Homer Electric gets feasibility study permits

Ukraine-ENTSO-E Grid Synchronization links Ukraine and Moldova to the European grid via secure interconnection, matching frequency for stability, resilience, and energy security, enabling cross-border support, islanding recovery, and coordinated load balancing during wartime disruptions.

Key Points

Rapid alignment of Ukraine and Moldova into the European grid to enable secure interconnection and system stability.

✅ Matches 50 Hz frequency across interconnected systems

✅ Enables cross-border support and electricity trading

✅ Improves resilience, stability, and energy security

On February 24 Ukraine’s electric grid operator disconnected the country’s power system from the larger Russian-operated network to which it had always been linked. The long-planned disconnection was meant to be a 72-hour trial proving that Ukraine could operate on its own and to protect electricity supply before winter as contingencies were tested. The test was a requirement for eventually linking with the European grid, which Ukraine had been working toward since 2017. But four hours after the exercise started, Russia invaded.

Ukraine’s connection to Europe—which was not supposed to occur until 2023—became urgent, and engineers aimed to safely achieve it in just a matter of weeks. On March 16 they reached the key milestone of synchronizing the two systems. It was “a year’s work in two weeks,” according to a statement by Kadri Simson, the European Union commissioner for energy. That is unusual in this field. “For [power grid operators] to move this quickly and with such agility is unprecedented,” says Paul Deane, an energy policy researcher at the University College Cork in Ireland. “No power system has ever synchronized this quickly before.”

Ukraine initiated the process of joining Europe’s grid in 2005 and began working toward that goal in earnest in 2017, as did Moldova. It was part of an ongoing effort to align with Europe, as seen in the Baltic states’ disconnection from the Russian grid, and decrease reliance on Russia, which had repeatedly threatened Ukraine’s sovereignty. “Ukraine simply wanted to decouple from Russian dominance in every sense of the word, and the grid is part of that,” says Suriya Jayanti, an Eastern European policy expert and former U.S. diplomat who served as energy chief at the U.S. embassy in Kyiv from 2018 to 2020.

After the late February trial period, Ukrenergo, the Ukrainian grid operator, had intended to temporarily rejoin the system that powers Russia and Belarus. But the Russian invasion made that untenable. “That left Ukraine in isolation mode, which would be incredibly dangerous from a power supply perspective,” Jayanti says. “It means that there’s nowhere for Ukraine to import electricity from. It’s an orphan.” That was a particularly precarious situation given Russian attacks on key energy infrastructure such as the Zaporizhzhia nuclear power plant and ongoing strikes on Ukraine’s power grid that posed continuing risks. (According to Jayanti, Ukraine’s grid was ultimately able to run alone for as long as it did because power demand dropped by about a third as Ukrainians fled the country.)

Three days after the invasion, Ukrenergo sent a letter to the European Network of Transmission System Operators for Electricity (ENTSO-E) requesting authorization to connect to the European grid early. Moldelectrica, the Moldovan operator, made the same request the following day. While European operators wanted to support Ukraine, they had to protect their own grids, amid renewed focus on protecting the U.S. power grid from Russian hacking, so the emergency connection process had to be done carefully. “Utilities and system operators are notoriously risk-averse because the job is to keep the lights on, to keep everyone safe,” says Laura Mehigan, an energy researcher at University College Cork.

An electric grid is a network of power-generating sources and transmission infrastructure that produces electricity and carries it from places such as power plants, wind farms and solar arrays to houses, hospitals and public transit systems. “You can’t just experiment with a power system and hope that it works,” Deane says. Getting power where it is it needed when it is needed is an intricate process, and there is little room for error, as incidents involving Russian hackers targeting U.S. utilities have highlighted for operators worldwide.

Crucial to this mission is grid interconnection. Linked systems can share electricity across vast areas, often using HVDC technology, so that a surplus of energy generated in one location can meet demand in another. “More interconnection means we can move power around more quickly, more efficiently, more cost effectively and take advantage of low-carbon or zero-carbon power sources,” says James Glynn, a senior research scholar at the Center on Global Energy Policy at Columbia University. But connecting these massive networks with many moving parts is no small order.

