Chalk River reactor returns to service

By Toronto Star


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The Chalk River nuclear reactor, offline since mid-November, started back in service the morning of December 16 and is expected to begin producing medical isotopes within four days, Atomic Energy of Canada Ltd said.

The reactor makes more than two-thirds of global supply of the radioisotopes used in cancer tests. Shortages were quickly triggered last month when the reactor was shut down.

The reactor was supposed to be closed from Nov. 18 to Nov. 23 for planned maintenance, but the Canadian Nuclear Safety Commission refused to let it be restarted without an upgrade on the cooling pumps that prevent the reactor core from melting down.

The commission had discovered that AECL had been operating the reactor for 17 months without a battery-operated starter on the pumps, which the commission said was a condition of renewing the 50-year-old reactor's licence.

AECL spokesperson Dale Coffin said the Crown corporation voluntarily extended the maintenance shutdown to address the safety commission's concerns.

"We're still operating very safely and the reactor with the new upgrade in place already is even safer," said David Torgerson, the president of Atomic Energy of Canada's research and technology division.

Parliament pushed through legislation recently to bypass the commission's objections and get the reactor back online.

Meanwhile, the Conservative government says it's just a coincidence the AECL chairman quit last week following a furor over the shutdown of the reactor.

Health Minister Tony Clement said Michael Burns thought the chairman's post was a part-time one when he took it a year ago.

"As it turns out, there's a lot of work to be done," Clement said yesterday on CTV's Question Period. "So I think there were some indications this (resignation) might be coming up."

Prime Minister Stephen Harper announced the departure of Burns, a former Tory party fundraiser, in a terse news release.

The Tories appointed former Ontario bureaucrat Glenna Carr as the new chairman and named business executive Hugh MacDiarmid as chief executive officer.

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How Canada can capitalize on U.S. auto sector's abrupt pivot to electric vehicles

Canadian EV Manufacturing is accelerating with GM, Ford, and Project Arrow, integrating cross-border supply chains, battery production, rare-earths like lithium and cobalt, autonomous tech, and home charging to drive clean mobility and decarbonization.

 

Key Points

Canadian EV manufacturing spans electric and autonomous vehicles, domestic batteries, and integrated US-Canada trade.

✅ GM and Ford retool plants for EVs and autonomous production

✅ Project Arrow showcases Canadian zero-emission supply capabilities

✅ Lithium, cobalt, and battery hubs target cross-border resilience

 

The storied North American automotive industry, the ultimate showcase of Canada’s high-tensile trade ties with the United States and emerging Canada-U.S. collaboration on EVs momentum, is about to navigate a dramatic hairpin turn.

But as the Big Three veer into the all-electric, autonomous era, some Canadians want to seize the moment and take the wheel.

“There’s a long shadow between the promise and the execution, but all the pieces are there,” says Flavio Volpe, president of the Automotive Parts Manufacturers’ Association.

“We went from a marriage on the rocks to one that both partners are committed to. It could be the best second chapter ever.”

Volpe is referring specifically to GM, which announced late last month an ambitious plan to convert its entire portfolio of vehicles to an all-electric platform by 2035.

But that decision is just part of a cascading transformation across the industry, marking an EV inflection point with existential ramifications for one of the most tightly integrated cross-border manufacturing and supply-chain relationships in the world.

China is already working hard to become the “source of a new way” to power vehicles, President Joe Biden warned last week.

“We just have to step up.”

Canada has both the resources and expertise to do the same, says Volpe, whose ambitious Project Arrow concept — a homegrown zero-emissions vehicle named for the 1950s-era Avro interceptor jet — is designed to showcase exactly that, as recent EV assembly deals in Canada underscore.

“We’re going to prove to the market, we’re going to prove to the (manufacturers) around the planet, that everything that goes into your zero-emission vehicle can be made or sourced here in Canada,” he says.

“If somebody wants to bring what we did over the line and make 100,000 of them a year, I’ll hand it to them.”

