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BC Hydro Rate Freeze delivers immediate relief on electricity rates in British Columbia, reversing a planned 3% hike, as BCUC oversight, a utility review, and Site C project debates shape provincial energy policy.

Key Points

A one-year provincial policy halting BC Hydro electricity rate hikes while a utility review finds cost savings.

✅ Freeze replaces planned 3% hike approved by BCUC.

✅ Government to conduct comprehensive BC Hydro review.

✅ Critics warn $150M revenue loss impacts capital projects.

British Columbia's NDP government has announced it will freeze BC Hydro rates effective immediately, fulfilling a key election promise.

Energy, Mines and Petroleum Resources Minister Michelle Mungall says hydro rates have gone up by more than 24 per cent in the last four years and by more than 70 per cent since 2001, reflecting proposals such as a 3.75% increase over two years announced previously.

"After years of escalating electricity costs, British Columbians deserve a break on their bills," Mungall said in a news release.

BC Hydro had been approved by the B.C. Utilities Commission to increase the rate by three per cent next year, but Mungall said it will pull back its request in order to comply with the freeze.

In the meantime, the government says it will undertake a comprehensive review of the utility meant to identify cost-savings measures for customers often asked to pay an extra $2 a month on electricity bills.

The Liberal critic, Tracy Redies, says the one year rate freeze is going to cost BC Hydro, calling it a distraction from the bigger issue of the future of the Site C project and the oversight of a BC Hydro fund surplus as well.

"A one year rate freeze costs Hydro $150 million," Redies said. "That means there's $150 million less to invest in capital projects and other investments that the utility needs to make."

"This is putting off decisions that should be made today to the future."

Recommendations from the review — including possible new rates — will be implemented starting in April 2019.

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Alberta Renewable Energy Procurement is surging as corporate PPAs drive wind and solar growth, with the Pembina Institute and the Business Renewables Centre linking buyers and developers in Alberta's energy-only market near Medicine Hat.

Key Points

A market-led approach where corporations use PPAs to secure wind and solar power from Alberta projects.

✅ Corporate PPAs de-risk projects and lock in clean power.

✅ Alberta's energy-only market enables efficient transactions.

✅ Skilled workforce supports wind, solar, legal, and financing.

Alberta has big potential when it comes to providing renewable energy, advocates say.

The Pembina Institute says the practice of corporations committing to buy renewable energy is just taking off in Canada, and Alberta has both the energy sector and the skilled workforce to provide it.

Earlier this week, a company owned by U.S. billionaire Warren Buffett announced a large new wind farm near Medicine Hat. It has a buyer for the power.

Sara Hastings-Simon, director of the Pembina's Business Renewables Centre, says this is part of a trend.

"We're talking about the practice of corporate institutions purchasing renewables to meet their own electricity demand. And this is a really well-established driver for renewable energy development in the U.S.," she said. "You may be hearing headlines like Google, Apple and others that are buying renewables and we're helping to bring this practice to Canada."

The Business Renewables Centre (BRC) is a not-for-profit working to accelerate corporate and institutional procurement of renewables in Canada. The group held its inaugural all members event in Calgary on Thursday.

Hastings-Simon says shareholders and investors are encouraging more use of solar and wind power in Canada.

"We have over 10 gigawatts of renewable energy projects in the pipeline that are ready for buyers. And so we see multinational companies coming to Canada to start to procure here, as well as Canadian companies understanding that this is an opportunity for them as well," Hastings-Simon said.

"It's really exciting to see business interests driving renewable energy development."

Sara Hastings-Simon is the director of the Pembina Institute's Business Renewables Centre, which seeks to build up Alberta's renewable energy industry. (Mike Symington/CBC)

Hastings-Simon says renewable procurement could help dispel the narrative that it's all about oil and gas in Alberta by highlighting Alberta as a powerhouse for both green energy and fossil fuels in Canada.

She says the practice started with a handful of tech companies in the U.S. and has become more mainstream there, even as Canada remains a solar laggard to some observers, with more and more large companies wanting to reduce their energy footprint.

He says his U.S.-based organization has been working for years to speed up and expand the renewables market for companies that want to address their own sustainability.