One of the primary challenges of interconnecting grids is synchronizing them, which is what Ukrenergo, Moldelectrica and ENTSO-E accomplished last week. Synchronization is essential for sharing electricity. The task involves aligning the frequencies of every energy-generation facility in the connecting systems. Frequency is like the heartbeat of the electric grid. Across Europe, energy-generating turbines spin 50 times per second in near-perfect unison, and when disputes disrupt that balance, slow clocks across Europe can result, reminding operators of the stakes. For Ukraine and Moldova to join in, their systems had to be adjusted to match that rhythm. “We can’t stop the power system for an hour and then try to synchronize,” Deane says. “This has to be done while the system is operating.” It is like jumping onto a moving train or a spinning ride at the playground: the train or ride is not stopping, so you had better time the jump perfectly.

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Ontario Pumped Storage advances as Ontario's largest energy storage project, delivering clean electricity, long-duration capacity, and grid reliability for peak demand, led by TC Energy and Saugeen Ojibway Nation, with IESO review underway.

Key Points

A long-duration storage project in Meaford storing clean power for peak demand, supporting Ontario's emission-free grid.

✅ Stores clean electricity to power 1M homes for 11 hours

✅ Partnership: TC Energy and Saugeen Ojibway Nation

✅ Pending IESO review and OEB regulation decisions

In a bid to accelerate the province's ambitions for clean economic growth, TC Energy Corporation has announced significant progress in the development of the Ontario Pumped Storage Project. The Government of Ontario in Canada has unveiled a plan to address growing energy needs as a sustainable road map aimed at achieving an emission-free electricity sector, and as part of this plan, the Ministry of Energy is set to undertake a final evaluation of the proposed Ontario Pumped Storage Project. A decision is expected to be reached by the end of the year.

Ontario Pumped Storage is a collaborative effort between TC Energy and the Saugeen Ojibway Nation. The project is designed to be Ontario's largest energy storage initiative, capable of storing clean electricity to power one million homes for 11 hours. As the province strives to transition to a cleaner electricity grid by embracing clean power across sectors, long duration storage solutions like Ontario Pumped Storage will play a pivotal role in providing reliable, emission-free power during peak demand periods.

The success of the Project hinges on the approval of TC Energy's board of directors and a fruitful partnership agreement with the Saugeen Ojibway Nation. TC Energy is aiming for a final investment decision in 2024, as Ontario confronts an electricity shortfall in the coming years, with the anticipated in-service date being in the early 2030s, pending regulatory and corporate approvals.

“Ontario Pumped Storage will be a critical component of Ontario’s growing clean economy and will deliver significant benefits and savings to consumers,” said Corey Hessen, Executive Vice-President and President, TC Energy, Power and Energy Solutions. “Ontario continues to attract major investments that will have large power needs — many of which are seeking zero-emission energy before they invest. We are pleased the government is advancing efforts to recognize the significant role that long duration storage plays — firming resources, including new gas plants under provincial consideration, will become increasingly valuable in supporting a future emission-free electricity system.” 

The Municipality of Meaford also expressed its support for the project, recognizing the positive impact it could have on the local economy and the overall electricity system of Ontario. Additionally, various stakeholders, including LiUNA OPDC, LiUNA Local 183, and the Ontario Chamber of Commerce, lauded the potential for job creation, training opportunities, and resilient energy infrastructure as Ontario seeks new wind and solar power to ease a coming electricity supply crunch.

The timeline for Ontario Pumped Storage's progress includes a final analysis by the Independent Electricity System Operator (IESO) to confirm its role in Ontario's electricity system and in balancing demand and emissions during the transition, to be completed by 30 September 2023. Concurrently, the Ministry of Energy will engage in consultations on the potential regulation of the Project via the Ontario Energy Board, while debates over clean, affordable electricity intensify ahead of the Ontario election, with a final determination scheduled for 30 November 2023.

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Canada Clean Electricity Expansion is urged by the IEA to meet net-zero targets, scaling non-emitting generation, electrification, EV demand, and grid integration across provinces to decarbonize industry, buildings, and transport while ensuring reliability and affordability.

Key Points

An IEA-backed pathway for Canada to scale non-emitting power, electrification, and grid links to meet net-zero goals.

✅ Double or triple clean generation to replace fossil fuels

✅ Integrate provincial grids to decarbonize dependent regions

✅ Manage EV and heating loads with reliability and affordability

Canada will need more electricity capacity if it wants to hit its climate targets, and cleaning up Canada's electricity will be critical, according to a new report from the International Energy Agency (IEA).

The report offers mainly a rosy picture of Canada's overall federal energy policy. But, the IEA draws attention to Canada's increasing future electricity demands, and ultimately, calls on Canada to leverage its non-emitting energy potential and expand renewable energy to hit its climate targets.  

