A-1+
F1+
Aa2
AA
AA
High grade
P-1
Aa3
AAAAA1
A+
A+
A-1
F1
A2
A
A
Upper medium grade
A3
AAP-2
A-2
F2
Baa1
BBB+
BBB+
Baa2
BBB
BBB
Lower medium grade
P-3
A-3
F3
Baa3
BBBBBBBa1
BB+
BB+
Non-investment grade
Ba2
BB
BB
speculative
Ba3
BBBBB
B
B1
B+
B+
B2
B
B
Highly speculative
B3
BBCaa1CCC+
Substantial risks
Not prime
Caa2
CCC
Extremely speculative
Caa3
CCCC
CCC
C
In default with little
CC
prospect for recovery
Ca
C
C
DDD
/
D
/
DD
/
In default/
D
Source: Wikipedia, 2012

	
  

	
  

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Annex 4: About the Authors
Mycle Schneider is an independent international consultant on energy and nuclear policy based in
Paris. He is a member of the International Panel on Fissile Materials (IPFM), based at Princeton
University, U.S.. He has provided information and consulting services, amongst others, to the Belgian
Energy Minister, the French and German Environment Ministries, the U.S. Agency for International
Development, the International Atomic Energy Agency, Greenpeace, the International Physicians for
the Prevention of Nuclear War, the Worldwide Fund for Nature, the European Commission, theEuropean Parliament’s Scientific and Technological Option Assessment Panel and its General
Directorate for Research, the Oxford Research Group, and the French Institute for Radiation
Protection and Nuclear Safety. Mycle has given evidence and held briefings at national Parliaments inthirteen countries and at the European Parliament. Between 2004 and 2009, he was in charge of theEnvironment and Energy Strategies lecture of an International MSc at the French Ecole des Mines in
Nantes. He has given lectures at eighteen universities and engineering schools around the globe. He
founded the Energy Information Agency WISE-Paris in 1983 and directed it until 2003. In 1997, alongwith Japan’s Jinzaburo Takagi, he received the Right Livelihood Award, also known as the“Alternative Nobel Prize.”
Antony Froggatt works as independent European energy consultant based in London. Since 1997, he
has worked as a freelance researcher and writer on energy and nuclear policy issues in the EU andneighboring states. He has worked extensively on EU energy issues for European governments, theEuropean Commission and Parliament, environmental NGOs, commercial bodies, and media. He has
given evidence to inquiries and hearings in the parliaments of Austria, Germany, and the EU. He is apart time senior research fellow at the Royal Institute of International Affairs – Chatham House in
London. He is a regular speaker at conferences, universities, and training programs across the region.
Prior to working freelance, Antony served for nine years as a nuclear campaigner and coordinator forGreenpeace International.
------------------------------------Peter A. Bradford, a former member of the United States Nuclear Regulatory Commission (NRC)and former chair of the New York and Maine utility regulatory commissions, has taught at the Yale
School of Forestry and Environmental Studies and currently is an Adjunct Professor at Vermont Law
School teaching “Nuclear Power and Public Policy.” Mr. Bradford is also a commissioner on New
York's Moreland Commission on Utility Storm Response and on the Texas/Vermont Low Level
