Energy Department Announces 20 New Competitors for the American-Made Solar Prize

Wylfa Nuclear Project Cancellation reflects Hitachi's withdrawal, pulling £16bn from North Wales, risking jobs, reshaping UK nuclear power plans as renewables grow and Chinese involvement rises amid shifting energy market policies.

Key Points

An indefinite halt to Hitachi's Wylfa Newydd nuclear plant, removing about £16bn investment and jobs from North Wales.

✅ Hitachi withdraws funding amid changing energy market costs

✅ Puts 400 local roles and up to 10,000 construction jobs at risk

✅ UK shifts toward renewables as nuclear project support stalls

Chris Ruane said Japanese firm Hitachi’s announcement this morning about the Wylfa project would take £16 billion of investment out of the region.

He said it was the latest in a list of energy projects which had been scrapped as he responded to a statement from business secretary Greg Clark.

Mr Ruane, the Labour member for the Vale of Clywd, said: “In his statement he said the Government are relying now more on renewables, can I put the North Wales picture to him; 1,500 wind turbines were planned off the coast of North Wales. They were removed, those plans were cancelled by the private sector.

“The tidal lagoons for Wales were key to the development of the Welsh economy – the Government itself pulled the support for the Swansea Bay tidal lagoon. That had a knock-on effect for the huge lagoon planned off the coast of North Wales.

“And now today we hear of the cancellation of a £16 billion investment in the North Wales economy. This will devastate the North Wales economy. The people of North Wales need to know that the Prime Minister is batting for them and batting for the UK.”

Mr Clark blamed the changing landscape of the energy market for today’s announcement, and said Wales has been a “substantial and proud leader” in renewable energy during the UK’s green industrial revolution over recent years.

But another Labour MP from North Wales, Albert Owen, of Ynys Mon, said the Wylfa plant’s cancellation in his constituency is putting 400 jobs at risk, as well as the “potential of 8-10,000 construction jobs”, as well as hundreds of operational jobs and 33 apprenticeships.

He asked Mr Clark: “Can I say straightly can we work together to keep this project alive, to ensure that we create the momentum so it can be ready for a future developer or this developer with the right mechanism?”

The minister replied that he and his officials would “work together in a completely open-book way on the options” to try and salvage the project.

But in the Lords, Labour former security minister Lord West of Spithead said the UK’s nuclear industry was in crisis, noting that Europe is losing nuclear power as well.

“In the 1950s our nation led the world in nuclear power generation and decisions by successive governments, of all hues, have got us in the position today where we cannot even construct a large civil nuclear reaction,” he told peers at question time.

Lord West asked: “Are we content that now the only player seems to be Chinese and that by 2035… we are happy for the Chinese to control one third of the energy supply of our nation?”

Business, Energy and Industrial Strategy minister Lord Henley said the Government had hoped for a better announcement from Hitachi but that was not the case.

He said costs in the nuclear sector were rising, amid setbacks at Hinkley Point C, while costs for many renewables were coming down and this was one of the reasons for the problem.

Tory former energy secretary Lord Howell of Guildford said the Chinese were in “pole position” for the rebuilding and replacement “of our nuclear fleet” and this would have a major impact on UK energy policy and plans to meet net zero targets in the 2030s.

Plaid Cymru’s Lord Wigley warned that putting the Wylfa Newydd on indefinite hold would cause economic planning blight in north-west Wales and urged the Government to raise the level of support allocated to the region.

Lord Henley acknowledged the announcement was not welcome but added: “We remain committed to nuclear power. We will look to see what we can do. We still have a great deal of expertise in this country and we can work on that.”

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Hydro One-Avista acquisition sparks Idaho regulatory scrutiny over foreign ownership, utility merger impacts, rate credits, and public interest, as FERC and FCC approvals advance and consumers question governance, service reliability, and long-term rate stability.

Key Points

A cross-border utility merger proposal with Idaho oversight, weighing foreign ownership, rates, and reliability.

✅ Idaho PUC review centers on public interest and rate impacts.

✅ FERC and FCC approvals granted; state decisions pending.

