Privatize Atomic Energy of Canada Ltd.

By Jan Carr, Financial Post


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Canada is known on the world stage for our energy resources and prowess. It is therefore no surprise that energy is central to plans for economic growth in several provinces.

Alberta of course, with its massive coal, oil and gas reserves and its status as a global centre of the energy business, is obvious. So too perhaps is Newfoundland and Labrador, not just for its off-shore oil but for the renewable energy bonanza of undeveloped hydroelectric and wind resources in Labrador.

Less obvious is SaskatchewanÂ’s initiative to leverage the 8% of the worldÂ’s uranium supplies it has through the value-added development of a nuclear industry. And similarly, New Brunswick intends to make use of its strategic location and expanding portfolio of electricity and gas infrastructure to become an energy hub for northeastern North America.

But governments have not yet recognized CanadaÂ’s unique capabilities in nuclear power technology as a platform for investment in future prosperity. To suggest that nuclear power could be a vector for sustainable economic development may surprise many. Nuclear energy has an aura of being both environmentally harmful and expensive, but the facts indicate otherwise.

Over the 60 years of its existence Atomic Energy of Canada Limited (AECL) has become one of the worldÂ’s leaders in nuclear power technology with its unique CANDU reactor design. Today half of OntarioÂ’s electricity is generated at Canadian designed, manufactured and operated CANDU nuclear stations. Including those in three Canadian provinces, there are some four-dozen AECL CANDU reactors in operation around the world.

Nuclear energy is featuring heavily in national energy plans throughout the world because it is the only commercially available source of energy on the scale presently provided by coal, oil and gas that does not contribute to climate change through carbon dioxide emissions. The World Nuclear Association reports that 20 new reactors are presently under construction in 11 countries and will join the more than 400 already in service in some 40 countries in providing almost one-fifth of the worldÂ’s electricity supply by 2020. The world needs CanadaÂ’s CANDU technology for at least some of these reactors, and hereÂ’s why.

Unlike all other nuclear technologies, CANDU can use unenriched or natural uranium. This frees owners of CANDU reactors from being tied by long-term contracts to highly specialized and security-sensitive suppliers of enriched fuel. And since it is the enrichment process rather than the nuclear reactor itself that entails the skills and equipment necessary for manufacturing nuclear weapons, CANDU does not add to proliferation concerns in the same way as other technologies.

As well, CANDU reactors can be adapted to burn the spent fuel from enriched fuel reactors. This not only reduces the volume of spent fuel under long-term management in storage sites but it reduces the remnant radioactivity level in the spent fuel. In reducing the volume and potency of waste, CANDU is the Blue Box of the nuclear industry.

The same features that allow CANDU technology to use natural and spent uranium also make it simpler than other nuclear technologies to adapt to using thorium as a fuel. Thorium is not only three to four times more plentiful than uranium but it is also more evenly distributed. Whereas half the worldÂ’s supply of uranium is located in just three countries, three quarters of thorium reserves are evenly spread among six countries. Energy security resulting from plentiful and widespread resources can only reduce geopolitical tension.

The promise of CANDU as a platform for thorium-based energy is no doubt one of the reasons the Chinese government recently signed a development agreement with AECL and why the Indian Prime Minister recently met with AECL and Canadian government officials. Thorium promises countries like China and India energy independence.

India in particular has 12% of the worldÂ’s known thorium and relies heavily on imported energy. Both countries have future energy requirements that could dwarf current consumption by the Western industrialized world and, absent advances such as thorium-burning CANDU reactors, will be based on fossil fuels which contribute to climate change.

So if AECLÂ’s unique Canadian nuclear technology has so many positive attributes, why doesnÂ’t it feature in any governmentÂ’s prosperity plans? In Canada, it seems that this is primarily because AECL is owned by the federal government and energy policy is a provincial responsibility. The traditional ebb and flow of federal-provincial politics and tensions mixed with the less-than-popular image of the nuclear industry and its consequent lack of appeal to voters means that the obvious economic opportunity gets passed over.