"We try and make that a little bit easier by building out a community that can help to really reinforce each other, share lessons learned, best practices and then drive for transactions to have actual material impact worldwide," he said.

"We're really excited to be working with the Pembina group and the BRC Canada team," he said. "We feel our best value for this is just to support them with our experiences and lessons. They've been basically doing the same thing for many years helping to grow and grow and cultivate the market."

Porter says Alberta's market is more than ready.

"There are some precedent transactions already so people know it can work," he said. "The way Alberta is structured, being an energy-only market is useful. And I think that there is a strong ecosystem of both budget developers and service providers … that can really help these transactions get over the line."

As procurement ramps up, Hastings-Simon says Alberta already has the skilled workers needed to fill renewable energy jobs across the province.

"We have a lot of the knowledge that's needed, and that's everybody from the construction down through the legal and financing — all those pieces of building big projects," she said. "We are seeing increasing interest in people that want to become involved in that industry, and so there is increasing demand for training in things like solar power installation and wind technicians."

Hastings-Simon predicts an increase in demand for both the services and the workers.

"As this industry ramps up, we're going to need to have more workers that are active in those areas," she said. "So I think we can see a very nice increase — both the demand and the number of folks that are able to work in this field."

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US-Canada Electricity Tariff Dispute intensifies as proposed tariffs spur Canadian threats to restrict hydroelectric exports, risking cross-border energy supply, grid reliability, higher electricity prices, and clean energy goals in the Northeast and Midwest.

Key Points

Trade clash over tariffs and hydroelectric exports that threatens power supply, prices, and grid reliability.

✅ Potential export curbs on Canadian hydro to US markets

✅ Risks: higher prices, strained grids, reduced clean energy

✅ Diplomacy urged to avoid retaliatory trade measures

In early February 2025, escalating trade tensions between the United States and Canada have raised concerns about the future of electricity exports from Canada to the U.S. The potential imposition of tariffs by the U.S. has prompted Canadian officials to consider retaliatory measures, including restricting electricity exports and pursuing high-level talks such as Ford's Washington meeting with federal counterparts.

Background of the Trade Dispute

In late November 2024, President-elect Donald Trump announced plans to impose a 25% tariff on all Canadian products, citing issues related to illegal immigration and drug trafficking. This proposal has been met with strong opposition from Canadian leaders, who view such tariffs as unjustified and detrimental to both economies, even as tariff threats boost support for Canadian energy projects among some stakeholders.

Canada's Response and Potential Retaliatory Measures

In response to the proposed tariffs, Canadian officials have discussed various countermeasures. Ontario Premier Doug Ford has threatened to cut electricity supplies to 1.5 million Americans and ban imports of U.S.-made beer and liquor. Other provinces, such as Quebec and Alberta, are also considering similar actions, though experts advise against cutting Quebec's energy exports due to reliability concerns.

Impact on U.S. Energy Supply

Canada is a significant supplier of electricity to the United States, particularly in regions like the Northeast and Midwest. A reduction or cessation of these exports could lead to energy shortages and increased electricity prices in affected U.S. states, with New York especially vulnerable according to regional assessments. For instance, Ontario exports substantial amounts of electricity to neighboring U.S. states, and any disruption could strain local energy grids.

Economic Implications

The imposition of tariffs and subsequent retaliatory measures could have far-reaching economic consequences. In Canada, industries such as agriculture, manufacturing, and energy could face significant challenges due to reduced access to the U.S. market, even as many Canadians support energy and mineral tariffs as leverage. Conversely, U.S. consumers might experience higher prices for goods and services that rely on Canadian imports, including energy products.

Environmental Considerations

Beyond economic factors, the trade dispute could impact environmental initiatives. Canada's hydroelectric power exports are a clean energy source that helps reduce carbon emissions in the U.S., where policymakers look to Canada for green power to meet targets. A reduction in these exports could lead to increased reliance on fossil fuels, potentially hindering environmental goals.

The escalating trade tensions between the United States and Canada, particularly concerning electricity exports, underscore the complex interdependence of the two nations. While the situation remains fluid, it highlights the need for diplomatic engagement to resolve disputes and maintain the stability of cross-border energy trade.

