Fusion receives major financial backing

By Globe and Mail


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One of Canada's leading purveyors of fossil fuels, oil sands company Cenovus Energy Inc. CVE-T, is placing a bet on a science-fiction energy source in hopes that nuclear fusion can one day help squeeze bitumen out of Fort McMurray.

The company is making a $4-million investment in General Fusion, a Burnaby, B.C.-based startup that announced $19.5-million in new development capital, including some from Bezos Expeditions, the personal investment company of Amazon.com founder Jeff Bezos.

General Fusion ranks among Canada's most ambitious small companies, with a goal to create a new energy source that could have global application.

"This is the holy grail of energy," said founder Michel Laberge. "In 100 years, the whole planet will run on fusion."

Over the course of the last decade, Mr. Laberge has worked on a barebones budget to develop this technology, knowing he is attempting something that has eluded throngs of scientists around the world. The billions of dollars spent on similar attempts have, so far, failed.

Mr. Laberge, meanwhile, started building his own fusion prototype in an old gas station. General Fusion has since grown to 45 employees, including 10 with doctorates in plasma physics, and there are plans to add 20 more staff this year.

Yet the company's ambition remains a very long shot — even if the potential prize, the development of a mass energy source that could compete with coal on cost without any greenhouse emissions or nuclear waste, is enormous.

For Cenovus, the investment is tiny by corporate standards: It represents roughly a half-day's cash flow, and pales in comparison to the billions it is pouring into building its oil sands projects. But it carries some symbolic significance for a small company attempting to differentiate itself as a technical innovator in an industry criticized for not doing more to protect the environment. And if fusion works, it could help displace natural gas as the primary energy source for the extraction of bitumen that process has been compared to burning gold to make lead.

"If it works, it could potentially be applied in the oil sands operation," said Dave Hassan, team lead of environmental technology investments for Cenovus, which has also poured money into diesel emission reductions and well-abandonment technology. "And it may be something where we would actually want to become a fusion energy producer."

For General Fusion, it's much-needed new capital — the company has raised a total of $30-million to put toward developing the highly complex systems needed to make fusion power. Venture capitalists such as Chrysalix, GrowthWorks, Braemer Energy Ventures, Entrepreneurs Fund and SET Venture Partners have also contributed.

General Fusion is currently building full-scale components to show the systems will work. But the company is still years away from generating electricity.

"This is a long-term process. The reality is, before we've got a working power plant sitting here churning out electricity 24/7 for 30 years, there's going to be hundreds of millions — if not billions — needed to be invested. So we will be raising money again for some time," said Michael Delage, General Fusion's vice-president of business development.

Mr. Laberge is happy to tackle a problem no one else has yet solved. "I want to save the planet because we're going down the drain," he said. "Why do I attempt it where everybody else has failed? I must have a big head or something. I think I can beat the big guys."

Unlike nuclear power, which uses fission, or the breakup of atoms, to create electricity, fusion works by pressing atoms together. That has proven immensely difficult. It requires huge pressure and temperatures as high as 150-million degrees Celsius. ITER, a major international fusion plant being built in the south of France, carries an estimated $21-billion price tag, and is purely a demonstration project. It will take that project many more years — and many more billions — to build a commercial power plant.

General Fusion believes it can do that for far less — and far faster.

"We're saying that if we can do what we believe we can do, by four years from now we'll be in a position ITER can't possibly get to before 2035," said Mike Brown, chairman of energy venture capital company Chrysalix and one of the earliest investors in General Fusion. "Now, it's all dependent on whether these things work. And let's not kid ourselves — one of the reasons fusion is hard is because it's hard."

General Fusion has designed a system that uses a sphere surrounded by 200 pistons. Those pistons are designed to each hit within 10-millionths of a second, creating a simultaneous wave of pressure that helps create a fusion reaction. It hasn't been easy. Recent years have seen the company succeed in synchronizing the timing of piston strikes, but it has yet to create the force needed. The pistons must hit at 180 kilometres per hour, and so far, they have achieved 108 kph. Modifications are making progress, but they take time.