Radioactive Waste Commission. A member of the China Sustainable Energy Policy Council, he
served on a recent panel evaluating the reliability of the Vermont Yankee nuclear power plant, on theEuropean Bank for Reconstruction and Development (EBRD) Panel advising how best to replace theremaining Chernobyl nuclear plants in Ukraine, a panel on the opening of the Mochovce nuclear
power plant in Slovakia, and the Keystone Center collaborative on nuclear power and climate change.
He is the author of “Fragile Structures: A Story of Oil Refineries, National Securities and the Coast ofMaine” and many articles. He is a graduate of Yale University and the Yale Law School and is Vice
Chair of the board of The Union of Concerned Scientists (UCS).
Julie Hazemann is the director of EnerWebWatch, an international documentation monitoring
service, specializing in energy and climate issues, launched in 2004. Since 1992, she has maintained aworld nuclear reactors database and undertakes data modeling work for the World Nuclear Industry
Status Report. From 1983 to 2006, she worked in various positions at WISE-Paris, an independent
information service on energy and environment issues that she co-founded. Starting in 1989, shedeveloped the computerization of the library and electronic information products. Her responsibilities
covered database development, specialized translation and project management, as well as research
activities for specific projects. She is a member of négaWatt (France). She develops EnerWebWatch in
the framework of the Coopaname coop.
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Komei Hosokawa, MA, PhD, teaches environmental sociology, development studies and energy
policy issues at the School of Social and Environmental Research, Kyoto Seika University, Kyoto. He
is co-chair of the Pacific-Asia Resource Center (PARC), Tokyo. He also serves as board director of
the Takagi Fund for Citizen Science and of Greenpeace Japan. He is a social scientist by training, andhas longtime field research experience in Indigenous communities and environment in Australia. In
the late 1980s, Australia-Japan uranium issues led him to take an active part in the social movements
concerning nuclear power questions in Japan and abroad. He is accredited member of the AustralianInstitute of Aboriginal and Torres Strait Islander Studies (AIATSIS), Canberra. Recently he wasappointed chief secretary of the Citizens’ Commission on Nuclear Energy (CCNE), an independent
think-tank launched by the Takagi Fund. CCNE aims to deliver alternative, sensible andcomprehensive policy guidelines toward nuclear phaseout in Japan.
	 Steve Thomas is Professor of Energy Policy and Director of Research for the Business School,
University of Greenwich. Mr. Thomas holds a BSc (honors) degree in Chemistry from Bristol
University and has been working in energy policy analysis since 1976. His main research interests arereforms of energy industries, economics and policy towards nuclear power, and corporate policies ofenergy industry companies. Recent clients include Public Services International, the European
Federation of Public Service Unions, the Nonproliferation Policy Education Center (U.S.),
Energywatch (U.K.) and Greenpeace International.
	
