Study warns of cost overruns at proposed reactors

By MarketWatch


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A new academic study warns the cost of building nuclear power plants will likely come in at the high end of current industry estimates of $5 billion to $8 billion each, and that it would be cheaper for the U.S. to instead focus on energy efficiency and alternative sources such as wind and solar.

The study by the Vermont Law School's Institute for Energy and the Environment comes as the nuclear power industry moves forward with plans to build at least two dozen new reactors backed by federal loan guarantees and other subsidies, including one new project officially launched in Ohio by Duke Energy.

The projected costs for nuclear plans amounts to 12 to 20 cents per kilowatt hour, more expensive than the average cost of increased use of energy efficiency and renewable energies at 6 cents per kilowatt hour, according to the study.

"There are a host of alternatives that are superior to nuclear reactors," said Mark Cooper, one of the study's authors. "Building nuclear reactors would be the worst choice you could have for reducing carbon emissions."

Cooper sifted through 36 cost estimates for proposed new reactors and concluded that the projected price tags have already quadrupled since the start of the industry's so-called "nuclear renaissance" nearly a decade ago.

The costs have risen even before any approvals for new plants by the Nuclear Regulatory Commission, a process expected to take another two years or so.

In a conference call with reporters, Cooper pointed out that the last surge of plant construction in the U.S. from the early 1960s and 70s saw a sevenfold increase in plant costs. Half of planned reactors had to be abandoned or cancelled due to massive cost overruns, he said.

A new set of loan guarantees and other subsidies will help shift the risk and potential costs of the new generation of plants onto rate payers and taxpayers, he said.

"The nuclear industry is hiding costs and risks are shifting to the taxpayer," said Peter Bradford, a former member of the U.S. Nuclear Regulatory Commission. "The subsidies don't show up in cost estimates to ratepayers."

Steve Kerekes of the Nuclear Energy Institute, an industry group, argued that comparisons to nuclear power plant costs 30 years ago are moot because the underlying economic conditions have changed.

"Back then you had much higher inflation," he said. "Newer reactors have more interchangeable parts with modular designs. They've been built in less than five years in Europe already."

Kerekes also pointed out that the cost of alternative energy has risen as well, and noted that a wind farm proposed by Boone Pickens will likely cost $10 billion to $12 billion according to press reports.

While the wind farm could generate the equivalent power of one nuclear reactor, it's already expected to cost more than the $5 billion to $8 billion projected cost of a new reactors.

Meanwhile, Ohio Governor Ted Strickland, Duke Energy, Areva, USEC Inc. and UniStar Nuclear Energy formed an alliance to build a nuclear power plant at a U.S. Department of Energy site in Piketon, Ohio.

Dubbed the Southern Ohio Clean Energy Park Alliance, the partnership will evaluate the site as a potential location for a new nuclear power plant, including preparing a plant site study and licensing documents for the Nuclear Regulatory Commission.

UniStar is a joint alliance between France's EDF and Constellation Energy.

The clean energy park comes after an Energy Department effort to convert former weapons sites for energy production. Duke will manage the project, provide project oversight and serve as the applicant for any NRC licensing.

Of the 27 new reactors now proposed for the United States, the Duke-UniStar project marks the third to be proposed at a site that doesn't include an existing plant, according to Mitchell Singer of the Nuclear Energy Institute.

The other two are the Duke Energy project in Cherokee County, South Carolina and a Progress Energy plant on the books for Levy County, Florida.

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Enel kicks off 90MW Spanish wind build

Enel Green Power España Aragon wind farms advance Spain's renewable energy transition, with 90MW under construction in Teruel, Endesa investment of €88 million, 25-50MW turbines, and 2017 auction-backed capacity enhancing grid integration and clean power.

 

Key Points

They are three Teruel wind projects totaling 90MW, part of Endesa's 2017-awarded plan expanding Spain's clean energy.

✅ 90MW across Sierra Costera I, Allueva, and Sierra Pelarda

✅ €88m invested; 14+7+4 turbines; Endesa-led build in Teruel

✅ Part of 2017 tender: 540MW wind, 339MW solar, nationwide

 

Enel Green Power Espana, part of Enel's wind projects worldwide, has started constructing three wind farms in Aragon, north-east Spain, which are due online by the end of the year.

The projects, all situated in the Teruel province, are worth a total investment of €88 million.

The biggest of the facilities, Sierra Costera I, will have a 50MW and will feature 14 turbines.