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Heathrow Airport Power Outage: Vulnerabilities Flagged Days Before Disruption

Heathrow Airport Power Outage 2025 disrupted operations with mass flight cancellations and diversions after a grid failure, exposing infrastructure resilience gaps, crisis management flaws, and raising passenger compensation and safety oversight concerns.

 

Key Points

A grid failure closed Heathrow, causing mass cancellations and diversions, exposing resilience and communication lapses.

✅ Grid fire triggered airport-wide shutdown

✅ 1,400+ flights canceled or diverted

✅ Inquiry probes resilience, communication, compensation

 

On March 21, 2025, Heathrow Airport, Europe's busiest, suffered a catastrophic power outage, similar to another high-profile outage seen at major events, that led to the cancellation and diversion of over 1,400 flights, affecting nearly 300,000 passengers and costing airlines an estimated £100 million. The power failure, triggered by a fire at an electricity substation in west London, left Heathrow with a significant operational crisis. This disruption is even more significant considering that Heathrow is one of the most expensive airports globally, which raises concerns about its infrastructure resilience and broader electricity system resilience across Europe.

In a parliamentary committee meeting, Heathrow officials admitted that vulnerabilities in the airport’s power supply were flagged just days before the outage. Nigel Wicking, Chief Executive of the Heathrow Airline Operators' Committee (HAOC), informed MPs that concerns regarding power resilience had been raised on March 15, following disruptions caused by cable thefts impacting runway lights. Despite these warnings, the airport’s management did not address the vulnerabilities urgently, even as UK net zero policies continue to reshape infrastructure planning, which ultimately led to the disastrous outage.

The airport was closed for a day, with serious consequences for not only airlines but also the surrounding community and businesses. British Airways alone faced millions of pounds in losses, and passengers experienced significant emotional distress, missing vital life events like weddings and funerals due to flight cancellations. The committee is now questioning officials from National Grid and Scottish and Southern Electricity Networks to better understand why Heathrow’s infrastructure failed, in the context of a cleaner grid following the British carbon tax that reduced coal use, how it communicated with affected parties, and what measures will be taken to compensate impacted passengers.

Heathrow’s Chief Executive, Thomas Woldbye, defended the closure decision, stating it would have been disastrous to keep the airport open under such circumstances. He noted that continuing operations would have left tens of thousands of passengers stranded and would have posed safety risks due to the failure of fire surveillance and CCTV systems. However, Wicking, representing the airlines, pointed out that Heathrow’s lack of resilience was unacceptable given the amount spent on the airport, emphasizing the need for better infrastructure, including addressing SF6 in switchgear during upgrades, and more transparent management practices.

Looking forward, the MPs intend to investigate the airport’s emergency preparedness, why the resilience review from 2018 wasn’t shared with airlines, and whether enough preventative measures were in place amid surging data demand that could strain electricity supplies. The outcome of this inquiry could have lasting effects on how Heathrow and other major airports handle their infrastructure and crisis management systems, as drought-driven hydro challenges demonstrate the wider climate stresses on power networks.

 

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"Kill the viability": big batteries to lose out from electricity grid rule change

AEMC Storage Charging Rules spark industry backlash as Tesla, Snowy Hydro, and investors warn transmission charges on batteries and pumped hydro could deter grid-scale storage, distort the National Electricity Market, and slow decarbonisation.

 

Key Points

AEMC Storage Charging Rules are proposals to bill grid storage for network use, shaping costs and investment.

✅ Charges apply when batteries draw power; double-charging concerns.

✅ Tesla and Snowy Hydro warn of reduced viability and delays.

✅ AEMO recommends exemptions; investors seek certainty.

 

Tesla, Snowy Hydro and other big suppliers of storage capacity on Australia’s main electricity grid warn proposed rule changes amount to a tax on their operations that will deter investors and slow the decarbonisation of the industry.

The Australian Energy Market Commission (AEMC) will release its final decision this Thursday on new rules for integrating batteries, pumped hydro and other forms of storage.

