New reactor head ready for Davis-Besse

Hydro-Que9bec 2020 Profit Outlook faces COVID-19 headwinds as revenue drops, U.S. Northeast export demand weakens, and clean-energy infrastructure plans shift toward domestic investments, energy efficiency, EV charging stations, and grid upgrades to stabilize net income.

Key Points

A forecast of COVID-19 revenue declines, weaker U.S. exports, and a shift to energy efficiency and grid upgrades.

✅ Q1 profit fell 14%; net income $1.53B vs $1.77B

✅ Exports to U.S. Northeast weaker; revenue off ~$130M Mar-Jun

✅ Strategy: energy efficiency, EV charging, grid, dam upgrades

Hydro-Québec expects the coronavirus pandemic to chop “hundreds of millions of dollars” off 2020 profits, its new chief executive officer said.

COVID-19 has depressed revenue by about $130 million between March and June, Sophie Brochu said Monday, as residential electricity use rose even while overall consumption dropped. Shrinking electricity exports to the U.S. northeast are poised to compound the shortfall, she said.

“What we’re living through is not small. The impacts are real,” Brochu said on a conference call with reporters, noting that utilities such as Hydro One supported Ontario's COVID-19 response at the height of the pandemic. “I’m not talking about a billion. I’m talking about hundreds of millions. We have no idea how quickly the economy will restart. As we approach the fall we will have a better view.”

Hydro-Québec last month reported a 14-per-cent drop in first-quarter profit and warned full-year results would fall short of targets as the COVID-19 crisis weighs on power demand. Net income in the quarter was $1.53 billion compared with $1.77 billion a year ago, the company said.

Canada’s biggest electricity producer had earlier been targeting 2020 profit of between $2.8 billion and $3 billion, according to its current strategic plan and corporate structure currently in place.

The first quarter was the utility’s last under former CEO Eric Martel, who left to take over at jetmaker Bombardier Inc. Brochu, who previously ran Énergir, replaced him April 6.

To boost exports over time, Brochu said Hydro-Québec will look to strengthen ties with neighbours such as Ontario, where the Hydro One CEO is working to repair relations with government and investors, and the U.S. The CEO said she’s heartened by New York Governor Andrew Cuomo’s call last month for new power lines from Canada and upstate to promote clean energy.

“This is a clear, encouraging signal that must express itself through very concrete negotiations,” she said. “The United States is our backyard. This is true for Ontario, where key system staff lockdowns were even contemplated, and the Atlantic provinces as well. This is our ecosystem, and we intend to build on our footprint, on the relationships that we have.”

Though stricter environmental hurdles make it more complicated to get power lines built today than a decade ago, the CEO insists it’s still possible to sell electricity to neighbouring U.S. states.

“Is it more difficult today to build energy projects? The answer is yes,” she said. “Does this clog up the U.S. northeast market? Not at all. I believe this federation of ecosystems is very promising.”

In the meantime, Hydro-Québec is planning to speed up investments at home — for example, by building new charging stations that will be needed to serve a growing fleet of electric cars. The utility will also upgrade some of its Montreal-area facilities, as well as its massive dams on the Manicouagan River, Brochu said. The investments will result in additional capacity.

“Today we need to put water in the pump of Quebec, so we will concentrate our human and financial efforts here,” she said. “We are needed in Quebec.” 

Hydro-Québec is stepping up efforts to promote energy efficiency among its customer base, amid retroactive billing concerns, which Brochu said could postpone the need to build large dams.

“We have to move towards ‘no-regret moves.’ What’s a no-regret move? It’s energy efficiency,” Brochu said earlier Monday during a presentation to the Chamber of Commerce of Metropolitan Montreal, noting that Ontario debated peak rate relief for self-isolating customers. “This is healthy, it’s fundamental and it will contribute to Quebec’s economic rebound by lowering energy costs.”

Brochu also pledged to build a more diverse workforce after the company said last week that 8.2 per cent of staff belong to “visible and ethnic” minorities.

“This can be improved on,” she said. “What I’m expressing today is my determination, and that of the management team, to move the needle.”

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Germany Hydrogen-Ready Power Plants Tender accelerates the energy transition by enabling clean energy generation, decarbonization, and green hydrogen integration through retrofit and new-build capacity, resilient infrastructure, flexible storage, and grid reliability provisions.

Key Points

Germany tender to build or convert plants for hydrogen, advancing decarbonization, energy security, and clean power.