  Yukio Yamaguchi, PhD in Engineering (University of Tokyo), studied condensed matter physics at
the University of Tokyo Graduate School of Science. He has taught in Northwestern University,
University of Tokyo, Hosei University and several other schools. He is deeply concerned about therelations between the problems of science education and the problems of nuclear energy; andpublished a number of books in these topics particularly targeted at middle and high school students.
He is familiar with the history of grassroots resistance in Japan. Since 1998, he is co-director of the
Citizen's Nuclear Information Center (CNIC), Tokyo. He is also an enthusiastic supporter andpractitioner of organic farming.	
 	
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Annex 5: Abbreviations
ABWR – Advanced Boiling Water Reactor
ADR – Alternative Dispute Resolution
AECL – Atomic Energy Canada Limited
AGEB – Artbeitsgemeinschaft Energiebilanz
AGR – Advanced Gas Reactor
APWR – Advanced Pressurized Water Reactor
ASN – French Nuclear Safety Authority
BERR – Department for Business, Enterprise and Regulatory Reform (U.K.)
BNEF – Bloomberg New Energy Finance
BOO – Build, Own and Operate
BOOT – Build-Own-Operate-Transfer
BWR – Boiling Water Reactor
CANDU – Canadian Deuterium Uranium
CCS – Carbon Capture and Storage
CEA – French Atomic Energy Commission
CEO – Chief Executive Officer
CFD – Contract for Difference
CGN or CGNPC – Chinese Guangdong Nuclear Power Company
CHP – Combined Heat and PowerCNEA – Comision Nacional de Energia Atomica – Argentina
CNSC – Canadian Nuclear Safety Commission
CNNC – Chinese National Nuclear Company
COL – Construction and Operation Licence
CSN – Consejo de Seguridad Nuclear – Spain Safety Authority
DAC – Design Acceptance Certificate
DECC – Department of Energy and Climate Change – U.K.
DGEC – Direction générale de l'énergie et du climat – France
DGEMP – Direction générale de l'énergie et des matières premières – France
DOE – US Department of Energy
EBITDA – Earnings before interest, taxes, depreciation and amortization
EC/EBIDTA – Enterprise Value Earnings before interest, taxes, depreciation and amortization
EDF - Électricité de France
EIA – Environmental Impact Assessment
EMR – Electricity Market Reform
ENEC – Emirates Nuclear Energy Corporation
EPR – European Pressurized Water Reactor or Evolutionary Pressurized Water Reactor#
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ERÚ – Czech Energy Regulatory Office
ESBWR – Economic Simplified Boiling Water Reactor
ESP – Early Site Permit
EU – European Union
EU ETS – European Union Emissions Trading System
EVN – Electricity of Vietnam
EWEA – European Wind Energy Association
FANC – Belgian Nuclear Control Authority
FANR – Federal Authority for Nuclear Regulation - United Arab Emirates
FCF – Free Cash Flow
FL3 – Flamanville-3
FIT – Feed-in Tariff
GDA – Generic Design Assessment
GWEC – Global Wind Energy Council
I&C – Instrumentation and Control
IAEA – International Atomic Energy Agency
IDAC – Interim Design Acceptance Certificate
IEA – International Energy Agency
IEEJ – Institute for Energy and Economics of Japan
INES – International Nuclear Events Scale
INIG – Integrated Nuclear Infrastructure GroupIRSN – Institut de radioprotection et de sûreté nucléaire – France
IZES – Institut für Zukunfts Energie Systeme
JAEC – Jordon Atomic Energy Commission or Japan Atomic Energy Commission
JAIF – Japan Atomic Industrial Forum
JNES – Japan Nuclear Energy Safety Organisation
JSW – Japan Steel Works
KA-CARE – King Abdullah City for Atomic and Renewable Energy
KEPCO – Korea Electric Power Corporation or Kansai Electric Power Corporation – JapanKHNP – Korea Hydro and Nuclear PowerKINS – Korean Institute of Nuclear Safety
K-POPONS – The Korean Professors’ Organization for a Post-Nuclear Energy Society
LTS – Long Term Shutdown
METI – Ministry of Economics, Trade and Industry
MoU – Memorandum of Understanding
MOX – Mixed Oxide FuelmSv – millisievert

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mSv/h – millisievert per hour
NAIIC – National Diet of Japan Fukushima Nuclear Accident Independent Investigation Commission
NDA – Nuclear Decommissioning Authority
NEI – Nuclear Engineering International
NEXI – Nippon Export and Investment Insurance
NINA – Nuclear Innovation North America
NIW – Nuclear Intelligence Weekly
NNB GenCo – Nuclear New Build Generation Company
NPS – National Policy Statement (U.K.)
NPV – net present value
NPCIL – Nuclear Power Corporation of India Ltd
NPI – Nuclear Power International
NPT – Non-Proliferation Treaty
NNC – National Nuclear Centre (Kazakhstan)
NPP – Nuclear Power Plant
NRA – Nuclear Regulation Authority – Japan
NRC – Nuclear Regulatory Commission – U.S.
NSG – Nuclear Suppliers GroupNSSC – Nuclear Safety and Security Commission – Korea
OECD – Organisation for Economic Development and Co-operation
OFGEM – Office for Gas and Electricity Markets – U.K.
OL3 – Olkiluoto-3
ONR – Office of Nuclear Regulation – U.K.
OPG – Ontario Power Generation
PAEC – Pakistan Atomic Energy Commission
PBMR – Pebble Bed Modular Reactor
PGE – Polska Grupa Energetyczna
PLEX – Plant Life Extension
PPA – Power Purchase Agreement
PRIS – Power Reactor Information System
PSC – Public Service Commission
PV – Photovoltaic
PwC – PricewaterhouseCoopers
PWR – Pressurized Water Reactor
RBMK – Light water cooled, graphite moderated
S&P – Standard and Poor’s
SCRO – State Research Council Office – China