The AEMC’s draft decision, released in July, angered many firms because it proposed charging storage providers for drawing power, ignoring a recommendation by the Australian Electricity Market Operator (AEMO) that they be exempt.

Battery maker Tesla, which has supplied some of the largest storage to the National Electricity Market, said in a submission that the charges would “kill the commercial viability of all grid storage projects, causing inefficient investment in alternative network”, with consumers paying higher costs.

Snowy Hydro, which is building the giant Snowy 2 pumped storage project and already operates a smaller one, said in its submission the proposed changes if implemented would jeopardise investment.

“This is a major policy change, amounting to a tax on infrastructure critical to achieving a renewable future,” Snowy Hydro said.

AEMO itself argued it was important storage providers were not “disincentivised from connecting to the transmission network, as they generally provide a net benefit to the power system by charging at periods of low demand”.

Australia’s electricity grid faces economic and engineering challenges, similar to Ontario's storage push as it adjusts to the arrival of lower cost and also lower carbon alternatives to fossil fuels.

While rule changes are necessary to account for operators that can both draw from and supply power, how they are implemented can have long-lasting effects on the technologies that get encouraged or repelled, including control of EV charging issues, independent experts say.

“It doesn’t have to be this way,” said Bruce Mountain, director of the Victoria Energy Policy Centre. “In Britain, where the UK grid transformation is underway, the regulator dealing with the same issues has said that storage devices don’t pay the system charges when they withdraw electricity from the grid,” he said.

The prospect that storage operators will have to pay transmission charges could “drastically” affect their profitability since their business models rely on the difference between the price their pay for power and how much they can sell it for. Gas generators and network monopolies would benefit from the change, Mountain said.

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An AEMC spokesperson said the commission had consulted widely, including from those who objected to the payment for transmission access.

“The market is moving towards a future that will be increasingly reliant on energy storage to firm up the growing volume of renewable energy and deliver on the increasing need for critical system security services, with examples such as EVs supporting grid stability in California as the ageing fleet of thermal generators retire,” the spokesperson said, declining to elaborate on the final ruling before it is published.

“The regulatory framework needs to facilitate this transition as the energy sector continues to decarbonise,” the official said.

AusNet, which operates the Victorian energy transmission grid, said that while “technological neutrality is paramount for battery and hybrid unit connections to both the distribution and transmission networks,” it did not back charging storage access to networks in all cases.

“[Ausnet] supports a clear exemptions framework for energy storage providers,” a spokesperson said. “We recommend that batteries and other hybrid facilities should have transmission use of system charges waived if they provide a net benefit to network customers.”

We are not aware of anyone that supports the charging storage access to networks in all circumstances.

“Batteries and hybrid facilities that consume energy from the network should be provided no preferential treatment relative to other customers and generators.”

Jonathan Upson, a principal at Strategic Renewable Consulting, though, said the AEMC wants electricity flowing through batteries to be taxed twice to pay network charges – once when the electricity charges the battery and then again when the same electricity is sent out by the battery an hour or two later but this time with customers paying.

“The AEMC’s draft decision has the identical rationale for eliminating franking credits on all dividends, resulting in double taxing of company profits,” he said.

Christiaan Zuur, director of energy transformation at the Clean Energy Council, said that while much of AEMC’s draft proposal was constructive, “those benefits are either nullified or maybe even outweighed” by uncertainty over charges.

“Risk perception” will be important since potential newcomers won’t be sure of what charges they will pay to connect to the grid and existing operators could have their connection agreements reopened, Zuur said.

“Investors focus on the potential risk. It does factor through to the integral costs for projects,” he said.

The outcome of new charges may prompt more people to put batteries on their premises and draw power from their own solar panels, Mountain said, with rising EV adoption introducing new grid challenges, cutting their reliance on a centralised network.

“Ironically, it encourages customers to depend less and less on the grid,” he said. “It’s almost like the capture of the dominant interests playing out over time at their own expense.”