✅ Hydrogen-ready retrofits and new-build generation capacity

✅ Supports decarbonization, grid reliability, and flexible storage

✅ Future-proof design for green hydrogen supply integration

Germany, a global leader in energy transition and environmental sustainability, has recently launched an ambitious call for tenders aimed at developing hydrogen-ready power plants. This initiative is a significant step in the country's strategy to transform its energy infrastructure and support the broader goal of a greener economy. The move underscores Germany’s commitment to reducing greenhouse gas emissions and advancing clean energy technologies.

The Need for Hydrogen-Ready Power Plants

Hydrogen, often hailed as a key player in the future of clean energy, offers a promising solution for decarbonizing various sectors, including power generation. Unlike fossil fuels, hydrogen produces zero carbon emissions when used in fuel cells or burned. This makes it an ideal candidate for replacing conventional energy sources that contribute to climate change.

Germany’s push for hydrogen-ready power plants reflects the country’s recognition of hydrogen’s potential in achieving its climate goals. Traditional power plants, which typically rely on coal, natural gas, or oil, emit substantial amounts of CO2. Transitioning these plants to utilize hydrogen can significantly reduce their carbon footprint and align with Germany's climate targets.

The Details of the Tender

The recent tender call is part of Germany's broader strategy to incorporate hydrogen into its energy mix, amid a nuclear option debate in climate policy. The tender seeks proposals for power plants that can either be converted to use hydrogen or be built with hydrogen capability from the outset. This approach allows for flexibility and innovation in how hydrogen technology is integrated into existing and new energy infrastructures.

One of the critical aspects of this initiative is the focus on “hydrogen readiness.” This means that power plants must be designed or retrofitted to operate with hydrogen either exclusively or in combination with other fuels. The goal is to ensure that these facilities can adapt to the growing availability of hydrogen and seamlessly transition from conventional fuels without significant additional modifications.

By setting such requirements, Germany aims to stimulate the development of technologies that can handle hydrogen’s unique properties and ensure that the infrastructure is future-proofed. This includes addressing challenges related to hydrogen storage, transportation, and combustion, and exploring concepts like storing electricity in natural gas pipes for system flexibility.

Strategic Implications for Germany

Germany’s call for hydrogen-ready power plants has several strategic implications. First and foremost, it aligns with the country’s broader energy strategy, which emphasizes the need for a transition from fossil fuels to cleaner alternatives, building on its decision to phase out coal and nuclear domestically. As part of its commitment to the Paris Agreement and its own climate action plans, Germany has set ambitious targets for reducing greenhouse gas emissions and increasing the share of renewable energy in its energy mix.

Hydrogen plays a crucial role in this strategy, particularly for sectors where direct electrification is challenging. For instance, heavy industry and certain industrial processes, such as green steel production, require high-temperature heat that is difficult to achieve with electricity alone. Hydrogen can fill this gap, providing a cleaner alternative to natural gas and coal.

Moreover, this initiative helps Germany bolster its leadership in green technology and innovation. By investing in hydrogen infrastructure, Germany positions itself as a pioneer in the global energy transition, potentially influencing international standards and practices. The development of hydrogen-ready power plants also opens up new economic opportunities, including job creation in engineering, construction, and technology sectors.

Challenges and Opportunities

While the push for hydrogen-ready power plants presents significant opportunities, it also comes with challenges. Hydrogen production, especially green hydrogen produced from renewable sources, remains relatively expensive compared to conventional fuels. Scaling up production and reducing costs are critical for making hydrogen a viable alternative for widespread use.

Furthermore, integrating hydrogen into existing power infrastructure, alongside electricity grid expansion, requires careful planning and investment. Issues such as retrofitting existing plants, ensuring safe handling of hydrogen, and developing efficient storage and transportation systems must be addressed.

Despite these challenges, the long-term benefits of hydrogen integration are substantial, and a net-zero roadmap indicates electricity costs could fall by a third. Hydrogen can enhance energy security, reduce reliance on imported fossil fuels, and support global climate goals. For Germany, this initiative is a step towards realizing its vision of a sustainable, low-carbon energy system.

Conclusion

Germany’s call for hydrogen-ready power plants is a forward-thinking move that reflects its commitment to sustainability and innovation. By encouraging the development of infrastructure capable of using hydrogen, Germany is taking a significant step towards a cleaner energy future. While challenges remain, the strategic focus on hydrogen underscores Germany’s leadership in the global transition to a low-carbon economy. As the world grapples with the urgent need to address climate change, Germany’s approach serves as a model for integrating emerging technologies into national energy strategies.