Internationally, AECL is hobbled as a publicly owned entity without access to commercially motivated capital and organizational flexibility that its competitors based in France and Japan have. We would all benefit from a well executed privatization focused on relieving taxpayers of AECLÂ’s business risks while freeing up the company to pursue global commercial opportunities. In so doing, economic prosperity would be enhanced by building the ranks of the 30,000 men and women presently working in the 150 companies that constitute CanadaÂ’s nuclear industry.

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Report call for major changes to operation of Nova Scotia's power grid

Nova Scotia Energy Modernization Act proposes an independent system operator, focused energy regulation, coal phase-out by 2030, renewable integration, transmission upgrades, and competitive market access to boost consumer trust and grid reliability across the province.

 

Key Points

Legislation to create an independent system operator and energy regulator, enabling coal phase-out and renewable integration.

✅ Transfers grid control from Nova Scotia Power to an ISO

✅ Establishes a focused energy regulator for multi-sector oversight

✅ Accelerates coal retirement, renewables build-out, and grid upgrades

 

Nova Scotia is poised for a significant overhaul in how its electricity grid operates, with the electricity market headed for a reshuffle as the province vows changes, following a government announcement that will strip the current electric utility of its grid access control. This move is part of a broader initiative to help the province achieve its ambitious energy objectives, including the cessation of coal usage by 2030.

The announcement came from Tory Rushton, the Minister of Natural Resources, who highlighted the recommendations from the Clean Electricity Task Force's report to make the electricity system more accountable to Nova Scotians according to the authors. The report suggests the creation of two distinct entities: an autonomous system operator for energy system planning and an independent body for energy regulation.

Minister Rushton expressed the government's agreement with these recommendations, while the premier had earlier urged regulators to reject a 14% rate hike to protect customers, stating plans to introduce a new Energy Modernization Act in the next legislative session.

Under the proposed changes, Nova Scotia Power, a privately-owned entity, will retain its operational role but will relinquish control over the electricity grid. This responsibility will shift to an independent system operator, aiming to foster competitive practices essential for phasing out coal—currently a major source of the province’s electricity.

Additionally, the existing Utility and Review Board, which recently approved a 14% rate increase despite political opposition, will undergo rebranding to become the Nova Scotia Regulatory and Appeals Board, reflecting a broader mandate beyond energy. Its electricity-related duties will be transferred to the newly proposed Nova Scotia Energy Board, which will oversee various energy sectors including electricity, natural gas, and retail gasoline.

The task force, led by Alison Scott, a former deputy energy minister, and John MacIsaac, an ex-executive of Nalcor Energy, was established by the province in April 2023 to determine the needs of the electrical system in meeting Nova Scotia's environmental goals.

Minister Rushton praised the report for providing a clear direction towards achieving the province's 2030 environmental targets and beyond. He estimated that establishing the recommended bodies would take 18 months to two years, and noted the government cannot order the utility to cut rates under current law, promising job security for current employees of Nova Scotia Power and the Utility and Review Board throughout the transition.

The report advocates for the new system operator to improve consumer trust by distancing electricity system decisions from Nova Scotia Power's corporate interests. It also critiques the current breadth of the Utility and Review Board's mandate as overly extensive for addressing the energy transition's long-term requirements.

Nova Scotia Power's president, Peter Gregg, welcomed the recommendations, emphasizing their role in the province's shift towards renewable energy, as neighboring jurisdictions like P.E.I. explore community generation to build resilience, he highlighted the importance of a focused energy regulator and a dedicated system operator in advancing essential projects for reliable customer service.

The task force's 12 recommendations also include the requirement for Nova Scotia Power to submit an annual asset management plan for regulatory approval and to produce reports on vegetation and wood pole management. It suggests the government assess Ontario's hydro policies for potential adaptation in Nova Scotia and calls for upgrades to the transmission grid infrastructure, with projected costs detailed by Stantec.

Alison Scott remarked on the comparative expense of coal power against renewable sources like wind, suggesting that investments in the grid to support renewables would be economically beneficial in the long run.

 

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$1.6 Billion Battery Plant Charges Niagara Region for Electric Vehicle Future

Ontario EV Battery Separator Plant anchors Canada's EV supply chain, with Asahi Kasei producing lithium-ion battery separators in Niagara Region to support Honda's Alliston assembly, clean transportation growth, and sustainable manufacturing jobs.