Separately, the latest edition of the Clean Energy Council Confidence Index shows leadership by state governments is helping to shore up investor appetite for investing in renewable energy amid 2021 electricity lessons even with higher 2030 emissions reduction goals from the federal government.

Overall, investor confidence increased by a point in the last six months – from 6.3 to 7.3 out of 10 – following strong commitments and policy development from state governments, particularly on the east coast, the council said.

“The results of this latest survey illustrate the economic value in policy that lowers the emissions footprint of our electricity generation, supporting regional centres and creating jobs. Investors recognise the opportunities created by limiting global temperature rise to 1.5 degrees,” said council chief executive Kane Thornton.

Among the states, NSW, Victoria and Queensland led in terms of positive investor sentiment.

Correction: this article was amended on 30 November. An earlier version stated Ausnet supported charging storage for network access. A spokesperson said it backed a waiver on charges if certain conditions are met.        

 

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Sudbury Hydro crews aim to reconnect service after storm

Sudbury Microburst Power Outage strains hydro crews after straight-line winds; New Sudbury faces downed power lines, tree damage, and hazardous access as restoration efforts, mutual aid, and safety protocols aim to reconnect customers by weekend.

 

Key Points

A microburst downed lines in New Sudbury, cutting power as crews tackle hazardous access and complex repairs.

✅ Straight-line winds downed poles, trees, and service lines

✅ Crews face backyard access hazards, complex reconnections

✅ Mutual aid linemen, arborists, and crane work speed restoration

 

About 300 Sudbury Hydro customers are still without power Thursday after Monday's powerful microburst storm, part of a series of damaging storms in Ontario seen across the province.

The utility's spokesperson, Wendy Watson, says the power in the affected New Sudbury neighbourhoods should be back on by the weekend, even as Toronto power outages persisted in a recent storm.

The storm, which Environment Canada said was classified as a microburst or straight line wind damage, similar to a severe windstorm in Quebec, downed a number of power lines in the city.

Now crews are struggling with access to the lines, a challenge that BC Hydro's atypical storm response also highlighted, as they work to reconnect service in the area.

"In some cases, you can't get to someone's back yard, or you have to go through the neighbour's yard," Watson said.

"We have one case where [we had] equipment working over a swimming pool. It's dicey, it's really dirty and it's dangerous."

Monday's storm caused massive property damage across the city, particularly in New Sudbury. (Benjamin Aubé/CBC)

Veteran arborist Jim Allsop told CBC News he hasn't seen damage like this in his 30-plus years in the business.

"I don't know how many we've done up to date, but I have another 35 trees on houses," Allsop said. "We'll be probably another week."

"We've rented a crane to help speed up the process, and increase safety, and we're getting five or six done in our 12-hour days."

Scott Aultman, a lineman with North Bay Hydro, said he has seen a few storms in his career, and isn't usually surprised by extensive damage a storm can cause.

"When you see a trailer on its side, you know, you don't see that every day," Aultman said.

But during the clean up, Aultman said the spirit of camaraderie runs high with crews from different areas, as seen when Canadian crews helped Florida during Hurricane Irma.

"We were pumped. It's part of the trade, everybody gets together," Aultman said. "We had a big storm in 2006 and the Sudbury guys were up helping us, so it's great, it's nice to be able to return the favour and help them out."

 

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California's future with income-based flat-fee utility bills is getting closer

California Income-Based Utility Fees would overhaul electricity bills as CPUC weighs fixed charges tied to income, grid maintenance costs, AB 205 changes, and per-kilowatt-hour rates, shifting from pure usage pricing to hybrid utility rate design.

 

Key Points

Income-based utility fees are fixed monthly charges tied to earnings, alongside per-kWh rates, to help fund grid costs.

✅ CPUC considers fixed charges by income under AB 205

✅ Separates grid costs from per-kWh energy charges

✅ Could shift rooftop solar and EV charging economics

 

Electricity bills in California are likely to change dramatically in 2026, with major changes under discussion statewide.

The California Public Utilities Commission (CPUC) is in the midst of an unprecedented overhaul of the way most of the state’s residents pay for electricity, as it considers revamping electricity rates to meet grid and climate goals.