✅ Avista to retain name and Spokane HQ post-transaction.

“Please don’t sell us to Canada.” That refrain, or versions of it, is on full display at the Idaho Public Utilities Commission, which admittedly isn’t everyone’s go-to entertainment site. But it is vitally important for this reason: the first big test of the expansionist dreams of the politically tempest-tossed Hydro One, facing political risk as it navigates markets, rests with its successful acquisition of Avista Corp., provider of electric generation, transmission and distribution to retail customers spread from Oregon to Washington to Montana and Idaho and up into Alaska.

The proposed deal — announced last summer, but not yet consummated — marks the first time the publicly traded Hydro One has embarked upon the acquisition of a U.S. utility. And if Idahoans spread from Boise to Coeur d’Alene to Hayden are any indication, they are not at all happy with the idea of foreign ownership. Here’s Lisa McCumber, resident of Hayden: “I am stating my objection to this outrageous merger/takeover. Hydro One charges excessive fees to the people it provides for, this is a monopoly beyond even what we are used to. I, in no way, support or as a customer, agree with the merger of this multi-billion-dollar, foreign, company.”

#google#

Or here’s Debra Bentley from Coeur d’Alene: “Fewer things have more control over a nation than its power source. In an age where we are desperately trying to bring American companies back home and ‘Buy American’ is somewhat of a battle cry, how is it even possible that it would or could be allowed for this vital necessity … to be controlled by a foreign entity?”

Or here’s Spencer Hutchings from Sagle: “This is an incredibly bad idea.”

There are legion of similar emails from concerned consumers, and the Maine transmission line debate offers a parallel in public opposition.

The rationale for the deal? Last fall Hydro One CEO Mayo Schmidt testified before the Idaho commission, which regulates all gas, water and electricity providers in the state. “Hydro One is a pure-play transmission and distribution utility located solely within Ontario,” Schmidt told commissioners. “It seeks diversification both in terms of jurisdictions and service areas. The proposed Transaction with Avista achieves both goals by expanding Hydro One into the U.S. Pacific Northwest and expanding its operations to natural gas distribution and electric generation. The proposed Transaction with Avista will deliver the increased scale and benefits that come from being a larger player in the utility industry.”

Translation: now that it is a publicly traded entity, Hydro needs to demonstrate a growth curve to the investment community. The value to you and me? Arguable. This is a transaction framed as a benefit to shareholders, one that won’t cause harm to customers. Premier Kathleen Wynne is feeling the pain of selling off control of an essential asset. In his testimony to the commission, Schmidt noted that the Avista acquisition would take the province’s Hydro ownership to under 45 per cent. (The Electricity Act technically prevents the sale of shares that would take the government’s ownership position below 40 per cent, though acquisitions appear to allow further dilution. )

Stratospheric compensation, bench-marked against other chief executives who enjoy similarly outsized rewards, is part of this game. I have written about Schmidt’s unconscionable compensation before, but that was when he was making a relatively modest $4 million. Relative, that is, to his $6.2 million in 2017 compensation ($3.5 million of that is in the form of share based awards).

Should the acquisition of Avista be approved, amendments to the CIC, or change in control agreements, for certain named Avista executive officers will allow them to voluntarily terminate their employment without “good reason.” That includes Scott Morris, the company’s CEO, who will exit with severance of $6.9 million (U.S.) and additional benefits taking the total to a potential $15.7 million.

Back to the deal: cost savings over time could be achieved, Schmidt continued in his testimony, though he was unable to quantify those. The integration between the two companies, he promised, will be “seamless.” Retail customers in Idaho, Washington and Oregon would benefit from proposed “Rate Credits” equalling an estimated $15.8 million across five years, even as Hydro One seeks to redesign its bills in Ontario. Idahoans would see a one per cent rate decrease through that period.

While Avista would become a wholly owned Hydro subsidiary, it would retain its name, and its headquarters in Spokane, Wash. In the case of Idaho specifically, a proposed settlement in April, subject to final approval by the commission, stipulates agreements on everything from staffing to governance to community contributions.