"Canada's wealth of clean electricity and its innovative spirit can help drive a secure and affordable transformation of its energy system and help realize its ambitious goals," stated Fatih Birol, the IEA executive director, in a news release.

The IEA notes that Canada has one of the cleanest energy grids globally, with 83 per cent of electricity coming from non-emitting sources in 2020. But this reflects nationwide progress in electricity to date; the report warns this is not a reason for Canada to rest on its laurels. More electricity will be needed to displace fossil fuels if Canada wants to hit its 2030 targets, the report states, and "even deeper cuts" will be required to reach net-zero by 2050.

"Perhaps more significantly, however, Canada will need to ensure sufficient new clean generation capacity to meet the sizeable levels of electrification that its net-zero targets imply."

Investing in new coal, oil and gas projects must stop to hit climate goals, global energy agency says
The Liberals have promised to create a 100 percent net-zero-emitting electricity system by 2035, with regulating oil and gas emissions and electric car sales as part of the plan; by then, every new light-duty vehicle sold in Canada will be a zero-emission vehicle. The switch from gas guzzlers to plug-in electric vehicles will create new pressures on Canada's electrical grid, as will any turn away from fossil natural gas for home heating.

To meet these challenges, the IEA warns, Canada would need to double or triple the power generated from non-emitting sources compared to today, a shift whose cost could reach $1.4 trillion according to the Canadian Gas Association. 

"Such a shift will require significant regulatory action," the report states, highlighting the need for climate policy for electricity grids to guide implementation, and that will require the federal government to work closely with provinces and territories that control power generation and distribution.

The report notes that the further integration of territorial and provincial electrical grids could allow fossil fuel-dependent provinces, like Alberta, to decarbonize and electrify their economies.

The report, entitled Canada 2022 Energy Policy Review, offers what it calls an "in-depth" look at the commitments Canada has made to transform its energy policy. Since the IEA conducted its last review in 2015, Canada has committed to cutting greenhouse gas emissions by 40 to 45 per cent from 2005 levels by 2030 and achieving net-zero by 2050 under an extended national target.

The IEA is well-known for the production of its annual World Energy Outlook. The Paris-based autonomous intergovernmental organization provides analysis, data, and policy recommendations to promote global energy security and sustainability. Canada is a part of the intergovernmental body, which also conducts peer reviews of its members' energy policy.

Oil and gas emissions rising
Natural Resources Minister Jonathan Wilkinson responded to the report in the IEA news release.

"This report acknowledges Canada's ambitious efforts and historic investments to develop pathways to achieve net-zero emissions by 2050 and ensure a transition that aligns with our shared objective of limiting global warming to 1.5 degrees Celsius," Wilkinson's statement read.

The report notes that — despite that objective — absolute emissions from Canadian oil and gas extraction went up 26 per cent between 2000 and 2019, largely from increased production.

Minister of Natural Resources Jonathan Wilkinson responds to a question at a news conference after the federal cabinet was sworn in, in Ottawa, on Oct. 26, 2021. (Justin Tang/The Canadian Press)
"Canada will need to reconcile future growth in oil sands production with increasingly strict greenhouse gas requirements," the report states.

On the plus side, the IEA found emissions per barrel of oilsands crude have decreased by 20 per cent in the last decade from technical and operational improvements.

The improving carbon efficiency of the oilsands is a "trend that is expected to continue at even higher rates," said Ben Brunnen, vice-president of oilsands, fiscal and economic policy at the Canadian Association of Petroleum Producers.

That may become important, the IEA report notes, as energy investors and buyers look for low-carbon assets and more countries adopt net-zero policies.

Further innovation, such as carbon capture and storage, could help to turn things around for Canada's oil patch, the report says. The Liberals have also said they will place a hard cap on oil and gas emissions from production, but that does not include the burning of the fossil fuels. 

In 2021, the IEA released a report that determined to achieve net-zero by 2050, among many steps, investments needed to end in coal mines, oil and gas wells. Thursday's report, however, made no mention of that, which disappointed at least one environmental group.

"A glaring omission was that this assessment says nothing about production. We know that the most important thing we can do is to stop using and producing oil and gas," said Julia Levin, a senior climate and energy program manager at Environmental Defence.

"And yet that was absent from this report, and that really is a glaring omission, which is completely out of line with their [the IEA's] own work."

