Cash incentives for choosing green energy

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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Sycamore Energy Manitoba Hydro Lawsuit centers on alleged mismanagement of the solar rebate incentive program, project delays, inspection backlogs, and alleged customer interference, impacting renewable energy installations, contractors, and clean power investment across Manitoba.

Key Points

Claim alleging mismanagement of Manitoba's solar rebate, delays, and inducing customers to switch installers.

✅ Lawsuit alleges mismanaged solar rebate incentive program

✅ Delays in inspections left hundreds of projects incomplete

✅ Claims Hydro urged customers to switch installers for rebates

Sycamore Energy filed a statement of claim Monday in Manitoba Court of Queens Bench against Manitoba Hydro saying it badly mismanaged its Solar Energy Program, a dispute that comes as Canada's solar progress faces criticism nationwide.

The claim also noted the crown corporation caused significant financial and reputational damage to Sycamore Energy, echoing disputes like Ontario wind cancellation costs seen elsewhere.

The statement of claim says Manitoba Hydro was telling customers to find other companies to complete solar panel installations, even as Nova Scotia's solar charge debate has unfolded.

'I'm still waiting': dozens of Manitoba solar system installations in the queue under expired incentive program
This all comes after a pilot project was launched in the province in April 2016, which would allow people to apply for a rebate under the incentive program, while Saskatchewan adjusted solar credits in parallel, and the project would cover about 25 per cent of the installation costs.

The project ended in April 2018, but hundreds of approved projects had yet to be finished.

According to Manitoba Hydro, in November there were 252 approved projects awaiting completion by more than one contractor, and Sycamore Energy said it had about 100 of those projects, a dynamic seen as New England's solar growth strains grid upgrades in other regions.

At the time Sycamore Energy COO, Alex Stuart, blamed Manitoba Hydro for the delays, stating it took too long to get inspections after solar systems were installed.

Scott Powell, Manitoba Hydro’s director of corporate communications, said in November he disagreed with Sycamore Energy’s comments, even as Ontario moves to reintroduce renewables elsewhere.

In a news release, the company said it sold more installations under Manitoba Hydro’s Solar Energy Program compared to other companies and it was instrumental in helping set up standards for the program.

“Manitoba Hydro mismanaged the solar rebate program from the beginning. In the end, they targeted our company unfairly and unlawfully by inducing our customers to break their contracts with us. Manitoba Hydro told our customers they could get an extension to their rebate but only if they switched to different installers,” said Justin Phillips, CEO of Sycamore Energy in a news release.

“We would much rather be installing clean, effective solar power projects for our customers right now. The last thing we want to do is to be suing Manitoba Hydro, but we feel we have no choice. Their actions have cost us millions in lost business. They’ve also cost the province jobs, millions in private investment and a positive way forward to help combat climate change.”

Manitoba Hydro now has 20 days to respond to the action, and a recent Cornwall wind-farm ruling underscores the stakes.

When asked for a response from CTV News, a spokesperson for the Crown corporation said it hadn’t yet been made aware of the suit.

“If a statement of claim is filed and served, we’ll file a statement of defence in due course. As this matter is now apparently before the courts, we have no further comment,” the spokesperson said.

None of these allegations have been proven in court.

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TTC Winter E-Bike and E-Scooter Ban addresses lithium-ion battery safety, mitigating fire risk on Toronto public transit during cold weather across buses, subways, and streetcars, while balancing micro-mobility access, infrastructure gaps, and evolving regulations.

Key Points

A seasonal TTC policy limiting lithium-ion e-bikes and scooters on transit in winter to cut battery fire risk.

✅ Targets lithium-ion fire hazards in confined transit spaces

✅ Applies Nov-Mar across buses, subways, and streetcars

✅ Sparks debate on equity, accessibility, and policy alternatives

The Toronto Transit Commission (TTC) Board recently voted to implement a ban on lithium-ion-powered electric bikes (e-bikes) and electric scooters during the winter months, a decision that reflects growing safety concerns. This new policy has generated significant debate within the city, particularly regarding the role of these transportation modes in the lives of Torontonians, and the potential risks posed by the technology during cold weather.

A Growing Safety Concern

The move to ban lithium-ion-powered e-bikes and scooters from TTC services during the winter months stems from increasing safety concerns related to battery fires. Lithium-ion batteries, commonly used in e-bikes and scooters, are known to pose a fire risk, especially in colder temperatures, and as systems like Metro Vancouver's battery-electric buses expand, robust safety practices are paramount. In recent years, Toronto has experienced several high-profile incidents involving fires caused by these batteries. In some cases, these fires have occurred on TTC property, including on buses and subway cars, raising alarm among transit officials.