The wind farm is spread across the municipalities of Mezquita de Jarque, Fuentes Calientes, Canada Vellida and Rillo.

The Allueva wind facility will feature seven turbines and will exceed 25MW.

Sierra Pelarda, in Fonfria, will have four turbines and a capacity of 15MW, as advances in offshore wind turbine technology continue to push scale elsewhere.

The projects bring the total number of wind farms that Enel Green Power Espana has started building in the Teruel province to six, equal to an overall capacity of 218MW.

Endesa chief executive Jose Bogas said: “These plants mark the acceleration on a new wave of growth in the renewable energy space that Endesa is committed to pursue in the next years, driving the energy transition in Spain.”

The six wind farms under construction in Teruel are part of the 540MW that Enel Green Power Espana was awarded in the Spanish government's renewable energy tender held in May 2017.

In Aragon, the company will invest around €434 million euros, reflecting broader European wind power investment trends in recent years, to build 13 wind farms with a total installed capacity of more than 380MW.

The remaining 160MW of wind capacity will be located in Andalusia, Castile-Leon, Castile La Mancha and Galicia, even as some Spanish turbine factories closed during pandemic restrictions.

Enel Green Power Espana was also awarded 339MW of solar capacity in the Spanish government's auction held in July 2017, while other Spanish developers advance CSP projects abroad in markets like Chile.

Once all wind and solar under the 2017 tender are complete they will boost the company’s capacity by around 52%.

 

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Nova Scotia can't order electric utility to lower power rates, minister says

Nova Scotia Power Rate Regulation explains how the privately owned utility is governed by the Utility Review Board, limiting government authority, while COVID-19 relief measures include suspended disconnections, waived fees, payment plans, and emergency assistance.

 

Key Points

URB oversight where the board, not the province, sets power rates, with COVID-19 relief pausing disconnections and fees.

✅ Province lacks authority to order rate cuts

✅ URB regulates Nova Scotia Power rates

✅ Relief: no disconnections, waived fees, payment plans

 

The province can't ask Nova Scotia Power to lower its rates to ease the financial pressure on out-of-work residents because it lacks the authority to take that kind of action, even as the Nova Scotia regulator approved a 14% hike in a separate proceeding, the provincial energy minister said Thursday.

Derek Mombourquette said he is in "constant contact" with the privately owned utility.

"The conversations are ongoing with Nova Scotia Power," he said after a cabinet meeting.

When asked if the Liberal government would order the utility to lower electricity rates as households and businesses struggle with the financial fallout from the COVID-19 pandemic, Mombourquette said there was nothing he could do.

"We don't have the regulatory authority as a government to reduce the rates," he told reporters during a conference call.

"They're independent, and they are regulated through the (Nova Scotia Utility Review Board). My conversations with Nova Scotia Power essentially have been to do whatever they can to support Nova Scotians, whether it's residents or businesses in this very difficult time."

Asked if the board would take action, the minister said: "I'm not aware of that," despite the premier's appeals to regulators in separate rate cases.

However, the minister noted that the utility, owned by Emera Inc., has suspended disconnections for bill non-payment for at least 90 days, a step similar to reconnection efforts by Hydro One announced in Ontario.

It has also relaxed payment timelines and waived penalties and fees, while some jurisdictions offered lump-sum credits to help with bills.

Nova Scotia Power CEO Wayne O'Connor has also said the company is making additional donations to a fund available to help low-income individuals and families pay their energy bills.

In late March, Ontario cut electricity rates for residential consumers, farms and small businesses in response to a surge in people forced to work from home as a result of the pandemic, alongside bill support measures for ratepayers.

Premier Doug Ford said there would be a 45-day switch to off-peak rates, later moving to a recovery rate framework, which meant electricity consumers would be paying the lowest rate possible at any time of day.

The change was expected to cost the province about $162 million.

 

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Can Canada actually produce enough clean electricity to power a net-zero grid by 2050?

Canada Clean Electricity drives a net-zero grid by 2035, scaling renewables like wind, solar, and hydro, with storage, smart grids, interprovincial transmission, and electrification of vehicles, buildings, and industry to cut emissions and costs.