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Maritime Link HVDC Transmission connects Newfoundland and Nova Scotia to the North American grid, enabling renewable energy imports, subsea cable interconnection, Muskrat Falls hydro power delivery, and lower carbon emissions across Atlantic Canada.

Key Points

A 500 MW HVDC intertie linking Newfoundland and Nova Scotia to deliver Muskrat Falls hydro power.

✅ 500 MW capacity using twin 170 km subsea HVDC cables

✅ Interconnects Newfoundland and Nova Scotia to the North American grid

✅ Enables Muskrat Falls hydro imports, cutting CO2 and costs

For the first time, electricity has been sent between Newfoundland and Nova Scotia through the new Maritime Link.

The 500-megawatt transmission line — which connects Newfoundland to the North American energy grid for the first time and echoes projects like the New England Clean Power Link underway — was tested Friday.

"This changes not only the energy options for Newfoundland and Labrador but also for Nova Scotia and Atlantic Canada," said Rick Janega, the CEO of Emera Newfoundland and Labrador, which owns the link.

"It's an historic event in our eyes, one that transforms the electricity system in our region forever."

'On time and on budget'

It will eventually carry power from the Muskrat Falls hydro project in Labrador, where construction is running two years behind schedule and $4 billion over budget, a context in which the Manitoba Hydro line to Minnesota has also faced delay, to Nova Scotia consumers. It was supposed to start producing power later this year, but the new deadline is 2020 at the earliest.

The project includes two 170-kilometre subsea cables across the Cabot Strait between Cape Ray in southwestern Newfoundland and Point Aconi in Cape Breton.

The two cables, each the width of a two-litre pop bottle, can carry 250 megawatts of high voltage direct current, and rest on the ocean floor at depths up to 470 metres.

This reel of cable arrived in St. John's back in April aboard the Norwegian vessel Nexans Skagerrak, after the first power cable reached Nova Scotia earlier in the project. (Submitted by Emera NL)

The Maritime Link also includes almost 50 kilometres of overland transmission in Nova Scotia and more than 300 kilometres of overland transmission in Newfoundland, paralleling milestones on Site C transmission work in British Columbia.

The link won't go into commercial operation until January 1.

Janega said the $1.6-billion project is on time and on budget.

"We're very pleased to be in a position to be able to say that after seven years of working on this. It's quite an accomplishment," he said.

This Norwegian vessel was used to transport the 5,500 tonne subsea cable. (Submitted by Emera NL)

Once in service, the link will improve electrical interconnections between the Atlantic provinces, aligning with climate adaptation guidance for Canadian utilities.

"For Nova Scotia it will allow it to achieve its 40 per cent renewable energy target in 2020. For Newfoundland it will allow them to shut off the Holyrood generating station, in fact using the Maritime Link in advance of the balance of the project coming into service," Janega said.

Karen Hutt, president and CEO of Nova Scotia Power, which is owned by Emera Inc., calls it a great day for Nova Scotia.

"When it goes into operation in January, the Maritime Link will benefit Nova Scotia Power customers by creating a more stable and secure system, helping reduce carbon emissions, and enabling NSP to purchase power from new sources," Hutt said in a statement.

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Spain Electricity Prices surge to record highs as the wholesale market hits €339.84/MWh, driven by gas costs and CO2 permits, impacting PVPC regulated tariffs, free-market contracts, and household energy bills, OMIE data show.

Key Points

Rates in Spain's wholesale market that shape PVPC tariffs and free-market bills, moving with gas prices and CO2 costs.

✅ Record €339.84/MWh; peak 20:00-21:00; low 04:00-05:00 (OMIE).

✅ PVPC users and free-market contracts face higher bills.

✅ Drivers: high gas prices and rising CO2 emission rights.

Electricity in Spain's wholesale market will rise in price once more as European electricity prices continue to surge. Once again, it will set a historical record in Spain, reaching €339.84/MWh. With this figure, it is already the fifth time that the threshold of €300 has been exceeded.