 

Key Points

Asahi Kasei's Niagara Region plant makes lithium-ion battery separators supplying Honda's EV factory in Ontario.

✅ Starts up by 2027 to align with Honda EV output timeline.

✅ Backed by clean tech tax credits and public investment.

✅ Boosts local jobs, R&D, and clean transportation leadership.

 

The automotive industry is undergoing a seismic shift, and Canada is firmly planting its flag in the electric vehicle (EV) revolution, propelled by recent EV assembly deals across the country. A new $1.6 billion battery component plant in Ontario's Niagara Region signifies a significant step towards a cleaner, more sustainable transportation future. This Asahi Kasei facility, a key player in Honda's $15 billion electric vehicle supply chain investment, promises to create jobs, boost the local economy, and solidify Ontario's position as a leader in clean transportation technology.

Honda's ambitious project forms part of Honda's Ontario EV investment that involves constructing a dedicated battery plant adjacent to their existing Alliston, Ontario assembly facility. This new plant will focus on producing fully electric vehicles, requiring a robust supply chain for critical components. Asahi Kasei's Niagara Region plant enters the picture here, specializing in the production of battery separators – a thin film crucial for separating the positive and negative electrodes within a lithium-ion battery. These separators play a vital role in ensuring the battery functions safely and efficiently.

The Niagara Region plant is expected to be operational by 2 027, perfectly aligning with Honda's EV production timeline. This strategic partnership benefits both companies: Honda secures a reliable source for a vital component, while Asahi Kasei capitalizes on the burgeoning demand for EV parts. The project is a catalyst for economic growth in Ontario, creating jobs in construction and manufacturing, supporting an EV jobs boom province-wide, and potentially future research and development sectors. Additionally, it positions the province as a hub for clean transportation technology, attracting further investment and fostering innovation.

This announcement isn't an isolated event. News of Volkswagen constructing a separate EV battery plant in St. Thomas, Ontario, and the continuation of a major EV battery project near Montreal further underscore Canada's commitment to electric vehicles. These developments signify a clear shift in the country's automotive landscape, with a focus on sustainable solutions.

Government support has undoubtedly played a crucial role in attracting these investments. The Honda deal involves up to $5 billion in public funds. Asahi Kasei's Niagara Region plant is also expected to benefit from federal and provincial clean technology tax credits. This demonstrates a collaborative effort between government and industry, including investments by Canada and Quebec in battery assembly, to foster a thriving EV ecosystem in Canada.

The economic and environmental benefits of this project are undeniable. Battery production is expected to create thousands of jobs, while the shift towards electric vehicles will lead to reduced emissions and a cleaner environment. Ontario stands to gain significantly from this transition, becoming a leader in clean energy technology and attracting skilled workers and businesses catering to the EV sector, especially as the U.S. auto pivot to EVs accelerates across the border.

However, challenges remain. Concerns about the environmental impact of battery production, particularly the sourcing of raw materials and the potential for hazardous waste, need to be addressed. Additionally, ensuring a skilled workforce capable of handling the complexities of EV technology is paramount.

Despite these challenges, the future of electric vehicles in Canada appears bright. Major automakers are making significant investments, government support is growing, and consumer interest in EVs is on the rise. The Niagara Region plant serves as a tangible symbol of Canada's commitment to a cleaner and more sustainable transportation future. With careful planning and continued Canada-U.S. collaboration across the sector, this project has the potential to revolutionize the Canadian automotive industry and pave the way for a greener tomorrow.

 

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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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Canada's Electricity Exports at Risk Amid Growing U.S.-Canada Trade Tensions

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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Analysis: Why is Ontario’s electricity about to get dirtier?

Ontario electricity emissions forecast highlights rising grid CO2 as nuclear refurbishments and the Pickering closure drive more natural gas, limited renewables, and delayed Quebec hydro imports, pending advances in storage and transmission upgrades.

 

Key Points

A projection that Ontario's grid CO2 will rise as nuclear units refurbish or retire, increasing natural gas use.