Will that meet the test? It’s up to the commission to determine whether the proposed transaction will keep a lid on rates and is “consistent with the public interest.” Hydro One is hoping for a decision from regulatory agencies in all the named states by mid-August and a closing date by the end of September, though U.S. regulators can ultimately determine the fate of such deals. The Federal Energy Regulatory Commission granted its approval in January, followed last week by the Federal Communications Commission. Washington and Alaska have reached settlement agreements. These too are pending final state approvals.

The $5.3-billion deal (or $6.7 billion Canadian) is subject to ongoing hearings in Idaho, and elsewhere rate hikes face opposition as hearings begin. Members of the public are encouraged to have their say. The public comment deadline is June 27.

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H2 Gateway Hydrogen Network accelerates clean energy in B.C., building electrolysis plants and hydrogen fueling stations for zero-emission vehicles, heavy-duty trucks, and long-haul transit, supporting decarbonization, green hydrogen supply, and infrastructure investment.

Key Points

A $900M B.C. initiative by HTEC to build electrolysis plants and 20 hydrogen fueling stations for zero-emission transport.

✅ $900M project with HTEC, CIB, and B.C. government

✅ 3 electrolysis plants plus byproduct liquefaction in North Vancouver

✅ Up to 20 stations; 14 for heavy-duty vehicles in B.C. and Alberta

British Columbia is taking a significant step towards a cleaner future with a brand new $900 million project. This initiative, spearheaded by hydrogen company HTEC and supported by the CIB in B.C. and the B.C. government, aims to establish a comprehensive hydrogen network across the province. This network will encompass both hydrogen production plants and fueling stations, marking a major leap in developing hydrogen infrastructure in B.C.

The project, dubbed "H2 Gateway," boasts several key components. At its core lies the construction of three brand new electrolysis hydrogen production plants. These facilities will be strategically located in Burnaby, Nanaimo, and Prince George, ensuring a wide distribution of hydrogen fuel. An additional facility in North Vancouver will focus on liquefying byproduct hydrogen, maximizing resource efficiency.

The most visible aspect of H2 Gateway will undoubtedly be the network of hydrogen fueling stations. The project envisions up to 20 stations spread across British Columbia and Alberta, complementing the province's Electric Highway build-out, with 18 being situated within B.C. itself. This extensive network will significantly enhance the accessibility of hydrogen fuel, making it a more viable option for motorists. Notably, 14 of these stations will be designed to handle heavy-duty vehicles, catering to the transportation sector's clean energy needs.

The economic and environmental benefits of H2 Gateway are undeniable. The project is expected to generate nearly 300 jobs, aligning with recent grid job creation efforts, providing a much-needed boost to the B.C. economy. More importantly, the widespread adoption of hydrogen fuel promises significant reductions in greenhouse gas emissions. Hydrogen-powered vehicles produce zero tailpipe emissions, making them a crucial tool in combating climate change.

British Columbia's investment in hydrogen infrastructure aligns with a global trend. As countries strive to achieve ambitious climate goals, hydrogen is increasingly viewed as a promising clean energy source. Hydrogen fuel cells offer several advantages over traditional electric vehicles, and while B.C. leads the country in going electric, they boast longer driving ranges and shorter refueling times, making them particularly attractive for long-distance travel and heavy-duty applications.

While H2 Gateway represents a significant step forward, challenges remain. The production of clean hydrogen, often achieved through electrolysis using renewable energy sources, faces power supply challenges and requires substantial initial investment. Additionally, the number of hydrogen-powered vehicles on the road is still relatively low.

However, projects like H2 Gateway are crucial in overcoming these hurdles. By creating a robust hydrogen infrastructure, B.C. is sending a strong signal to the industry and, alongside BC Hydro's EV charging expansion across southern B.C., is building a comprehensive clean transportation network. This investment will not only benefit the environment but also incentivize the development and adoption of hydrogen-powered vehicles. As the technology matures and production costs decrease, hydrogen fuel has the potential to revolutionize transportation and play a key role in a sustainable future.