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SCE(&G) – Southern California Electric (& Gas)
SE – Slovak Electric
SEA – Strategic Environmental Assessment
SNPTC – State Nuclear Power Technology Corp. – China
STP – South Texas Project
STUK – Finnish Radiation and Nuclear Safety Authority
Sv – Sievert
Sv/h – Sievert per hour
TANE – Toshiba American Energy Corporation
TEPCO – Tokyo Electric Power Company
TFEU – Treaty on the Functioning of the European Union
TVA – Tennessee Valley Authority
TVO – Teollisuuden Voima Tyj
UAE – United Arab Emirates
UBS – Union Bank of Switzerland
VEB – Vnesheconombank
VVER – Light Water Reactor – Russian design
WACC – Weighted Average Cost of Capital
WANO – World Association of Nuclear Operators
WNA – World Nuclear Association
WEC – World Energy Council
WNISR – World Nuclear Industry Status Report
WNN – World Nuclear NewsElectrical Units
kW – kilowatt (unit of installed electric power)
kWh – kilowatt-hour (unit of electricity)
MW – megawatt (106)MWe – megawatt electric
GW – gigawatt (109)GWe – gigawatt electric
TWh – terawatt hour (1012)
	
  
	
  

	
  

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Annex 6. Status of Nuclear Power in the World (1 July 2013)
Nuclear Reactors1
Countries

Argentina
Armenia
BelgiumBrazilBulgaria
CanadaChina
Czech Republic
FinlandFranceGermany
Hungary
India
Iran
Japan
MexicoNetherlands
Pakistan
Romania
RussiaSlovakia
Slovenia
South Africa
South Korea
Spain
SwedenSwitzerland
TaiwanUkraineUnited Kingdom
USA
EU27
World Total

Operate(Reactors)

Capacity
(MWe)

2
1
7
2
2
19
18
6
4
58
9
4
20
1
44
2
1
3
2
33
4
1
2
23
7
10
5
6
15
16
100
131
427

935
375
5 926
1 884
1 906
13 53213 8163 766
2 736
63 13012 068
1 889
4 388
915
38 009
1 530
482
725
1 300
23 643
1 816
688
1 860
20 718
7 112
9 395
3 263
5 018
13 1079 243
98 903
121 457
364 078

Average
Age(Years)
34
33
33
22
24
30
8
22
34
28
28
28
19
2
26
21
40
19
11
30
21
32
27
18
29
34
38
32
25
30
34
28

Under
Construction4(Reactors)
1

1
28
1
1
7

2
9
2

4

2
2
3
4
66

Power2

Energy3

Share ofElectricity5

Share ofCommercial
Primary Energy5%(=)
27%(−)
51%(−)
3%(=)
32%(=)
15%(=)
2%(=)
35%(+)
33%(=)
75%(−)
16%(−)
46%(+)
4%(=)<1% (+)
2,1%(−)
5%(=)
4%(=)
5%(+)
19%(=)
18%(=)
54%(+)
36%(−)
5%(=)
30%(−)
21%(=)
38%(−)
36%(−)
18%(=)
46%(=)
18%(=)
19%(=)
27%(=)6
10%(–)3

2%
?%
15%
1%
20%
7%
<1%
16%
20%
39%
7%
16%
1%
<1%
<1%
1%
1%
2%
8%
6%
21%
?%
3%
13%
10%
28%
20%
8%
16%
8%
8%
4,5%

© Mycle Schneider Consulting

Notes
1
Mycle Schneider Consulting, based on IAEA, PRIS database, July 2013, and others.
2
In 2012, based on IAEA, PRIS database, July 2013.
3
BP, “Statistical Review of World Energy”, June 2013.
4
As of 1 July 2013.
5
A +/-/= in brackets refer to change in 2012 versus the level in 2011; a change of less than 1% is considered =.
6
Eurostat, “Electricity Statistics", 2011,
http://epp.eurostat.ec.europa.eu/statistics_explained/index.php?title=File:Electricity_Statistics,_2011_%28in_GWh%29.png&filetimestamp=20120507123319, accessed 7 June 2012.