GM earned the ire of Canadian auto workers in 2018 by announcing the closure of its assembly plant in Oshawa, Ont. It later resurrected the facility with a $170-million investment to retool it for autonomous vehicles.

“It was, ‘You closed Oshawa, how dare you?’ And I was one of the ‘How dare you’ people,” Volpe says.

“Well, now that they’ve reopened Oshawa, you sit there and you open your eyes to the commitment that General Motors made.”

Ford, too, has entered the fray, promising $1.8 billion to retool its sprawling landmark facility in Oakville, Ont., to build EVs.

It’s a leap of faith of sorts, considering what market experts say is ongoing consumer doubt about EVs and EV supply shortages that drive wait times.

“Range anxiety” — the persistent fear of a depleted battery at the side of the road — remains a major concern, even though it’s less of a problem than most people think.

Consulting firm Deloitte Canada, which has been tracking automotive consumer trends for more than a decade, found three-quarters of future EV buyers it surveyed planned to charge their vehicles at home overnight.

“The difference between what is a perceived issue in a consumer’s mind and what is an actual issue is actually quite negligible,” Ryan Robinson, Deloitte’s automotive research leader, says in an interview.

“It’s still an issue, full stop, and that’s something that the industry is going to have to contend with.”

So, too, is price, especially with the end of the COVID-19 pandemic still a long way off. Deloitte’s latest survey, released last month, found 45 per cent of future buyers in Canada hope to spend less than $35,000 — a tall order when most base electric-vehicle models hover between $40,000 and $45,000.

“You put all of that together and there’s still, despite the electric-car revolution hype, some major challenges that a lot of stakeholders that touch the automotive industry face,” Robinson says.

“It’s not just government, it’s not just automakers, but there are a variety of stakeholders that have a role to play in making sure that Canadians are ready to make the transition over to electric mobility.”

With protectionism no longer a dirty word in the United States and Biden promising to prioritize American workers and suppliers, the Canadian government’s job remains the same as it ever was: making sure the U.S. understands Canada’s mission-critical role in its own economic priorities.

“We’re both going to be better off on both sides of the border, as we have been in the past, if we orient ourselves toward this global competition as one force,” says Gerald Butts, vice-chairman of the political-risk consultancy Eurasia Group and a former principal secretary to Prime Minister Justin Trudeau.

“It served us extraordinarily well in the past … and I have no reason to believe it won’t serve us well in the future.”

Last month, GM announced a billion-dollar plan to build its new all-electric BrightDrop EV600 van in Ingersoll, Ont., at Canada’s first large-scale EV manufacturing plant for delivery vehicles.

That investment, Volpe says, assumes Canada will take the steps necessary to help build a homegrown battery industry — with projects such as a new Niagara-region battery plant pointing the way — drawing on the country’s rare-earth resources like lithium and cobalt that are waiting to be extracted in northern Ontario, Quebec and elsewhere.

Given that the EV industry is still in his infancy, the free market alone won’t be enough to ensure those resources can be extracted and developed, he says.

“General Motors made a billion-dollar bet on Canada because it’s going to assume that the Canadian government — this one or the next one — is going to commit” to building that business.

Such an investment would pay dividends well beyond the auto sector, considering the federal Liberal government’s commitment to lowering greenhouse gas-emissions, including a 2035 EV mandate, and meeting targets set out in the Paris climate accord.

“If you make investments in renewable energy and utility storage using battery technology, you can build an industry at scale that the auto industry can borrow,” Volpe says.

Major manufacturing, retail and office facilities would be able to use that technology to help “shave the peak” off Canada’s GHG emissions and achieve those targets, all the while paving the way for a self-sufficient electric-vehicle industry.

“You’d be investing in the exact same technology you’d use in a car.”

There’s one problem, says Robinson: the lithium-ion batteries on roads right now might not be where the industry ultimately lands.

“We’re not done with with battery technology,” Robinson says. “What you don’t want to do is invest in a technology that is that is rapidly evolving, and could potentially become obsolete going forward.”

Fuel cells — energy-efficient, hydrogen-powered units that work like batteries, but without the need for constant recharging — continue to be part of the conversation, he adds.