 

Key Points

Canada Clean Electricity is a shift to a net-zero grid by 2035 using renewables, storage, and smart grids to decarbonize

✅ Doubles non-emitting generation for electrified transport and heating

✅ Expands wind, solar, hydro with storage and smart-grid balancing

✅ Builds interprovincial lines and faster permitting with Indigenous partners

 

By Merran Smith and Mark Zacharias

Canada is an electricity heavyweight. In addition to being the world’s sixth-largest electricity producer and third-largest electricity exporter in the global electricity market today, Canada can boast an electricity grid that is now 83 per cent emission-free, not to mention residential electricity rates that are the cheapest in the Group of Seven countries.

Indeed, on the face of it, the country’s clean electricity system appears poised for success. With an abundance of sunshine and blustery plains, Alberta and Saskatchewan, the Prairie provinces most often cited for wind and solar, have wind- and solar-power potential that rivals the best on the continent. Meanwhile, British Columbia, Manitoba, Quebec, and Newfoundland and Labrador have long excelled at generating low-cost hydro power.

So it would only be natural to assume that Canada, with this solid head start and its generous geography, is already positioned to provide enough affordable clean electricity to power our much-touted net-zero and economic ambitions.

But the reality is that Canada, like most countries, is not yet prepared for a world increasingly committed to carbon neutrality, in part because demand for solar electricity has lagged, even as overall momentum grows.

The federal government’s forthcoming Clean Electricity Standard – a policy promised by the governing Liberals during the most recent election campaign and restated for an international audience by Prime Minister Justin Trudeau at the United Nations’ COP26 climate summit – would require all electricity in the country to be net zero by 2035 nationwide, setting a new benchmark. But while that’s an encouraging start, it is by no means the end goal. Electrification – that is, hooking up our vehicles, heating systems and industry to a clean electricity grid – will require Canada to produce roughly twice as much non-emitting electricity as it does today in just under three decades.

This massive ramp-up in clean electricity will require significant investment from governments and utilities, along with their co-operation on measures and projects such as interprovincial power lines to build an electric, connected and clean system that can deliver benefits nationwide. It will require energy storage solutions, smart grids to balance supply and demand, and energy-efficient buildings and appliances to cut energy waste.

While Canada has mostly relied on large-scale hydroelectric and nuclear power in the past, newer sources of electricity such as solar, wind, geothermal, and biomass with carbon capture and storage will, in many cases, be the superior option going forward, thanks to the rapidly falling costs of such technology and shorter construction times. And yet Canada added less solar and wind generation in the past five years than all but three G20 countries – Indonesia, Russia and Saudi Arabia, with some experts calling it a solar power laggard in recent years. That will need to change, quickly.

In addition, Canada’s Constitution places electricity policy under provincial jurisdiction, which has produced a patchwork of electricity systems across the country that use different energy sources, regulatory models, and approaches to trade and collaboration. While this model has worked to date, given our low consumer rates and high power reliability, collaborative action and a cohesive vision will be needed – not just for a 100-per-cent clean grid by 2035, but for a net-zero-enabling one by 2050.

Right now, it takes too long to move a clean power project from the proposal stage to operation – and far too long if we hope to attain a clean grid by 2035 and a net-zero-enabling one by 2050. This means that federal, provincial, territorial and Indigenous governments must work with rural communities and industry stakeholders to accelerate the approvals, financing and construction of clean energy projects and provide investor certainty.

In doing so, Canada can set a course to carbon neutrality while driving job creation and economic competitiveness, a transition many analyses deem practical and profitable in the long run. Our closest trading partners and many of the world’s largest companies and investors are demanding cleaner goods. A clean grid underpins clean production, just as it underpins our climate goals.

The International Energy Agency estimates that, for the world to reach net zero by 2050, clean electricity generation worldwide must increase by more than 2.5 times between today and 2050. Countries are already plotting their energy pathways, and there is much to learn from each other.

Consider South Australia. The state currently gets 62 per cent of its electricity from wind and solar and, combined with grid-scale battery storage, has not lost a single hour of electricity in the past five years. South Australia expects 100 per cent of its electricity to come from renewable sources before 2030. An added bonus given today’s high energy prices: Annual household electricity costs have declined there by 303 Australian dollars ($276) since 2018.

The transition to clean energy is not about sacrificing our way of life – it’s about improving it. But we’ll need the power to make it happen. That work needs to start now.

Merran Smith is the executive director of Clean Energy Canada, a program at the Morris J. Wosk Centre for Dialogue at Simon Fraser University in Vancouver. Mark Zacharias is a special adviser at Clean Energy Canada and visiting professor at the Simon Fraser University School of Public Policy.