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Annex 7. Nuclear Reactors in the World Listed as “Under Construction” (1 July 2013)
Country
Argentina…Atucha-2
Brazil…AngraChina3…Changjiang-1…Changjiang-2…Fangchenggang-1…Fangchenggang-2…Fangjiashan-1…Fangjiashan-2…Fuqing-1…Fuqing-2…Fuqing-3...Fuqing-4…Haiyang-1…Haiyang-2…Hongyanhe-2…Hongyanhe-3…Hongyanhe-4…Ningde-2…Ningde-3…Ningde-4…Sanmen-1…Sanmen-2...Shidao Bay-1…Taishan-1…Taishan-2...Tianwan-3…Yangjiang-1…Yangjiang-2…Yangjiang-3...Yangjiang-4
Finland…Olkiluoto-3
France…Flamanville-3
India…Kakrapar-3…Kakrapar-4…Kudankulam-1…Kudankulam-2…PFBR…Rajasthan-7…Rajasthan-8
Pakistan…Chasnupp-3…Chasnupp-4
Country
Russia15…BN-800

Units

MWe (net)

Construction Start

Planned Grid Connection

1

692

1981/07/14

Middle of 20131

1
28

1 245
27 7902010/06/01

20162

2010/04/25
2010/11/21
2010/07/30
2010/12/234
2008/12/26
2009/07/17
2008/11/21
2009/06/17
2010/12/31
2012/11/17
2009/09/24
2010/06/21
2008/03/28
2009/03/07
2009/08/15
2008/11/12
2010/01/08
2010/09/29
2009/04/19
2009/12/17
2012/12/09
2009/10/28
2010/04/15
2012/11/17
2008/12/16
2009/06/04
2010/11/15
2012/11/17

2014
2015
2015
2016
2013/12
2014/102013/11
2014/09
2015/075
2016/056
2014/06
2015/03
2013
2014
2014
2013
2014
2015
2014/037
2015/09
2016
20148
2015
2017
2013/08
2014
2015
2017

610
610
1000
1000
1000
1000
1000
1000
1000
1000
1000
1000
1000
1000
1000
1000
1000
1000
1000
1000
200
1660
1660
1050
1000
1000
1000
1000
1

1 600

2005/08/12

2016 9

1
7

1 600
4 824

2007/12/03

2016102010/11/22
2010/11/22
2002/03/31
2002/07/04
2004/10/23
2011/07/18
2011/09/3011

2015/03/31
2015/09/30
2013/07 (commercial operation)12
2014/03 (commercial operation)13
2014 (commercial operation)14
2016/03/31
2016/09/30

2011/05/28
2011/12/18
Construction Start

2016/09/01
2017/07/01
Planned Grid Connection

630
630
917
917
470
630
630
2

630
315
315
Units MWe (net)
9
7 273
78916

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201420World Nuclear Industry Status Report 2013

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...Leningrad-2-1…Leningrad-2-2…Novovoronezh-2-1...Novovoronezh-2-2…Lomonosov-1…Lomonosov-2…Rostov-3…Rostov-4
Slovakia...Mochovce-3...Mochovce-4
South Korea…Shin-Kori-3…Shin-Kori-4…Shin-Wolsong-2...Shin Hanul-1...Shin Hanul-2
Taiwan…Lungmen-1…Lungmen-2
Ukraine…Khmelnitski-3…Khmelnitski-4
United Arab Emirates…Barakah-1…Barakah-2
USA...Virgil C. Summer-2...Vogtle-3...Watts Bar
Total

1085
1085
1114
1114
32
32
1011
1011
2

880
440
440

5

2008/10/25
2010/04/15
2008/06/24
2008/07/12
2007/04/15
2007/04/15
198318
1983192016 (commercial operation)21
2016? (commercial operation)22
2014 (commercial operation)23
2016 (commercial operation)24
2019/12 (commercial operation)25
2019/12 (commercial operation)26
2014 (commercial operation)27
2017/06 (commercial operation)28