“The amount of investment is huge, and you want to be sure that you’re making the right decision, so you don’t find yourself behind the curve just as all that capacity is coming online.”

 

 

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Warren Buffett’s Secret To Cheap Electricity: Wind

Berkshire Hathaway Energy Wind Power drives cheap electricity rates in Iowa via utility-scale wind turbines, integrated transmission, battery storage, and grid management, delivering renewable energy, stable pricing, and long-term rate freezes through 2028.

 

Key Points

A vertically integrated wind utility lowering Iowa rates via owned generation, transmission, and advanced grid control.

✅ Owned wind assets meet Iowa residential demand

✅ Integrated transmission lowers costs and losses

✅ Rate freeze through 2028 sustains cheap power

 

In his latest letter to Berkshire Hathaway shareholders, Warren Buffett used the 20th anniversary of Berkshire Hathaway Energy to tout its cheap electricity bills for customers.

When Berkshire purchased the majority share of BHE in 2000, the cost of electricity for its residential customers in Iowa was 8.8 cents per kilowatt-hour (kWh) on average. Since then, these electricity rates have risen at a paltry <1% per year, with a freeze on rate hikes through 2028. As anyone who pays an electricity bill knows, that is an incredible deal.  

As Buffett himself notes with alacrity, “Last year, the rates [BHE’s competitor in Iowa] charged its residential customers were 61% higher than BHE’s. Recently, that utility received a rate increase that will widen the gap to 70%.”

 

The Winning Strategy

So, what’s Buffett’s secret to cheap electricity? Wind power.

“The extraordinary differential between our rates and theirs is largely the result of our huge accomplishments in converting wind into electricity,” Buffett explains. 

Wind turbines in Iowa that BHE owns and operates are expected to generate about 25.2 million megawatt-hours (MWh) of electricity for its customers, as projects like Building Energy operations begin to contribute. By Buffett’s estimations, that will be enough to power all of its residential customers’ electricity needs in Iowa.  


The company has plans to increase its renewable energy generation in other regions as well. This year, BHE Canada is expected to start construction on a 117.6MW wind farm in Alberta, Canada with its partner, Renewable Energy Systems, that will provide electricity to 79,000 homes in Canada’s oil country.

Observers note that Alberta is a powerhouse for both green energy and fossil fuels, underscoring the region's unique transition.

But I would argue that the secret to BHE’s success perhaps goes deeper than transitioning to sources of renewable energy. There are plenty of other utility companies that have adopted wind and solar power as an energy source. In the U.S., where renewable electricity surpassed coal in 2022, at least 50% of electricity customers have the option to buy renewable electricity from their power supplier, according to the Department of Energy. And some states, such as New York, have gone so far as to allow customers to pick from providers who generate their electricity.

What differentiates BHE from a lot of the competition in the utility space is that it owns the means to generate, store, transmit and supply renewable power to its customers across the U.S., U.K. and Canada, with lessons from the U.K. about wind power informing policy.

In its financial filings for 2019, the company reported that it owns 33,600MW of generation capacity and has 33,400 miles of transmission lines, as well as a 50% interest in Electric Transmission Texas (ETT) that has approximately 1,200 miles of transmission lines. This scale and integration enables BHE to be efficient in the distribution and sale of electricity, including selling renewable energy across regions.

BHE is certainly not alone in building renewable-energy fueled electricity dominions. Its largest competitor, NextEra, built 15GW of wind capacity and has started to expand its utility-scale solar installations. Duke Energy owns and operates 2,900 MW of renewable energy, including wind and solar. Exelon operates 40 wind turbine sites across the U.S. that generate 1,500 MW.

 

Integrated Utilities Power Ahead

It’s easy to see why utility companies see wind as a competitive source of electricity compared to fossil fuels. As I explained in my previous post, Trump’s Wrong About Wind, the cost of building and generating wind energy have fallen significantly over the past decade. Meanwhile, improvements in battery storage and power management through new technological advancements have made it more reliable (Warren Buffett bet on that one too).