 

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Green energy could drive Covid-19 recovery with $100tn boost

Renewable Energy Economic Recovery drives GDP gains, job growth, and climate targets by accelerating clean energy investment, green hydrogen, and grid modernization, delivering high ROI and a resilient, low-carbon transition through stimulus and policy alignment.

 

Key Points

A strategy to boost GDP and jobs by accelerating clean power and green hydrogen while meeting climate goals.

✅ Adds $98tn to global GDP by 2050; $3-$8 return per $1 invested

✅ Quadruples clean energy jobs to 42m; improves health and welfare

✅ Cuts CO2 70% by 2050; enables net-zero via green hydrogen

 

Renewable energy could power an economic recovery from Covid-19 through a green recovery that spurs global GDP gains of almost $100tn (£80tn) between now and 2050, according to a report.

The International Renewable Energy Agency’s new IRENA report found that accelerating investment in renewable energy could generate huge economic benefits while helping to tackle the global climate emergency.

The agency’s director general, Francesco La Camera, said the global crisis ignited by the coronavirus outbreak exposed “the deep vulnerabilities of the current system” and urged governments to invest in renewable energy to kickstart economic growth and help meet climate targets.

The agency’s landmark report found that accelerating investment in renewable energy would help tackle the climate crisis and would in effect pay for itself.

Investing in renewable energy would deliver global GDP gains of $98tn above a business-as-usual scenario by 2050, as clean energy investment significantly outpaces fossil fuels, by returning between $3 and $8 on every dollar invested.

It would also quadruple the number of jobs in the sector to 42m over the next 30 years, and measurably improve global health and welfare scores, according to the report.

“Governments are facing a difficult task of bringing the health emergency under control while introducing major stimulus and recovery measures, as a US power coalition demands action,” La Camera said. “By accelerating renewables and making the energy transition an integral part of the wider recovery, governments can achieve multiple economic and social objectives in the pursuit of a resilient future that leaves nobody behind.”

The report also found that renewable energy could curb the rise in global temperatures by helping to reduce the energy industry’s carbon dioxide emissions by 70% by 2050 by replacing fossil fuels, with measures like a fossil fuel lockdown hastening the shift.

Renewables could play a greater role in cutting carbon emissions from heavy industry and transport to reach virtually zero emissions by 2050, particularly by investing in green hydrogen.

The clean-burning fuel, which can replace the fossil fuel gas in steel and cement making, could be made by using vast amounts of clean electricity to split water into hydrogen and oxygen elements.

Andrew Steer, chief executive of the World Resources Institute, said: “As the world looks to recover from the current health and economic crises, we face a choice: we can pursue a modern, clean, healthy energy system, or we can go back to the old, polluting ways of doing business. We must choose the former.”

The call for a green economic recovery from the coronavirus crisis comes after a warning from Dr Fatih Birol, head of the International Energy Agency, that government policies must be put in place to avoid an investment hiatus in the energy transition, even as the solar and wind industry faces Covid-19 disruptions.

“We should not allow today’s crisis to compromise the clean energy transition, even as wind power growth persists despite Covid-19,” he said. “We have an important window of opportunity.”

Ignacio Galán, the chairman and CEO of the Spanish renewables giant Iberdrola, which owns Scottish Power, said the company would continue to invest billions in renewable energy as well as electricity networks and batteries to help integrate clean energy in the electricity.

“A green recovery is essential as we emerge from the Covid-19 crisis. The world will benefit economically, environmentally and socially by focusing on clean energy,” he said. “Aligning economic stimulus and policy packages with climate goals is crucial for a long-term viable and healthy economy.”

 

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ATCO Electric agrees to $31 million penalty following regulator's investigation

ATCO Electric administrative penalty underscores an Alberta Utilities Commission probe into a sole-sourced First Nation contract, Jasper transmission line overpayments, and nondisclosure to ratepayers, sparked by a whistleblower and pending settlement approval.

 

Key Points

A $31M AUC settlement over alleged overpayment, sole-sourcing, and nondisclosure tied to a Jasper transmission line.

✅ $31M administrative penalty; AUC settlement pending approval

✅ Sole-sourced First Nation contract to protect related ATCO deal

✅ Overpayment concealed when seeking recovery from ratepayers

 

Regulated Alberta utility ATCO Electric has agreed to pay a $31 million administrative penalty after an Alberta Utilities Commission utilities watchdog investigation found it deliberately overpaid a First Nation group for work on a new transmission line, and then failed to disclose the reasons for it when it applied to be reimbursed by ratepayers for the extra cost.