✅ Nuclear refurbs and Pickering shutdown cut zero-carbon baseload

✅ Gas plants fill capacity gaps, boosting GHG emissions

✅ Quebec hydro imports face cost, transmission, and timing limits

 

Ontario's energy grid is among the cleanest in North America — but the province’s nuclear plans mean that some of our progress will be reversed over the next decade.

What was once Canada’s largest single source of greenhouse-gas emissions is now a solar-power plant. The Nanticoke Generating Station, a coal-fired power plant in Haldimand County, was decommissioned in stages from 2010 to 2013 — and even before the last remaining structures were demolished earlier this year, Ontario Power Generation had replaced its nearly 4,000 megawatts with a 44-megawatt solar project in partnership with the Six Nations of the Grand River Development Corporation and the Mississaugas of the Credit First Nation.

But neither wind nor solar has done much to replace coal in Ontario’s hydro sector, a sign of how slowly Ontario is embracing clean power in practice across the province. At Nanticoke, the solar panels make up less than 2 per cent of the capacity that once flowed out to southern Ontario over high-voltage transmission lines. In cleaning up its electricity system, the province relied primarily on nuclear power — but the need to extend the nuclear system’s lifespan will end up making our electricity dirtier again.

“We’ve made some pretty great strides since 2005 with the fuel mix,” says Terry Young, vice-president of corporate communications at the Independent Electricity System Operator, the provincial agency whose job it is to balance supply and demand in Ontario’s electricity sector. “There have been big changes since 2005, but, yes, we will see an increase because of the closure of Pickering and the refurbs coming.”

“The refurbs” is industry-speak for the major rebuilds of both the Darlington and Bruce nuclear-power stations. The two are both in the early stages of major overhauls intended to extend their operating lives into the 2060s: in the coming years, they’ll be taken offline and rebuilt. (The Pickering nuclear plant will not be refurbished and will shut down in 2024.)

The catch is that, as the province loses its nuclear capacity in increments, Ontario will be short of electricity in the coming years and the IESO will need to find capacity elsewhere to make sure the lights stay on. And that could mean burning a lot more natural gas — and creating more greenhouse-gas emissions.

According to the IESO’s planning assumptions, electricity will be responsible for 11 megatonnes of greenhouse-gas emissions annually by 2035 (last year, it was three megatonnes). That’s the “reference case” scenario: if conservation and efficiency policies shave off some electricity demand, we could get it down to something like nine megatonnes. But if demand is higher than expected, it could be as high as 13 megatonnes — more than quadruple Ontario’s 2018 emissions.

Even in the worst-case scenario, the province’s emissions from electricity would still be less than half of what they were in 2005, before the province began phasing out its coal generation. But it’s still a reversal of a trend that both Liberals and Progressive Conservatives have boasted about — the Liberals to justify their energy policies, the PCs to justify their hostility to a federal carbon tax.

Young emphasized that technology can change and that the IESO’s planning assumptions are just that: projections based on the information available today. A revolution in electricity storage could make it possible to store the province’s cleaner power sources overnight for use during the day, but that’s still only in the realm of speculation — and the natural-gas infrastructure exists in the real world, today.

Ontario Power Generation — the Crown corporation that operates many of the province’s power plants, including Pickering and Darlington — recently bought four gas plants, two of them outright (two it already owned in part). All were nearly complete or already operational, so the purchase itself won’t change the province’s emissions prospects. Rather, OPG is simply looking to maintain its share of the electricity market after the Pickering shutdown.

“It will allow us to maintain our scale, with the upcoming end of Pickering’s commercial operations, so that we can continue our role as the driver of Ontario’s lower carbon future,” Neal Kelly, OPG’s director of media, issues, and management, told TVO.org via email. “Further, there is a growing need for flexible gas fired generation to support intermittent wind and solar generation.”

The shift to more gas-fired generation has been coming for a while, and critics say that Ontario has missed an opportunity to replace the lost Pickering capacity with something cleaner. MPP Mike Schreiner, leader of the Green party, has argued for years that Ontario should have pursued an agreement with Quebec to import clean hydroelectricity.

“To me, it’s a cost-effective solution, and it’s a zero-emissions solution,” Schreiner says. “Regardless of your position on sources of electricity, I think everyone could agree that waterpower from Quebec is going to be less expensive.”