But what is also striking is that integrated power and transmission enables these utility companies to make those decisions; both in terms of sourcing power from renewable energy, as well as the pricing of the final product. Until wind and solar power are widespread, these utility companies are going to have an edge of the more fragmented ends of the industry who can’t make these purchasing or pricing decisions independently. 

Warren Buffett very rarely misses a beat. He’s not the Oracle of Omaha for nothing. Berkshire Hathaway’s ownership of BHE has been immensely profitable for its shareholders. In the year ended December 31, 2019, BHE and its subsidiaries reported net income attributable to BHE shareholders of $2.95 billion.

There’s no question that renewable energy will transform the utility industry over the next decade. That change will be led by the likes of BHE, who have the power to invest, control and manage their own energy generation assets.

 

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Mike Sangster to Headline Invest in African Energy Forum

TotalEnergies Africa Energy Strategy 2025 spotlights oil, gas, LNG, and renewables, with investments in Namibia, Congo, Mozambique, Uganda, Morocco, and South Africa, driving upstream growth, clean energy, and energy transition partnerships.

 

Key Points

An investment roadmap uniting oil, gas, LNG, and renewables to speed Africa's upstream growth and energy transition.

✅ Keynote by Mike Sangster at IAE Paris 2025.

✅ Oil, gas, LNG projects across Namibia, Congo, Mozambique, Uganda.

✅ Scaling renewables: solar, wind, green ammonia for export.

 

Mike Sangster, Senior Vice President for Africa at TotalEnergies, will play a pivotal role in the upcoming Invest in African Energy (IAE) Forum, which will take place in Paris on May 13-14, 2025. As a key figure in one of the world’s largest energy companies, Sangster's participation in the forum is expected to offer crucial insights into Africa’s evolving energy landscape, particularly in the areas of oil, gas, and renewable energy.

TotalEnergies' Role in Africa's Energy Landscape

TotalEnergies has long been a major player in Africa’s energy sector, driving development across both emerging and established markets. The company has a significant footprint in countries such as Namibia, the Republic of Congo, Libya, Mozambique, Uganda, and South Africa. TotalEnergies’ investments span both traditional oil and gas projects as well as renewable energy initiatives, reflecting its commitment to a more diversified energy future for Africa.

In Namibia, for instance, TotalEnergies is advancing its Venus-1 discovery, with plans to produce its first oil by the end of the decade. The company is also heavily involved in the Orange Basin exploration. Meanwhile, in the Republic of Congo, TotalEnergies is investing $600 million to enhance deepwater production at its Moho Nord field.

Beyond oil and gas, the company is expanding its renewable energy portfolio across the continent. This includes significant solar, wind, and hydropower projects, such as the 500 MW Sadada solar project in Libya, a 216 MW solar plant with battery storage in South Africa, and a 1 GW wind and solar project in Morocco designed to produce green ammonia for export.

The Invest in African Energy Forum

The IAE Forum, which TotalEnergies’ Sangster will headline, is an exclusive event aimed at facilitating investment between African energy markets and global investors, including discussions on COVID-19 funding for electricity access mechanisms that emerged, and their relevance to current capital flows. With a focus on fostering partnerships and discussions about the future of energy in Africa, the event will bring together industry experts, project developers, investors, and policymakers for two days of intensive engagement.

The forum will also serve as a crucial platform for sharing perspectives on the role of private investment, as outlined in the IEA investment outlook for Africa's power systems, in Africa’s energy future, strategies for unlocking new upstream opportunities, and the transition to a more sustainable energy system. This makes Sangster's participation, as someone directly involved in both conventional and renewable energy projects across the continent, particularly significant.

TotalEnergies' Diversified Strategy in Africa

Sangster’s keynote address and participation in an exclusive fireside chat will provide an in-depth look into TotalEnergies’ strategy for Africa. His insights will touch upon the company's ongoing projects in the oil and gas sectors, as well as its renewable energy investments. TotalEnergies has committed to making its portfolio more sustainable, underscored by its recent VSB acquisition to expand renewables capabilities, while continuing to be a leader in the energy transition.