An agreed statement of facts contained in a settlement agreement between ATCO Electric Ltd. and the commission's enforcement staff says the company sole-sourced a contract in 2018 for work that was necessary for an electric transmission line to Jasper, Alta., even as BC Hydro marked a Site C transmission line milestone elsewhere.

The company that won the contract was co-owned by the Simpcw First Nation in Barriere, B.C., while debates over a First Nations electricity line in Ontario underscore related issues, and the agreement says one of the reasons for the sole-sourcing was that another of Calgary-based ATCO's subsidiaries had a prior deal with the First Nation for infrastructure projects that included the provision of work camps on the Trans Mountain Pipeline expansion project.

The statement of facts says ATCO Electric feared that if it didn't grant the contract to the First Nation group and instead put the work to tender, amid legal pressures such as a treaty rights challenge, the group might back out of its deal with ATCO Structures and Logistics and partner with another, non-ATCO company on the Trans Mountain work.

The agreed statement says ATCO Electric paid several million dollars more than market value for some of the Jasper line work, while a Manitoba-Minnesota line delay was being weighed in another jurisdiction, and staff attempted to conceal the reasons for the overpayment when they sought to recover the extra money from Alberta consumers.

It states the investigation was sparked by a whistleblower, and notes the agreement between the utility commission's enforcement staff and ATCO Electric must still be approved by the Alberta Utilities Commission, a process comparable to hearings that consider oral traditional evidence on interprovincial lines.

The commission must be satisfied the settlement is in the public interest, a consideration often informed by concerns from Site C opponents in other regions.

 

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Only one in 10 utility firms prioritise renewable electricity – global study

Utility Renewable Investment Gap highlights Oxford study in Nature Energy: most electric utilities favor fossil fuels over clean energy transition, expanding coal and gas, risking stranded assets and missing climate targets despite global decarbonization commitments.

 

Key Points

Most utilities grow fossil capacity over renewables, slowing decarbonization and jeopardizing climate goals.

✅ Only 10% expand renewables faster than coal and gas growth

✅ 60% still add fossil plants; 15% actively cut coal and gas

✅ Risks: stranded assets, missed climate targets, policy backlash

 

Only one in 10 of the world’s electric utility companies are prioritising clean energy investment over growing their capacity of fossil fuel power plants, according to research from the University of Oxford.

The study of more than 3,000 utilities found most remain heavily invested in fossil fuels despite international efforts to reduce greenhouse gas emissions and barriers to 100% renewables in the US that persist, and some are actively expanding their portfolio of polluting power plants.

The majority of the utility companies, many of which are state owned, have made little change to their generation portfolio in recent years.

Only 10% of the companies in the study, published in the research journal Nature Energy, are expanding their renewable energy capacity, mirroring global wind and solar growth patterns, at a faster rate than their gas- or coal-fired capacity.

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Of the companies prioritising renewable energy growth, 60% have not stopped concurrently expanding their fossil fuel portfolio and only 15% of these companies are actively reducing their gas and coal capacity.

Galina Alova, the author of the report, said the research highlighted “a worrying gap between what is needed” to tackle the climate crisis, with calls for a fossil fuel lockdown gaining attention, and “what actions are being taken by the utility sector”.

The report found 10% of utilities were favouring growth in gas-fired power plants. This cluster is dominated by US utilities, even as renewables surpass coal in US generation in the broader market, eager to take advantage of the country’s shale gas reserves, followed by Russia and Germany.

Only 2% of utilities are actively growing their coal-fired power capacity ahead of renewables or gas. This cluster is dominated by Chinese utilities – which alone contributed more than 60% of coal-focused companies – followed by India and Vietnam.

The report found the majority of companies prioritising renewable energy were clustered in Europe. Many of the industry’s biggest players are investing in low-carbon energy and green technologies, even as clean energy's dirty secret prompts debate, to replace their ageing fossil fuel power plants.


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In the UK, amid UK renewables backlog that has stalled billions, coal plants are shutting at pace ahead of the government’s 2025 ban on coal-fired power in part because the UK’s domestic carbon tax on power plants make them uneconomic to run.

“Although there have been a few high-profile examples of individual electric utilities investing in renewables, this study shows that overall, the sector is making the transition to clean energy slowly or not at all,” Alova said.

“Utilities’ continued investment in fossil fuels leaves them at risk of stranded assets – where power plants will need to be retired early – and undermines global efforts to tackle climate change.”
 

 

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