1985/01/0129
1985/01/0130

2014/1031
2015/1032

2008/10/31
2009/09/15
2008/09/23
2012/7/12
2013/6/19

2013/09 (commercial operation)33
2014/12 (commercial operation)34
2014 (commercial operation)35
2017/04 (commercial operation)36
2018/04 (commercial operation)37

1999/03/31
1999/08/30

2014-15 (commercial operation)38
2015 (commercial operation)39

1986/03/01
1987/02/01

2015/01/0140
2016/01/0141

2012/07/18
2013/05/30

201742
201843

2013/03/09
2013/03/12
1972/12/01
1972-20132017/03/1544
mid-201745
2015/09-1246
2013-2019

6 320
1340
1340
960
1340
1340

2

2 600
1300
1300

2

1 900
950
950

2

2 690
1 345
1 345

3

3 399
1 117
1 117
1 165

66

63 443	  © Mycle Schneider Consulting

Sources: IAEA-PRIS, 2013, unless otherwise noted.

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  
Notes	  1

Delayed multiple times. This date from Nucleoeléctrica Argentina S.A., “El hombre que logró terminar Atucha II”, accessed
22 June 2012. IAEA-PRIS indicates 1 July 2013.
2
Delayed multiple times. IAEA commercial startup 1 January 2016 reintroduced in 2013,
http://www.iaea.org/PRIS/CountryStatistics/ReactorDetails.aspx?current=26, accessed 22 June 2013.
3
No IAEA startup date for any Chinese reactor (except Fuqing-3 and Changjiang-2). The estimate for all reactors are drawn orderived from www.world-nuclear.com/info/inf63.html, accessed 15 June 2013.
4This date was introduced by IAEA-PRIS at a much later date. The WNA gives 2011 as construction start, see http://www.worldnuclear.com/info/inf63.html, accessed on 22 June 2013.
5
IAEA gives 31 July 2015 as commercial operation date, see
http://www.iaea.org/PRIS/CountryStatistics/ReactorDetails.aspx?current=935, accessed 22 June 2013.
6
Operation previously announced for 2017 by WNA (December 2012). Last estimate May 2016 from www.worldnuclear.com/info/inf63.html, WNA, Nuclear Power in China, updated 7 June 2013, accessed 15 June 2013.
7
WNA says Sanmen -1 "is expected to load fuel in 2013 and begin operation in 2014 with the second about one year later",
WNA, “Chinese Nuclear Energy”, Updated 30 April 2013, see http://www.world-nuclear.org/info/Country-Profiles/Countries-AF/China--Nuclear-Power/#.UYEjs4UgpGw, accessed 1 May 2013.
8
Commercial operation for Taishan reactors 2014 & 2015, WNA, “Chinese Nuclear Energy”, Updated 30 April 2013 http://www.world-nuclear.org/info/Country-Profiles/Countries-A-F/China--Nuclear-Power/#.UYEjs4UgpGw, accessed 1 May 2013.
9
After numerous revisions of the original planned commissioning in 2009, the date refers to “commercial operation”.
Teollisuuden Voima (TVO) is preparing for the possibility that the start of the regular electricity production of Olkiluoto 3 nuclear