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Nuclear Waste Corrosion accelerates as stainless steel, glass, and ceramics interact in aqueous conditions, driving localized corrosion in repositories like Yucca Mountain, according to Nature Materials research on high-level radioactive waste storage.

Key Points

Degradation of waste forms and canisters from water-driven chemistry, causing accelerated, localized corrosion in storage.

✅ Stainless steel-glass contact triggers severe localized attack

✅ Ceramics and steel co-corrosion observed under aqueous conditions

✅ Yucca Mountain-like chemistry accelerates waste form degradation

The materials the United States and other countries plan to use to store high-level nuclear waste, even as utilities expand carbon-free electricity portfolios, will likely degrade faster than anyone previously knew because of the way those materials interact, new research shows.

The findings, published today in the journal Nature Materials (https://www.nature.com/articles/s41563-019-0579-x), show that corrosion of nuclear waste storage materials accelerates because of changes in the chemistry of the nuclear waste solution, and because of the way the materials interact with one another.

"This indicates that the current models may not be sufficient to keep this waste safely stored," said Xiaolei Guo, lead author of the study and deputy director of Ohio State's Center for Performance and Design of Nuclear Waste Forms and Containers, part of the university's College of Engineering. "And it shows that we need to develop a new model for storing nuclear waste."

Beyond waste storage, options like carbon capture technologies are being explored to reduce atmospheric CO2 alongside nuclear energy.

The team's research focused on storage materials for high-level nuclear waste -- primarily defense waste, the legacy of past nuclear arms production. The waste is highly radioactive. While some types of the waste have half-lives of about 30 years, others -- for example, plutonium -- have a half-life that can be tens of thousands of years. The half-life of a radioactive element is the time needed for half of the material to decay.

The United States currently has no disposal site for that waste; according to the U.S. General Accountability Office, it is typically stored near the nuclear power plants where it is produced. A permanent site has been proposed for Yucca Mountain in Nevada, though plans have stalled. Countries around the world have debated the best way to deal with nuclear waste; only one, Finland, has started construction on a long-term repository for high-level nuclear waste.

But the long-term plan for high-level defense waste disposal and storage around the globe is largely the same, even as the U.S. works to sustain nuclear power for decarbonization efforts. It involves mixing the nuclear waste with other materials to form glass or ceramics, and then encasing those pieces of glass or ceramics -- now radioactive -- inside metallic canisters. The canisters then would be buried deep underground in a repository to isolate it.

At the generation level, regulators are advancing EPA power plant rules on carbon capture to curb emissions while nuclear waste strategies evolve.

In this study, the researchers found that when exposed to an aqueous environment, glass and ceramics interact with stainless steel to accelerate corrosion, especially of the glass and ceramic materials holding nuclear waste.

In parallel, the electrical grid's reliance on SF6 insulating gas has raised warming concerns across Europe.

The study qualitatively measured the difference between accelerated corrosion and natural corrosion of the storage materials. Guo called it "severe."

"In the real-life scenario, the glass or ceramic waste forms would be in close contact with stainless steel canisters. Under specific conditions, the corrosion of stainless steel will go crazy," he said. "It creates a super-aggressive environment that can corrode surrounding materials."

To analyze corrosion, the research team pressed glass or ceramic "waste forms" -- the shapes into which nuclear waste is encapsulated -- against stainless steel and immersed them in solutions for up to 30 days, under conditions that simulate those under Yucca Mountain, the proposed nuclear waste repository.

Those experiments showed that when glass and stainless steel were pressed against one another, stainless steel corrosion was "severe" and "localized," according to the study. The researchers also noted cracks and enhanced corrosion on the parts of the glass that had been in contact with stainless steel.

Part of the problem lies in the Periodic Table. Stainless steel is made primarily of iron mixed with other elements, including nickel and chromium. Iron has a chemical affinity for silicon, which is a key element of glass.

The experiments also showed that when ceramics -- another potential holder for nuclear waste -- were pressed against stainless steel under conditions that mimicked those beneath Yucca Mountain, both the ceramics and stainless steel corroded in a "severe localized" way.

Other Ohio State researchers involved in this study include Gopal Viswanathan, Tianshu Li and Gerald Frankel.

This work was funded in part by the U.S. Department of Energy Office of Science.