The road ahead for hydrogen may not be entirely smooth, but British Columbia's commitment to H2 Gateway demonstrates a clear vision. By investing in clean energy infrastructure, the province is not only positioning itself as a leader in the fight against climate change, with Canada and B.C. investing in green energy solutions to accelerate progress, but also paving the way for a more sustainable transportation landscape.

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Manitoba Hydro Rate Increase sets electricity rates up 2.5% annually for three years via Bill 35, bypassing PUB hearings, citing Crown utility debt and pandemic impacts, with legislature debate and a multi-year regulatory review ahead.

Key Points

A government plan to lift electricity rates 2.5% annually over three years via Bill 35, bypassing PUB hearings.

✅ 2.5% annual hikes for three years set in legislation

✅ Bypasses PUB rate hearings during pandemic recovery

✅ Targets Crown utility debt; multi-year review planned

The Manitoba government is planning to raise electricity rates, with Manitoba Hydro scaling back next year, by 2.5 per cent a year over the next three years.

Finance Minister Scott Fielding says the increases, to be presented in a bill before the legislature, are the lowest in a decade and will help keep rates among the lowest in Canada, even as SaskPower's 8% hike draws scrutiny in a neighbouring province.

Crown-owned Manitoba Hydro had asked for a 3.5 per cent increase this year, similar to BC Hydro's 3% rise, to help pay off billions of dollars in debt.

“The way we figured this out, we looked at the rate increases that were approved by PUB (Public Utilities Board) over the last ten years, (and) we went to 75 per cent of that,” Fielding said during a Thursday morning press conference.

“It’s a pandemic, we know that there’s a lot of people that are unemployed, that are struggling, we know that businesses need to recharge after the business (sic), so this will provide them an appropriate break.”

Electricity rates are normally set by the Public Utilities Board, a regulatory body that holds rate hearings and examines the Crown corporation’s finances.

The Progressive Conservative government has temporarily suspended the regulatory process and has set rates itself, while Ontario rate legislation to lower rates moved forward in its jurisdiction.

Manitoba Liberal leader Dougald Lamont was quick to condemn the move, noting parallels to Ontario price concerns before saying in a news release the PCs “are abusing their power and putting Hydro’s financial future at risk by fixing prices in the hope of buying some political popularity.”

“Hydro’s rates should be set by the PUB after public hearings, not figured out on the back of a napkin in the Premier’s office,” Lamont wrote.

Fielding noted the increase would appear as an amendment to Bill 35, which will appear in the legislature this fall, as BC Hydro plans multi-year increases proceed elsewhere.

“All members of the legislative assembly will vote and debate this rate increase on Bill 35,” Fielding said.

“This will give the PUB time to implement reforms, and allow the utilities to prepare a more rigorous, multi-year review application process.”

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Miami Valley Windstorm Power Outages disrupted thousands as 60 mph gusts toppled trees, downed power lines, and damaged buildings. Utility crews and emergency services managed debris, while NWS alerts warned of extended restoration.

Key Points

Region-wide power losses from severe winds in the Miami Valley, causing damage, debris, and restoration.

✅ 60 mph gusts downed trees, snapped lines, blocked roads

✅ Crews from DP&L worked extended shifts to restore service

✅ NWS issued wind advisories; schools, businesses closed

On a recent day, powerful winds tore through the Miami Valley, causing significant disruption across the region. The storm, which was accompanied by gusts reaching dangerous speeds, led to windstorm power outages affecting thousands of homes and businesses. As trees fell and power lines were snapped, many residents found themselves without electricity for hours, and in some cases, even days.

The high winds, which were part of a larger weather system moving through the area, left a trail of destruction in their wake. In addition to power outages, there were reports of storm damage to buildings, vehicles, and other structures. The force of the wind uprooted trees, some of which fell on homes and vehicles, causing significant property damage. While the storm did not result in any fatalities, the destruction was widespread, with many communities experiencing debris-filled streets and blocked roads.