One of the company’s notable projects is the Mozambique LNG initiative, a $20 billion venture aimed at supplying liquefied natural gas to international markets. Additionally, TotalEnergies is gearing up for the first oil from its Tilenga field in Uganda, which will be transported through the East African Crude Oil Pipeline (EACOP), the longest heated crude oil pipeline in the world.

In South Africa, TotalEnergies is constructing one of the largest renewable energy projects, a 216 MW solar power plant with integrated battery storage. This project is expected to significantly contribute to the country’s clean energy ambitions. Furthermore, in Morocco, TotalEnergies is developing a major wind and solar facility that will produce green ammonia, aligning with its broader strategy to provide solutions for Europe’s energy needs.

Africa’s Energy Transition

The forum’s timing could not be more critical, given the pressing need for an energy transition in Africa. While the continent remains heavily reliant on fossil fuels for its energy needs, there is growing momentum toward incorporating renewable energy sources, a point reinforced by the IRENA renewables report on decarbonisation and quality of life, which highlights the transformative potential. Africa’s vast natural resources, combined with global investments and partnerships, position the continent as a key player in the global shift toward sustainable energy.

However, Africa faces unique challenges in transitioning to renewable energy, reflecting a broader Sub-Saharan electricity challenge that also presents opportunity, across many markets. These challenges include a lack of infrastructure, financial constraints, and the need for increased political stability in certain regions. The IAE Forum provides an opportunity to address these barriers, with industry leaders like Sangster offering solutions based on real-world experiences and investments.

As the energy sector continues to evolve globally, and even if electricity systems are unlikely to go fully green this decade according to some outlooks, Africa's potential remains vast. The continent’s diverse energy resources, from oil and gas to renewables, offer a unique opportunity to build a more sustainable and resilient energy future. The Invest in African Energy Forum serves as an important platform for global stakeholders to collaborate, learn, and invest in the energy transformation taking place across the continent.

Mike Sangster’s insights at the forum will undoubtedly shape discussions on how companies like TotalEnergies are navigating the intersection of universal electricity access goals, sustainability, and economic growth in Africa. With Africa’s energy needs expected to increase exponentially in the coming decades, ensuring that these needs are met sustainably and equitably will be a priority for both policymakers and private investors.

As the global energy landscape continues to shift, the Invest in African Energy Forum provides a critical space for shaping the future of Africa’s energy sector, offering invaluable opportunities for investment, innovation, and collaboration.

 

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Melting Glass Experiment Surprises Scientists by Defying a Law of Electricity

Electric Field-Induced Glass Softening reveals a Joule heating anomaly in silicate glass, where anode-side nanoscale alkali depletion drives ionic conduction, localized thermal runaway, melting, and evaporation, challenging homogeneity assumptions and refining materials processing models.

 

Key Points

An effect where electric fields lower glass softening temperature via nanoscale ionic migration and structural change.

✅ Anode-side alkali depletion creates extreme, localized heating

✅ Thermal runaway melts glass near the anode despite uniform bulk

✅ Findings refine Joule heating models and enable new glass processing

 

A team of scientists working with electrical currents and silicate glass have been left gobsmacked after the glass appeared to defy a basic physical law, in a field that also explores electricity-from-air devices for novel energy harvesting.

If you pass an electrical current through a material, the way that current generates heat can be described by Joule's first law. It's been observed time and time again, with the temperature always evenly distributed when the material is homogeneous (or uniform).

But not in this recent experiment. A section - and only a section - of silicate glass became so hot that it melted, and even evaporated. Moreover, it did so at a much lower temperature than the boiling point of the material.

The boiling point of pure silicate glass is 2,230 degrees Celsius (4,046 degrees Fahrenheit). The hottest temperature the researchers recorded in a homogeneous piece of silicate glass during the experiment was 1,868.7 degrees Celsius.

Say whaaaat.

"The calculations did not add up to explain what we were seeing as simply standard Joule heating," said engineer and materials scientist Himanshu Jain of Lehigh University.