Meanwhile, U.S. monitoring shows potent greenhouse gas declines confirming the impact of control efforts across the energy sector.

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National Grid Demand Flexibility Service helps stabilise the UK grid during tight supply, offering discounts for smart meter users who shift peak-time electricity use, reducing power cut risks amid low wind and import constraints.

Key Points

A National Grid scheme paying smart homes to cut peak-time use, easing supply pressure and avoiding power cuts.

✅ Pays volunteers with smart meters to reduce peak demand.

✅ Credits discounts for shifting use to off-peak windows.

✅ Manages tight margins and helps avert UK power cuts.

National Grid has decided not to activate a scheme on Tuesday to help the UK avoid power cuts after being poised to do so.

It would have seen some households offered discounts on their electricity bills if they cut peak-time use.

National Grid had been ready to trigger the scheme following a warning that Britain's energy supplies were looking tighter than usual this week.

However, it decided that the measure was not required.

Alerts are sent out automatically when expected supplies drop below a certain level. But they do not mean that blackouts are likely, or that the situation is critical.

National Grid said it was "confident" it would be able to manage margins and "demand is not at risk".

Discounts
Earlier on Monday, the grid operator said it was considering whether to pay households across Britain to reduce their energy use to help out on Tuesday evening.

Under the Demand Flexibility Service (DFS), announced earlier this month, customers that have signed up could get discounts on their bills if they use less electricity in a given window of time.

That could mean delaying the use of a tumble-dryer or washing machine, or cooking dinner in the microwave rather than the oven.

Major suppliers such as Octopus and British Gas are taking part, but only customers that have an electricity smart meter and that have volunteered are eligible. About 14 million UK homes have an electricity smart meter.

The DFS has already been tested twice but has not yet run live.

Octopus, the supplier with the most customers signed up, said that some households had earned more than £4 during the hour-long tests, while the average saving was "well over £1".

It came after forecasts projected a large drop in the amount of power that Britain will be able to import from French nuclear power stations on Monday and Tuesday evenings.

The lack of strong winds to power turbines has also affected how much power can be generated within the UK, and efforts to fast-track grid connections aim to ease constraints.

Such warnings are not unusual - around 12 have been issued and cancelled without issue in the last six years, and other regions such as Canada are seeing grids strained by harsh weather as well.

However, they have become more common this year due to the energy crisis, and the most recent notice was sent out last week.

The situation means that the UK will have to import electricity from other sources on Monday and Tuesday evening.

Supplies are also expected be tight in France, forecasters say.

France has been facing months of problems with its nuclear power plants, which generate around three-quarters of the country's electricity.

More than half of the nuclear reactors run by state energy company EDF have closed due to maintenance problems and technical issues.

It has added to a massive energy crisis in Europe which is facing a winter without gas supplies from Russia.

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Nova Scotia Power Active Demand Control Tariff lets the utility direct Port Hawkesbury Paper load, enabling demand response, efficiency, and industrial electricity rates, while regulators assess impacts on ratepayers, grid reliability, mill viability, and savings.

Key Points

A four-year tariff letting the utility control the mill load for demand response, efficiency, and lower costs.

✅ Utility can increase or reduce daily consumption at the mill

✅ Projected savings of $10M annually for other ratepayers to 2023

✅ Regulators reviewing cost allocation, monitoring, and viability

Nova Scotia Power is scheduled to appear before government regulators Tuesday morning seeking approval for a unique discount rate for its largest customer.

Under the four-year plan, Nova Scotia Power would control the supply of electricity to Port Hawkesbury Paper, a move referenced in a grid operations report that urges changes, with the right to direct the company to increase or reduce daily consumption throughout the year.

The rate proposal is supported by the mill, which says it needs to lower its power bill to keep its operation viable.

The rate went into effect on Jan. 1 on a temporary basis, pending the outcome of a hearing this week before the Nova Scotia Utility and Review Board, amid broader calls for an independent body to lead electricity planning.

The mill accounts for 10 per cent of the provincial electricity load, even as a neighbouring utility pursues more Quebec power for the region, producing glossy paper used in magazines and catalogs.

Nova Scotia Power says controlling how much electricity the mill uses — and when — will allow it to operate the system much more efficiently, as it expands biomass generation initiatives, saving other customers $10 million a year until the rate expires in 2023.

Ceding control 'not an easy decision'
In its opening statement that was filed in advance, Port Hawkesbury Paper said ceding the control of its electrical supply to Nova Scotia Power was "not an easy decision" to make, but the company is confident the arrangement will work.