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Ukraine Electricity Outages may pause as the grid stabilizes, with energy infrastructure repairs, generators, and reserves supporting supply; officials cite no rationing absent new Russian strikes, while Odesa networks recover and Ukrenergo completes restoration works.

Key Points

Planned power cuts in Ukraine paused as grid capacity, repairs, and reserves improve, barring new strikes.

✅ No rationing if Russia halts strikes on energy infrastructure

✅ Grid repairs and reserves meet demand for third straight week

✅ Odesa networks restored; Ukrenergo crews redeploy to repairs

Ukraine plans no more outages to ration electricity if there are no new strikes and has been able to amass some power reserves, the energy minister said on Saturday, as it continues to keep the lights on despite months of interruptions caused by Russian bombings.

"Electricity restrictions will not be introduced, provided there are no Russian strikes on infrastructure facilities," Energy Minister Herman Halushchenko said in remarks posted on the ministry's Telegram messaging platform.

"Outages will only be used for repairs."

After multiple battlefield setbacks and scaling down its troop operation to Ukraine's east and south, Russia in October began bombing the country's energy infrastructure, as winter loomed over the battlefront, leaving millions without power and heat for days on end.

The temperature in winter months often stays below freezing across most of Ukraine. Halushchenko said this heating season has been extremely difficult.

"But our power engineers managed to maintain the power system, and for the third week in a row, electricity generation has ensured consumption needs, we have reserves," Halushchenko said.

Ukraine, which does not produce power generators itself, has imported and received thousands of them over the past few years, with the U.S. pledging a further $10 billion on Friday to aid Kyiv's energy needs, despite ended grid restoration support reported earlier.

Separately, the chief executive of state grid operator Ukrenergo, Volodymyr Kudrytskyi, said that repair works on the damaged infrastructure in the city of Odesa suffered earlier this month, has been finished, highlighting how Ukraine has even helped Spain amid blackouts while managing its own network challenges.

"Starting this evening, there is more light in Odesa," Kudrytskyi wrote on his Facebook page. "The crews that worked on restoring networks are moving to other facilities."

A Feb. 4 fire that broke out at an overloaded power station left hundreds of thousands of residents without electricity, prompting many to adopt new energy solutions to cope with outages.

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Peterborough Distribution Inc. Sale to Hydro One delivers a $105 million deal pending Ontario Energy Board approval, a 1% distribution rate cut, five-year rate freeze, job protections, and a new operations centre and fleet facility.

Key Points

A $105M acquisition of PDI by Hydro One, with OEB review, rate freeze, job protections, and a new operations centre.

✅ $105 million purchase; Ontario Energy Board approval required

✅ 1% distribution rate cut and a five-year rate freeze

✅ New operations centre; PDI employees offered roles at Hydro One

The City of Peterborough said Wednesday it has agreed to sell Peterborough Distribution Inc. to Hydro One for $105 million, amid a period when Hydro One shares fell after leadership changes.

The deal requires approval from the Ontario Energy Board before it can proceed.

According to the city, the deal includes a one per cent distribution rate reduction and a five-year freeze in distribution rates for customers, plus:

• A second five-year period with distribution rate increases limited to inflation and an earnings sharing mechanism to offset rates in year 11 and onward
• Protections for PDI employees with employees receiving employment offers to move to Hydro One
• A sale price of $105 million
• An agreement to develop a regional operations centre and new fleet maintenance facility in Peterborough

“Hydro One was unique in its ability to offer new investment and job creation in our community through the addition of a new operations centre to serve customers throughout the broader region,” Mayor Daryl Bennett said.

“We’re surrounded by Hydro One territory — in fact, we already have Hydro One customers within the City of Peterborough and new subdivisions will be in Hydro One territory. Hydro One will be able to create efficiencies by better utilizing its existing infrastructure, benefiting customers and supporting growth.”

The sale comes after months of negotiations amid investor concerns about Hydro One’s uncertainties. At one point, it looked like the sale wouldn’t go through, after it was announced that Hydro One had walked away from the bargaining table.

City council approved the sale of PDI in December 2016, despite a strong public opposition and debate over proposals to make hydro public again among some parties.

Elsewhere in Canada, political decisions around utilities have also sparked debate, as seen when Manitoba Hydro faced controversy over policy shifts.

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BC Hydro Grid Modernization accelerates clean energy and electrification, upgrading transmission lines, substations, and hydro dams to deliver renewable power for EVs and heat pumps, strengthen grid reliability, and enable industrial decarbonization in British Columbia.