Quebec is eager to sell Ontario its surplus hydro power, but not everyone agrees that importing power would be cheaper. A study published by the Ontario Chamber of Commerce (and commissioned by Ontario Power Generation) calls the claim a “myth” and states that upgrading electric-transmission wires between Ontario and Quebec would cost $1.2 billion and take 10 years, while some estimates suggest fully greening Ontario's grid would cost far more overall.

With Quebec imports seemingly a non-starter and major changes to Ontario’s nuclear fleet already underway, there’s only one path left for this province’s greenhouse-gas emissions: upwards.

 

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Alberta set to retire coal power by 2023, ahead of 2030 provincial deadline

Alberta coal phaseout accelerates as utilities convert to natural gas, cutting emissions under TIER regulations and deploying hydrogen-ready, carbon capture capable plants, alongside new solar projects in a competitive, deregulated electricity market.

 

Key Points

A provincewide shift from coal to natural gas and renewables, cutting power emissions years ahead of the 2030 target.

✅ Capital Power, TransAlta converting coal units to gas

✅ TIER pricing drives efficiency, carbon capture readiness

✅ Hydrogen-ready turbines, solar projects boost renewables

 

Alberta is set to meet its goal to eliminate coal-fired electricity production years earlier than its 2030 target, amid a broader shift to cleaner energy in the province, thanks to recently announced utility conversion projects.

Capital Power Corp.’s plan to spend nearly $1 billion to switch two coal-fired power units west of Edmonton to natural gas, and stop using coal entirely by 2023, was welcomed by both the province and the Pembina Institute environmental think-tank.

In 2014, 55 per cent of Alberta’s electricity was produced from 18 coal-fired generators. The Alberta government announced in 2015 it would eliminate emissions from coal-fired electricity generation by 2030.

Dale Nally, associate minister of Natural Gas and Electricity, said Friday that decisions by Capital Power and other utilities to abandon coal will be good for the environment and demonstrates investor confidence in Alberta’s deregulated electricity market, where the power price cap has come under scrutiny.

He credited the government’s Technology Innovation and Emissions Reduction (TIER) regulations, which put a price on industrial greenhouse gas emissions, as a key factor in motivating the conversions.

“Capital Power’s transition to gas is a great example of how private industry is responding effectively to TIER, as it transitions these facilities to become carbon capture and hydrogen ready, which will drive future emissions reductions,” Nally said in an email.

Capital Power said direct carbon dioxide emissions at its Genesee power facility near Edmonton will be about 3.4 million tonnes per year lower than 2019 emission levels when the project is complete.

It says the natural gas combined cycle units it’s installing will be the most efficient in Canada, adding they will be capable of running on 30 per cent hydrogen initially, with the option to run on 95 per cent hydrogen in future with minor investments.

In November, Calgary-based TransAlta Corp. said it will end operations at its Highvale thermal coal mine west of Edmonton by the end of 2021 as it switches to natural gas at all of its operated coal-fired plants in Canada four years earlier than previously planned.

The Highvale surface coal mine is the largest in Canada, and has been in operation on the south shore of Wabamun Lake in Parkland County since 1970.

The moves by the two utilities and rival Atco Ltd., which announced three years ago it would convert to gas at all of its plants by this year, mean significant emissions reduction and better health for Albertans, said Binnu Jeyakumar, director of clean energy for Pembina.

“Alberta’s early coal phaseout is also a great lesson in good policy-making done in collaboration with industry and civil society,” she said.

“As we continue with this transformation of our electricity sector, it is paramount that efforts to support impacted workers and communities are undertaken.”

She added the growing cost-competitiveness of renewable energy, such as wind power, makes coal plant retirements possible, applauding Capital Power’s plans to increase its investments in solar power.

In Ontario, clean power policy remains a focus as the province evaluates its energy mix.

The company announced it would go ahead with its 75-megawatt Enchant Solar power project in southern Alberta, investing between $90 million and $100 million, and that it has signed a 25-year power purchase agreement with a Canadian company for its 40.5-MW Strathmore Solar project now under construction east of Calgary.
 

 

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