Utility bills currently rely on a use-more pay-more system, where bills are directly tied to how much electricity a resident consumes, a setup that helps explain why prices are soaring for many households.

California lawmakers are asking regulators to take a different approach, and some are preparing to crack down on utility spending as oversight intensifies. Some of the bill will pay for the kilowatt hours a customer uses and a monthly fixed fee will help pay for expenses to maintain the electric grid: the poles, the substations, the batteries, and the wires that bring power to people’s homes.

The adjustments to the state’s public utility code, section 739.9, came about because of changes written into a sweeping energy bill passed last summer, AB 205, though some lawmakers now aim to overturn income-based charges in subsequent measures.

A stroke of a pen, a legislative vote, and the governor’s signature created a move toward unprecedented income-based fixed charges across the state.

“This was put in at the last minute,” said Ahmad Faruqui, a California economist with a long professional background in utility rates. “Nobody even knew it was happening. It was not debated on the floor of the assembly where it was supposedly passed. Of course, the governor signed it.”

Faruqui wonders who was responsible for legislation that was added to the energy bill during the budget writing process. That process is not transparent.

“It’s a very small clause in a very long bill, which is mostly about other issues,” Faruqui said.

But that small adjustment could have a massive impact on California residents, because it links the size of a monthly flat fee for utility service to a resident’s income. Earn more money and pay a higher flat fee.

That fee must be paid even before customers are charged for how much power they draw.

Regulators interpreted legislative change as a mandate, but Faruqui is not sold.

“They said the commission may consider or should consider,” Faruqui said. “They didn’t mandate it. It’s worth re-reading it.”

In fact, the legislative language says the commission “may” adopt income-based flat fees for utilities. It does not say the commission “should” adopt them.

Nevertheless, the CPUC has already requested and received nine proposals for how a flat fee should be implemented, as regulators face calls for action amid soaring electricity bills.

The suggestions came from consumer groups, environmentalists, the solar industry and utilities.

 

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Quebec Hit by Widespread Power Outages Following Severe Windstorm

Quebec Windstorm 2025 disrupted Montreal and surrounding regions, triggering power outages, Hydro-Québec repairs, fallen trees, infrastructure damage, and transport delays, while emergency response and community resilience accelerated restoration and recovery efforts across the province.

 

Key Points

A severe April 29 windstorm with 100 km/h gusts caused outages, damage, and emergency recovery across Quebec.

✅ Gusts exceeded 100 km/h across Montreal and nearby regions

✅ Hydro-Québec restored power; crews cleared debris and lines

✅ Communities shared resources, shelters, and volunteer support

 

A powerful windstorm swept across Quebec on April 29, 2025, leaving tens of thousands of residents without electricity and causing significant damage to infrastructure. The storm's intensity disrupted daily life, leading to widespread outages across the province, fallen trees, and transportation delays.

Storm's Impact

The windstorm, characterized by gusts exceeding 100 km/h, struck various regions of Quebec, including Montreal and its surrounding areas. Hydro-Québec reported extensive power outages affecting numerous customers. The storm's ferocity led to the uprooting of trees, downing of power lines, and significant damage to buildings and vehicles.

Response and Recovery Efforts

In the aftermath, emergency services and utility companies mobilized to restore power and clear debris. Hydro-Québec crews worked tirelessly, much like Sudbury Hydro teams did in Ontario, to repair damaged infrastructure, while municipal authorities coordinated efforts to ensure public safety and facilitate the restoration process. Despite these efforts, some areas experienced prolonged outages, highlighting the storm's severity.

Community Resilience

Residents demonstrated remarkable resilience during the crisis. Many communities came together to support one another, as seen when Toronto neighborhoods rallied during lingering outages, sharing resources and providing assistance to those in need. Local shelters were set up to offer warmth and supplies to displaced individuals, and volunteers played a crucial role in the recovery process.