Utility companies in the Miami Valley, including Dayton Power & Light, quickly mobilized crews, similar to FPL's storm response in major events, to begin restoring power to the affected areas. However, the high winds presented a challenge for repair crews, as downed power lines and damaged equipment made restoration efforts more difficult. Many customers were left waiting for hours or even days for their power to be restored, and some neighborhoods were still experiencing outages several days after the storm had passed.

In response to the severe weather, local authorities issued warnings to residents, urging them to stay indoors and avoid unnecessary travel. Wind gusts of up to 60 miles per hour were reported, making driving hazardous, particularly on bridges and overpasses, similar to Quebec windstorm outages elsewhere. The National Weather Service also warned of the potential for further storm activity, advising people to remain vigilant as the system moved eastward.

The impact of the storm was felt not only in terms of power outages but also in the strain it placed on emergency services. With trees blocking roads and debris scattered across the area, first responders were required to work quickly and efficiently to clear paths and assist those in need. Many residents were left without heat, refrigeration, and in some cases, access to medical equipment that relied on electricity.

Local schools and businesses were also affected by the storm. Many schools had to cancel classes, either due to power outages or because roads were impassable. Businesses, particularly those in the retail and service sectors, faced disruptions in their operations as they struggled to stay open without power amid extended outages that lingered, or to address damage caused by fallen trees and debris.

In the aftermath of the storm, Miami Valley residents are working to clean up and assess the damage. Many homeowners are left dealing with the aftermath of tree removal, property repairs, and other challenges. Meanwhile, local governments are focusing on restoring infrastructure, as seen after Toronto's spring storm outages in recent years, and ensuring that the power grid is secured to prevent further outages.

While the winds have died down and conditions have improved, the storm’s impact will be felt for weeks to come, reflecting Florida's weeks-long restorations after severe storms. The region will continue to recover from the damage, but the event serves as a reminder of the power of nature and the resilience of communities in the face of adversity. For residents affected by the power outages, recovery will require patience as utility crews and local authorities work tirelessly to restore normalcy.

Looking ahead, experts are urging residents to prepare for the next storm season by ensuring that they have emergency kits, backup generators, and contingency plans in place. As climate change contributes to more extreme weather events, it is likely that storms of this magnitude will become more frequent. By taking steps to prepare in advance, communities across the Miami Valley can better handle whatever challenges come next.

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Gulf Power renewable energy contract underscores a Florida PSC-approved power purchase from Bay County's municipal solid waste plant, delivering 13.65 MW at a fixed price, boosting fuel diversity, lowering landfill waste, and saving customers money.

Key Points

A fixed-price PPA for 13.65 MW from Bay County's waste-to-energy plant, approved by Florida PSC to cut costs.

✅ Fixed-price purchase; pay only for energy produced.

✅ 13.65 MW from Bay County waste-to-energy facility.

✅ Cuts landfill waste and natural gas dependency.

The Florida Public Service Commission (PSC) approved Tuesday a contract under which Gulf Power Company will purchase all the electricity generated by the Bay County Resource Recovery Facility, a municipal solid waste plant, similar to SaskPower-Manitoba Hydro deal structures seen elsewhere, over the next six years.

“Gulf’s renewable energy purchase promotes Florida’s fuel diversity, further reducing our dependency on natural gas,” PSC Chairperson Julie Brown said. “This renewable energy option also reduces landfill waste, saves customers money, and serves the public interest.”

The contract provides for Gulf to acquire the Panama City facility’s 13.65 megawatts of renewable generation for its customers beginning in July 2017. Gulf will pay a fixed price, aligned with approaches in Alberta's clean electricity RFP programs, and only pays for the energy produced. The contract is expected to save approximately $250,000 and provides security for customers, a contrast to overruns at the Kemper power plant project, because if the plant does not supply energy, Gulf does not have to provide payment.

This contract is the third renewable energy contract between Gulf and Bay County, at a time when the Southern California plant closures may be postponed, continuing agreements approved in 2008 and 2014. In making the decision, the PSC considered Gulf’s need for power and developments such as the Turkey Point license renewal process, as well as the contract’s cost-effectiveness, payment provisions, and performance guarantees, as required by rule.

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