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power plant unit may be postponed until year 2016" TVO, Information About the Start-up of Olkiluoto 3 Nuclear Power Plant
Unit, 11 February 2013, http://www.tvo.fi/news/32, accessed February 11, 2013.
10
Delay of at least four years from original planning. EDF maintains this target date for first “commercialization of electricity” inspite of persisting major building issues (concreting, maintenance bridge…), see EDF, “Remplacement des consoles du pont demanutention du bâtiment réacteur”, Note d’information, 16 mars 2012.
11
Announced only in February 2012.
12
Delayed numerous times. No IAEA or WNA startup date. The latest IAEA date (2011/02/28) was simply dropped without being
replaced. Construction at least 5 years behind schedule. Commercial operation 2013/07 according to NPCIL, Plants Under
Construction, Kudankulam, http://www.npcil.nic.in/main/ConstructionDetail.aspx?ReactorID=77, accessed 15 June 201313
Delayed numerous times.. Construction at least 5 years behind schedule. No IAEA start-up date. Commercial operation 2014/03
according to NPCIL, Plants Under Construction, Kudankulam,
http://www.npcil.nic.in/main/ConstructionDetail.aspx?ReactorID=77, accessed 15 June 201314
Delayed numerous times. No IAEA start-up date. This estimate for commercial operation from www.worldnuclear.org/info/inf53.html, delayed from 2012 to 2013 a year ago, and to 2014 in latest versions. According to update from 1 May
2012, reactor was 86 percent complete, M.V. Ramana, personal communication, 14 June 2012.
15
Note on the Kursk-5 project: We decided to pull it from the list. No IAEA startup date is given and it was deleted from the
WNA construction list. WNA states on its website: “In February 2012 Rosatom confirmed that the project was terminated.”
Kursk-5 is based on an upgraded RBMK design.
Note on Baltiisk (Baltic nuclear plant): We have withdrawn the project from the list after reports that construction was halted andthe reactor replaced by a smaller design, see http://www.bellona.org/articles/articles_2013/baltic_npp_debacle, accessed 23 June
2013.
16
Capacity increased from 750 MW to 789 MW since July 2012.
17
The IAEA Power Reactor Information System (PRIS) database curiously provides a construction start date as 2006/07/18. Until
2003, the French Atomic Energy Commission (CEA) listed the BN-800 as “under construction” with a construction startup date of“1985.” In subsequent editions of the CEA’s annual publication ELECNUC, Nuclear Power Plants in the World, the BN-800 had
disappeared.
18
Originally construction started in 1983 and it resumed after interruptions in September 2009, from http://www.worldnuclear.org/info/Country-Profiles/Countries-O-S/Russia--Nuclear-Power/, accessed 4 May 2012.
19
Originally construction started in 1983 and, after interruptions, “first new concrete” was poured in June 2010, fromhttp://www.world-nuclear.org/info/Country-Profiles/Countries-O-S/Russia--Nuclear-Power/, accessed 4 May 2012.
20
Delayed numerous times; no IAEA startup date. This estimate from http://www.world-nuclear.org/info/CountryProfiles/Countries-O-S/Russia--Nuclear-Power/, accessed 4 May 2012.
21
No IAEA startup date. This estimate from http://www.world-nuclear.org/info/Country-Profiles/Countries-O-S/Russia--NuclearPower/, accessed 16 June 2013 (previous estimate 10/2013 in December 2012).
22
No IAEA startup date. This estimate from http://www.world-nuclear.org/info/Country-Profiles/Countries-O-S/Russia--NuclearPower/, accessed 16 June 2013.
23[No IAEA startup date.] Delayed from 2012/12/31. 31/12/2014 from PRIS, Novovoronezh-2-1 Reactor Details
http://www.iaea.org/PRIS/CountryStatistics/ReactorDetails.aspx?current=898, accessed 15 June, 2013.
24
No IAEA startup date. This estimate from http://www.world-nuclear.org/info/Country-Profiles/Countries-O-S/Russia--NuclearPower/, accessed 16 June 2013.
25
IAEA commercial operation date. Commercial operation originally planned for 2010 at Severod. Since moved to Lomonosov
and delayed by two years.
26
IAEA commercial operation date. Commercial operation originally planned for 2010 at Severod. Since moved to Lomonosov
and delayed by two years. Then delayed by another two years to 2014.
27
No IAEA startup date. This estimate from http://www.world-nuclear.org/info/Country-Profiles/Countries-O-S/Russia--NuclearPower/, accessed 15 June 2013.
28
Delayed from 2016. No IAEA startup date. This estimate from http://www.world-nuclear.org/info/Country-Profiles/CountriesO-S/Russia--Nuclear-Power/, accessed 15 June 2013.
29
On 11 June 2009 construction officially resumed.
30
On 11 June 2009 construction officially resumed.
31
Delayed numerous times. This date from PRIS, Mochovce-3 Reactor Details, Updated 14 June 2013 http://www.iaea.org/PRIS/CountryStatistics/ReactorDetails.aspx?current=544, accessed June 15, 2013.
and The Slovak Spectator, “Mochovce to be completed in 2014/15”, 8 April 2013
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World Nuclear Industry Status Report 2013