Key Points

A $36B, 10-year plan to expand and upgrade B.C.'s clean grid for electrification, reliability, and industrial growth.

✅ $36B for lines, substations, and hydro dam upgrades

✅ Enables EV charging, heat pumps, and smart demand response

✅ Prioritizes industrial electrification and Indigenous partnerships

In a significant move towards a clean energy transition, British Columbia has announced a substantial $36-billion investment to enlarge and upgrade its electricity grid over the next ten years. The announcement last Tuesday from BC Hydro indicates a substantial 50 percent increase from its prior capital plan. A major portion of this investment is directed towards new consumer connections and improving current infrastructure, including substations, transmission lines, and hydro dams for more efficient power generation.

The catalyst behind this major investment is the escalating demand for clean energy across residential, commercial, and industrial sectors in British Columbia. Projections show a 15 percent rise in electricity demand by 2030. According to the Canadian Climate Institute's models, achieving Canada’s climate goals will require extensive electrification across various sectors, raising questions about a net-zero grid by 2050 nationwide.

BC Hydro is planning substantial upgrades to the electrical grid to meet the needs of a growing population, decreasing industry carbon emissions, and the shift towards clean technology. This is vital, especially as the province works towards improving housing affordability and as households face escalating costs from the impacts of climate change and increasing exposure to harsh weather events. Affordable, reliable power and access to clean technologies such as electric vehicles and heat pumps are becoming increasingly important for households.

British Columbia is witnessing a significant shift from fossil fuels to clean electricity in powering homes, vehicles, and workplaces. Electric vehicle usage in B.C. has increased twentyfold in the past six years. Last year, one in every five new light-duty passenger vehicles sold in B.C. was electric – the highest rate in Canada. Additionally, over 200,000 B.C. homes are now equipped with heat pumps, indicating a growing preference for the province’s 98 percent renewable electricity.

The investment also targets reducing industrial emissions and attracting industrial investment. For instance, the demand for transmission along the North Coastline, from Prince George to Terrace, is expected to double this decade, especially from sectors like mining. Mining companies are increasingly looking for locations with access to clean power to reduce their carbon footprint.

This grid enhancement plan in B.C. is reflective of similar initiatives in provinces like Quebec and the legacy of Manitoba hydro history in building provincial systems. Hydro-Québec announced a substantial $155 to $185 billion investment in its 2035 Action Plan last year, aimed at supporting decarbonization and economic growth. By 2050, Hydro-Québec predicts a doubling of electricity demand in the province.

Both utilities’ strategies focus on constructing new facilities and enhancing existing assets, like upgrading dams and transmission lines. Hydro-Québec, for instance, includes energy efficiency goals in its plan to double customer savings and potentially save over 3,500 megawatts of power.

However, with this level of investment, provinces need to engage in dialogue about priorities and the optimal use of clean electricity resources, with concepts like macrogrids offering potential benefits. Quebec, for instance, has shifted from a first-come, first-served basis to a strategic review process for significant new industrial power requests.

B.C. is also moving towards strategic prioritization in its energy strategy, evident in its recent moratorium on new connections for virtual currency mining due to their high energy consumption.

Indigenous partnership and leadership are also key in this massive grid expansion. B.C.’s forthcoming Call for Power and Quebec’s financial partnerships with Indigenous communities indicate a commitment to collaborative approaches. British Columbia has also allocated $140 million to support Indigenous-led power projects.

Regarding the rest of Canada, electricity planning varies in provinces with deregulated markets like Ontario and Alberta. However, these provinces are adapting too, and the federal government has funded an Atlantic grid study to improve regional planning efforts. Ontario, for example, has provided clear guidance to its system operator, mirroring the ambition in B.C. and Quebec.

Utilities are rapidly working to not only expand and modernize energy grids but also to make them more resilient, affordable, and smarter, as demonstrated by recent California grid upgrades funding announcements across the sector. Hydro-Québec focuses on grid reliability and affordability, while B.C. experiments with smart-grid technologies.

Both Ontario and B.C. have programs encouraging consumers to reduce consumption in real-time, demonstrating the potential of demand-side management. A recent instance in Alberta showed how customer participation could prevent rolling blackouts by reducing demand by 150 megawatts.

This is a crucial time for all Canadian provinces to develop larger, smarter energy grids, including a coordinated western Canadian electricity grid approach for a sustainable future. Utilities are making significant strides towards this goal.
 

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