"Even under very moderate conditions, we observed fumes of glass that would require thousands of degrees higher temperature than Joule's law could predict!"

Jain and his colleagues from materials science company Corning Incorporated were investigating a phenomenon they had described in a previous paper. In 2015, they reported that an electric field could reduce the temperature at which glass softens, by as much as a few hundred degrees, a line of inquiry that parallels work on low-cost heat-to-electricity materials in energy research. They called this "electric field-induced softening."

 

It was certainly a peculiar phenomenon, so they set up another experiment. They put pieces of glass in a furnace, and applied 100 to 200 volts in the form of both alternating and direct currents.

Next, a thin wisp of vapour emanated from the spot where the anode conveying the current contacted the glass.

"In our experiments, the glass became more than a thousand degrees Celsius hotter near the positive side than in the rest of the glass, which was very surprising considering that the glass was totally homogeneous to begin with," Jain said.

This seems to fly in the face of Joule's first law, so the team investigated more closely - and found that the glass wasn't remaining as homogeneous as it started out. The electric field changed the chemistry and the structure of the glass on nanoscale, in just a small section close to the anode.

This region heats faster than the rest of the glass, to the point of becoming a thermal runaway - where an increase in temperature further increases temperature in a blistering feedback loop.

As it turned out, that spot of structural change and dramatic heat resulted in a small area of glass reaching melting point while the rest of the material remained solid.

"Unlike electronically conducting metals and semiconductors, with time the heating of ionically conducting glass becomes extremely inhomogeneous with the formation of a nanoscale alkali-depletion region, such that the glass melts near the anode, even evaporates, while remaining solid elsewhere," the researchers wrote in their paper.

In other words, the material wasn't homogeneous any more, which means the glass heating experiment doesn't exactly change how we apply Joule's first law.

But it's an exciting result, since until now we didn't know a material could actually lose its homogeneity with the application of an electrical current, with possible implications for thin-film heat harvesters in electronics. (The thing is, no one had tried electrically heating glass to these extreme temperatures before.)

So the physical laws of the Universe are still okay, as a piece of glass hasn't broken them. But Joule's first law may need a bit of tweaking to take this effect into account, a reminder that unconventional energy concepts like nighttime solar cells also challenge our intuitions.

And, of course, it's another piece of understanding that could help us in other ways too, including advances in thermoelectric materials that turn waste heat into electricity.

"Besides demonstrating the need to qualify Joule's law," Jain said, "the results are critical to developing new technology for the fabrication and manufacturing of glass and ceramic materials."

The research has been published in Scientific Reports.

 

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Ontario's electricity 'recovery rate' could lead to higher hydro bills

Ontario Hydro Flat Rate sets a single electricity rate at 12.8 cents per kWh, replacing time-of-use pricing for Ontario ratepayers, affecting hydro bills this summer, alongside COVID-19 Energy Assistance Program support.

 

Key Points

A fixed 12.8 cents per kWh electricity price replacing time-of-use rates across Ontario from June to November.

✅ Single rate applies 24/7, replacing time-of-use pricing

✅ May slightly raise bills versus pre-pandemic usage patterns

✅ COVID-19 aid offers one-time credits for households, small firms

 

A new provincial COVID-19 measure, including a fixed COVID-19 hydro rate designed to give Ontario ratepayers "stability" on their hydro bills this summer, could result in slightly higher hydro costs over the next four months.

Ontario Premier Doug Ford's government announced over the weekend that consumers would be charged a single around-the-clock electricity rate between June and November, before a Nov. 1 rate increase takes effect, replacing the much-derided time-of-use model ratepayers have complained about for years.

Instead of being charged between 10 to 20 cents per kilowatt hour, depending on the time of day electricity is used, including ultra-low TOU rates during off-peak hours, hydro users will be charged a blanket rate of 12.8 cents per kWh.

"The new rate will simply show up on your bill," Premier Doug Ford said at a Monday afternoon news conference.