In September 2019, Nova Scotia Power and the mill jointly applied for an "extra large active demand control tariff," which would provide electricity to the mill for about $61 per megawatt hour, well below the full cost of generating the electricity.

The utility said "fully allocating costs" would result in "prices in excess of $80/MWh ... and [would] not [be] financially viable for the mill."

In its statement, Port Hawkesbury Paper said since the initial filing "there have been greater near term declines in market demand and pricing for PHP's product than was forecast at that time, continuing to put pressure on our business and further highlighting the need to maintain the balance provided for in the new tariff."

Consumer advocate sees 'advantage,' but will challenge
Bill Mahody represents Nova Scotia Power's 400,000 residential customers before the review board. He wants proof the mill will pay enough toward the cost of generating the electricity it uses, amid concerns over biomass use in the province today.

"We filed evidence, as have others involved in the proceeding, that would call into question whether or not the rate design is capturing all of those costs and that will be a significant issue before the board," Mahody said.

Still, he sees value in the proposal.

The proposed new rate went into effect on Jan. 1 on a temporary basis. (The Canadian Press)
"This proposed rate gives Nova Scotia Power the ability to control that sizable Port Hawkesbury Paper load to the advantage of other ratepayers, as the province pursues more wind and solar projects, because Nova Scotia Power would be reducing the costs that other ratepayers are going to face," he said.

Mahody is also calling for a mechanism to monitor whether the mill's position actually improves to the point where it could pay higher rates.

"An awful lot can change during a four-year period, with new tidal power projects underway, and I think the board ought to have the ability to check in on this and make sure that their preferential rate continues to be justified," he said.

Major employer
Port Hawkesbury Paper, owned by Stern Partners in Vancouver, has received discounted power rates since it bought the idled mill in 2012. But the "load retention tariff" as it was called, expired at the end of 2019.

Regulators have accepted Nova Scotia Power's argument that it would cost other customers more if the mill ceased to operate.

The mill said it spends between $235 million and $265 million annually, employing 330 people directly and supporting 500 other jobs indirectly.

The Nova Scotia government pledged $124 million in financial assistance as part of the reopening in 2012.

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UK Energy Switching Surge sees 600,000 customers change suppliers in October, driven by competition, the Energy Switch Guarantee, and better tariffs, with Electralink's DTN supporting customer switching and Ofgem oversight.

Key Points

A rise in UK customers switching electricity suppliers in October, driven by competition and the Energy Switch Guarantee.

✅ 600,000 switches recorded in October

✅ 32% moved to small and mid-tier suppliers

✅ Energy Switch Guarantee assures simple, safe transfers

More than 600,000 customers took steps to save on their energy bills this winter by switching electricity provider in October, as forecasts such as a 16% bill decrease in April offer further encouragement, the latest figures from Energy UK reveal.

A third (32 per cent) of those changing providers in October moved to small and mid-tier suppliers.

Regional markets have seen changes too, including Irish electricity price increases that highlight wider cost pressures.

With recent research showing that that nine in ten energy switchers were happy with the process of changing suppliers and with the reassurance provided by the Energy Switch Guarantee - a series of commitments ensuring switches are simple, speedy and safe - and amid MPs proposing price restrictions to protect consumers, more and more customers are now confident when looking to move.

Lawrence Slade, chief executive of Energy UK said: 'Switching continues to surge with over 600,000 customers changing supplier to find a better deal last month. Many more will have made savings by checking they are on the best deal with their current supplier. It only takes a few minutes to do this and with over 55 suppliers across the market, there's never been more competition or choice.'

Around 75 per cent of the market are signatories of the Guarantee. This includes: British Gas, Bulb Energy, E.ON, EDF Energy, First Utility, Flow Energy, npower, Octopus Energy, Pure Planet, Sainsbury's Energy, Scottish Power, So Energy and Tonik Energy.

The switching data is supplied by Electralink who provides a secure service to transfer data between the electricity market participants. The company operates the Data Transfer Network (DTN) which underpins customer switching, meter interoperability and other business processes critical to a competitive electricity market, where knowing where your electricity comes from can support informed choices.

The data referenced in these reports is since our collection of data only and is for electricity only.

These figures do not include internal electricity switching, and statistics on this from the larger suppliers and on Standard Variable Tariffs can be viewed on the Ofgem website, while ministers consider ending the gas-electricity price link to reduce bills.

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