Lessons Learned

The storm underscored the importance of preparedness and infrastructure resilience, including vulnerabilities highlighted by a recent manhole fire affecting Hydro-Québec customers. In response, discussions have been initiated regarding the strengthening of power grids and the implementation of more robust emergency response strategies to mitigate the impact of future natural disasters.

As Quebec continues to recover, the collective efforts of its residents and emergency services serve as a testament to the province's strength and unity, even as similar strong-wind outages affect other regions, in the face of adversity.

 

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California Blackouts reveal lapses in power supply

California Electricity Reliability covers grid resilience amid heat waves, rolling blackouts, renewable energy integration, resource adequacy, battery storage, natural gas peakers, ISO oversight, and peak demand management to keep homes, businesses, and industry powered.

 

Key Points

Dependable California power delivery despite heat waves, peak demand, and challenges integrating renewables into grid.

✅ Rolling blackouts revealed gaps in resource adequacy.

✅ Early evening solar drop requires fast ramping and storage.

✅ Agencies pledge planning reforms and flexible backup supply.

 

One hallmark of an advanced society is a reliable supply of electrical energy for residential, commercial and industrial consumers. Uncertainty that California electricity will be there when we need it it undermines social cohesion and economic progress, as demonstrated by the travails of poor nations with erratic energy supplies.

California got a small dose of that syndrome in mid-August when a record heat wave struck the state and utilities were ordered to impose rolling blackouts to protect the grid from melting down under heavy air conditioning demands.

Gov. Gavin Newsom quickly demanded that the three overseers of electrical service to most of the state - the Public Utilities Commission, the Energy Commission and the California Independent Service Operator – explain what went wrong.

"These blackouts, which occurred without prior warning or enough time for preparation, are unacceptable and unbefitting of the nation's largest and most innovative state," Newsom wrote. "This cannot stand. California residents and businesses deserve better from their government."

Initially, there was some fingerpointing among the three entities. The blackouts had been ordered by the California Independent System Operator, which manages the grid and its president, Steve Berberich, said he had warned the Public Utilities Commission about the potential supply shortfall facing the state.

"We have indicated in filing after filing after filing that the resource adequacy program was broken and needed to be fixed," he said. "The situation we are in could have been avoided."

However, as political heat increased, the three agencies hung together and produced a joint report that admitted to lapses of supply planning and grid management and promised steps to avoid a repeat next summer.

"The existing resource planning processes are not designed to fully address an extreme heat storm like the one experienced in mid August," their report said. "In transitioning to a reliable, clean and affordable resource mix, resource planning targets have not kept pace to lead to sufficient resources that can be relied upon to meet demand in the early evening hours. This makes balancing demand and supply more challenging."

Although California's grid had experienced greater heat-related demands in previous years, most notably 2006, managers then could draw standby power from natural gas-fired plants and import juice from other Western states when necessary.

Since then, the state has shut down a number of gas-fired plants and become more reliant on renewable but less reliable sources such as windmills and solar panels.

August's air conditioning demand peaked just as output from solar panels was declining with the setting of the sun and grid managers couldn't tap enough electrons from other sources to close the gap.

While the shift to renewables didn't, unto itself, cause the blackouts, they proved the need for a bigger cushion of backup generation or power storage in batteries or some other technology. The Public Utilities Commission, as Beberich suggested, has been somewhat lax in ordering development of backup supply.

In the aftermath of the blackouts, the state Water Resources Control Board, no doubt with direction from Newsom's office, postponed planned shutdowns of more coastal plants, which would have reduced supply flexibility even more.

Shifting to 100% renewable electricity, the state's eventual goal, while maintaining reliability will not get any easier. The state's last nuclear plant, Diablo Canyon, is ticketed for closure and demand will increase as California eliminates gasoline- and diesel-powered vehicles in favor of "zero emission vehicles" as part of its climate policies push and phases out natural gas in homes and businesses.

Politicians such as Newsom and legislators in last week's blackout hearing may endorse a carbon-free future in theory, but they know that they'll pay the price as electricity prices climb if nothing happens when Californians flip the switch.

 

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