While the government said the new fixed rate would give customers "greater flexibility" to use their home appliances without having to wait for the cheapest rate -- and has tabled legislation to lower rates as part of its broader plan -- the new policy also effectively erases a pandemic-related hydro discount for millions of consumers.

For example, a pre-pandemic bill of $59.90 with time-of-use rates, will now cost $60.28 with the government's new recovery rate, as fixed pricing ends across the province, before delivery charges, rebates and taxes.

That same bill would have been much cheaper -- $47.57 -- if the government continued applying the lowest tier of time-of-use 24/7 under an off-peak price freeze as it had been doing since March 24.

The government also introduced support for electric bills with two new assistance programs to help customers struggling to pay their bills.

The COVID-19 Energy Assistance Program will provide a one-time payment consumers to help pay off electricity debt incurred during the pandemic -- which will cost the government $9 million.

The government will spend another $8 million to provide similar assistance to small businesses hit hard by the pandemic.

 

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National Grid to lose Great Britain electricity role to independent operator

UK Future System Operator to replace National Grid as ESO, enabling smart grid reform, impartial system planning, vehicle-to-grid, long duration storage, and data-driven oversight to meet net zero and cut consumer energy costs.

 

Key Points

The UK Future System Operator is an independent ESO and planner, steering net zero with impartial data and smart grid coordination.

✅ Replaces National Grid ESO with independent system operator

✅ Enables smart grid, vehicle-to-grid, and long-duration storage

✅ Supports net zero, lower bills, and impartial system planning

 

The government plans to strip National Grid of its role keeping Great Britain’s lights on as part of a proposed “revolution’” in the electricity network driven by smart digital grid technologies.

The FTSE 100 company has played a role in managing the energy system of England, Scotland and Wales, including efforts such as a subsea power link that brings renewable power from Scotland to England (Northern Ireland has its own network). It is the electricity system operator, balancing supply and demand to ensure the electricity supply. But it will lose its place at the heart of the industry after government officials put forward plans to replace it with an independent “future system operator”.

The new system controller would help steer the country towards its climate targets, at the lowest cost to energy bill payers, by providing impartial data and advice after an overhaul of the rules governing the energy system to make it “fit for the future”.

The plans are part of a string of new proposals to help connect millions of electric cars, smart appliances and other green technologies to the energy system, and to fast-track grid connections nationwide, which government officials believe could help to save £10bn a year by 2050, and create up to 10,000 jobs for electricians, data scientists and engineers.

The new regulations aim to make it easier for electric cars to export electricity from their batteries back on to the power grid or to homes when needed. They could also help large-scale and long-duration batteries play a role in storing renewable energy, supported by infrastructure such as a 2GW substation helping integrate supply, so that it is available when solar and wind power generation levels are low.

Anne-Marie Trevelyan, the energy and climate change minister, said the rules would allow households to “take control of their energy use and save money” while helping to make sure there is clean electricity available “when and where it’s needed”.

She added: “We need to ensure our energy system can cope with the demands of the future. Smart technologies will help us to tackle climate change while making sure that the lights stay on and bills stay low.”

The energy regulator, Ofgem, raised concerns earlier this year that National Grid would face a “conflict of interest” in providing advice on the future electricity system because it also owns energy networks that stand to benefit financially from future investment plans. It called for a new independent operator to take its place.

Jonathan Brearley, Ofgem’s chief executive, said the UK requires a “revolution” in how and when it uses electricity, including demand shifts during self-isolation to help meet its climate targets and added that the government’s plans for a new digital energy system were “essential” to meeting this goal “while keeping energy bills affordable for everyone”.

A National Grid spokesperson said the company would “work closely” with the government and Ofgem on the role of a future system operator, as well as “the most appropriate ownership model and any future related sale”.

The division has earned National Grid, which has addressed cybersecurity fears in supplier choices, an average of £199m a year over the last five years, or 1.3% of the group’s total revenues, which are split between the UK – where it operates high-voltage transmission lines in England and Wales, and the country’s gas system – and its growing energy supply business in the US, aligned with investment in a smarter electricity infrastructure in the US to modernize grids.

 

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