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32

	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
   	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  	
  

Delayed numerous times. This date from PRIS, Mochovce-3 Reactor Details, Updated 14 June 2013 http://www.iaea.org/PRIS/CountryStatistics/ReactorDetails.aspx?current=544, accessed June 15, 2013.
and The Slovak Spectator, “Mochovce to be completed in 2014/15”, 8 April 2013.
33
No IAEA startup date. Delayed. This date from www.world-nuclear.org/info/inf81.html, accessed 16 June 2013.
34
No IAEA startup date. Delayed. This date from www.world-nuclear.org/info/inf81.html, accessed 16 June 2013.
35
No IAEA startup date. Delayed. Startup date of 2012/05/28 withdrawn from IAEA-PRIS. This date from www.worldnuclear.org/info/inf81.html, accessed 16 June 2013.
36
New name for Shin Ulchin. Commercial operation date of 2017/04 from www.world-nuclear.org/info/inf81.html, accessed 15
June 2013, whereas Commercial date introduced by IAEA in late May (Shin Hanul-1 Reactor Details, Updated 30 May 2013) is
06/2016 http://www.iaea.org/pris/CountryStatistics/ReactorDetails.aspx?current=887 accessed 31 May 2013;37
No IAEA mentioning as of 29 June 2013; Commercial operation date of 2017/04 from www.worldnuclear.org/info/inf81.html, accessed 29 June 2013.
38
No IAEA startup date. Delayed many times from original start-up date of mid-2006. This date according to media reports,
including http://mobile.globalpost.com/dispatch/news/regions/asia-pacific/120305/taiwan-nuclear-power-plant-longmen-lungmen,
accessed 5 May 2012 and Nucleonics Week, “Lungmen critic gives legislators plan for reinspection, oversight”, 2 May 2013.
39
No IAEA startup date. Delayed many times from original start-up date of mid-2006. This date according to media reports,
including http://mobile.globalpost.com/dispatch/news/regions/asia-pacific/120305/taiwan-nuclear-power-plant-longmen-lungmen,
accessed 5 May 2012 and Nucleonics Week, “Lungmen critic gives legislators plan for reinspection, oversight”, 2 May 2013.
40
Delayed numerous times.
41
Delayed numerous times.
42
No IAEA startup date. This estimate from WNA, Nuclear Power United Arab Emirates, Updated May 2013 - http://www.worldnuclear.org/info/Country-Profiles/Countries-T-Z/United-Arab-Emirates/#.Ubx_sIUgojo, accessed 15 June, 2013.
43
No IAEA startup date. This estimate from WNA, WNA, Nuclear Power United Arab Emirates, Updated May 2013 http://www.world-nuclear.org/info/Country-Profiles/Countries-T-Z/United-Arab-Emirates/#.Ubx_sIUgojo, accessed 29 June, 2013.
44
No IAEA startup date. “Substantial completion”, according to SCE, “Quarterly Report to the South Carolina Office ofRegulatory Staff”, Quarter Ending 31 March 2013.
45
No IAEA startup date. This estimation from WNA, Nuclear Power in the USA, Updated April 2013 - http://www.worldnuclear.com/info/Country-Profiles/Countries-T-Z/USA--Nuclear-Power/#.UYFBUoUgqiY, accessed 1 May, 2013.
46
Delayed again. Now scheduled for startup by December 2015, see TVA press release, “Watts Bar 2 Progress Remains on
Track”, 11 April 2013, see http://www.tva.com/news/releases/aprjun13/wbn2.html, accessed 22 June 2013.

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