This new high is a 6.32 per cent increase on today’s average price of €319.63/MWh, which is also a historic record, while Germany's power prices nearly doubled over the past year. Monday’s energy price will make it 682.65 per cent higher than the corresponding date in 2020, when the average was €43.42.

According to data published by the Iberian Energy Market Operator (OMIE), Monday’s maximum will be between the hours of 8pm and 9pm, reaching €375/MWh, a pattern echoed by markets where Electric Ireland price hikes reflect wholesale volatility. The cheapest will be from 4am to 5am, at €267.99.

The prices of the ‘pool’ have a direct effect on the regulated tariff  – PVPC – to which almost 11 million consumers in the country are connected, and serve as a reference for the other 17 million who have contracted their supply in the free market, where rolling back prices is proving difficult across Europe.

These spiraling prices in recent months, which have fueled EU energy inflation, are being blamed on high gas prices in the markets, and carbon dioxide (CO2) emission rights, both of which reached record highs this year.

According to an analysis by Facua-Consumidores en Acción, if the same rates were maintained for the rest of the month, the last invoice of the year would reach €134.45 for the average user. That would be 94.1 per cent above the €69.28 for December 2020, while U.S. residential electricity bills rose about 5% in 2022 after inflation adjustments.

The average user’s bill so far this year has increased by 15.1 per cent compared to 2018, as US electricity prices posted their largest jump in 41 years. Thus, compared to the €77.18 of three years ago, the average monthly bill now reaches €90.87 euros. However, the Government continues to insist that this year households will end up paying the same as in 2018.

As Ruben Sanchez, the general secretary of Facua commented, “The electricity bill for December would have to be negative for President Sanchez, and Minister Ribera, to fulfill their promise that this year consumers will pay the same as in 2018 once the CPI has been discounted”.

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Spain Wind Turbine Factory Shutdowns disrupt manufacturing as Vestas, Siemens Gamesa, and Nordex halt Spanish plants amid COVID-19 lockdowns, straining supply chains and renewables projects across Europe, with partial operations and maintenance continuing.

Key Points

COVID-19 lockdowns pause Spanish wind factories by Vestas, Siemens Gamesa, and Nordex, disrupting supply chains.

✅ Vestas, Siemens Gamesa, Nordex halt Spanish manufacturing

✅ Service and maintenance continue under safety protocols

✅ Supply chain and project timelines face delays in Europe

Europe’s largest wind turbine makers on Wednesday said they had shut down more factories in Spain, a major hub for the continent’s renewables sector, in response to an almost total lockdown in the country to contain the coronavirus outbreak as the Covid-19 crisis disrupts the sector.

Denmark’s Vestas, the world No.1, has suspended production at its two Spanish plants, a spokesman told Reuters, adding that its service and maintenance business was still working. Vestas has also paused manufacturing and construction in India, which is under a nationwide lockdown too, he said, and similar disruptions could stall U.S. utility solar projects this year.

Top rival Siemens Gamesa, known for its offshore wind turbine lineup, suspended production at six Spanish factories on Monday, bringing total closures there to eight, a spokeswoman said.

Four components factories are still partially up and running, at Reinosa on the north coast, Cuenca near Madrid, Mungia and Siguiero, she added.

Germany’s Nordex, the No.8 globally which is 36% owned by Spain’s Acciona, has now shuttered all of its production in Spain, even as new projects like Enel’s 90MW build move ahead, including two nacelle casing factories in Barasoain and Vall d’Uixo, as well as a rotor blade site in Lumbier.

“Production is no longer active,” a spokeswoman said in response to a Reuters query.

The new closures take the number of idled wind power factories on the continent to 19, all in Spain and Italy, the European countries worst hit by the pandemic, with investments at risk across the sector.

Spain is second only to Italy in terms of numbers of coronavirus-related fatalities and restrictions have become even stricter in the country’s third week of lockdown at a time when renewables surpassed fossil fuels for the first time in Europe.

“Some factories have temporarily paused activity as a precautionary step to strengthen sanitary measures within the sites and guarantee full compliance with government recommendations,” industry association WindEurope said, noting that wind power grows in some markets despite the pandemic.

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