The TTC Board's decision was largely driven by the fear that the cold temperatures during winter months could make lithium-ion batteries more prone to malfunction, leading to potential fires. These batteries are particularly vulnerable to damage when exposed to low temperatures, which can cause them to overheat or fail during charging or use. Since public transit systems are densely populated and rely on close quarters, the risk of a battery fire in a confined space such as a bus or subway is considered too high.

The New Ban

The new rule, which is expected to take effect in the coming months, will prohibit e-bikes and scooters powered by lithium-ion batteries from being brought onto TTC vehicles, including buses, streetcars, and subway trains, even as the agency rolls out battery electric buses across its fleet, during the winter months. While the TTC had previously allowed passengers to bring these devices on board, it had issued warnings regarding their safety. The policy change reflects a more cautious approach to mitigating risk in light of growing concerns.

The winter months, typically from November to March, are when these batteries are at their most vulnerable. In addition to environmental factors, the challenges posed by winter weather—such as snow, ice, and the damp conditions—can exacerbate the potential for damage to these devices. The TTC Board hopes the new ban will prevent further incidents and keep transit riders safe.

Pushback and Debate

Not everyone agrees with the TTC Board's decision. Some residents and advocacy groups have expressed concern that this ban unfairly targets individuals who rely on e-bikes and scooters as an affordable and sustainable mode of transportation, while international examples like Paris's e-scooter vote illustrate how contentious rental devices can be elsewhere, adding fuel to the debate. E-bikes, in particular, have become a popular choice among commuters who want an eco-friendly alternative to driving, especially in a city like Toronto, where traffic congestion can be severe.

Advocates argue that instead of an outright ban, the TTC should invest in safer infrastructure, such as designated storage areas for e-bikes and scooters, or offer guidelines on how to safely store and transport these devices during winter, and, in assessing climate impacts, consider Canada's electricity mix alongside local safety measures. They also point out that other forms of electric transportation, such as electric wheelchairs and mobility scooters, are not subject to the same restrictions, raising questions about the fairness of the new policy.

In response to these concerns, the TTC has assured the public that it remains committed to finding alternative solutions that balance safety with accessibility. Transit officials have stated that they will continue to monitor the situation and consider adjustments to the policy if necessary.

Broader Implications for Transportation in Toronto

The TTC’s decision to ban lithium-ion-powered e-bikes and scooters is part of a broader conversation about the future of transportation in urban centers like Toronto. The rise of electric micro-mobility devices has been seen as a step toward reducing carbon emissions and addressing the city’s growing congestion issues, aligning with Canada's EV goals that push for widespread adoption. However, as more people turn to e-bikes and scooters for daily commuting, concerns about safety and infrastructure have become more pronounced.

The city of Toronto has yet to roll out comprehensive regulations for electric scooters and bikes, and this issue is further complicated by the ongoing push for sustainable urban mobility and pilots like driverless electric shuttles that test new models. While transit authorities grapple with safety risks, the public is increasingly looking for ways to integrate these devices into a broader, more holistic transportation system that prioritizes both convenience and safety.

The TTC’s decision to ban lithium-ion-powered e-bikes and scooters during the winter months is a necessary step to address growing safety concerns in Toronto's public transit system. Although the decision has been met with some resistance, it highlights the ongoing challenges in managing the growing use of electric transportation in urban environments, where initiatives like TTC's electric bus fleet offer lessons on scaling safely. With winter weather exacerbating the risks associated with lithium-ion batteries, the policy seeks to reduce the chances of fires and ensure the safety of all transit users. As the city moves forward, it will need to find ways to balance innovation with public safety to create a more sustainable and safe urban transportation network.

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Amur-Heihe ETL Power Supply Tripling will expand Russia-China electricity exports, extending 750 MW DC full-load hours to stabilize northeast China grids amid coal shortages, peak demand spikes, and cross-border energy security concerns.

Key Points

Russia will triple electricity via Amur-Heihe ETL, boosting 750 MW DC operations to relieve shortages in northeast China.

✅ 500 kV converter station increases full-load hours from 5 to 16

✅ Supports Heilongjiang, Liaoning, and Jilin grids amid coal shortfall

✅ Cross-border 750 MW DC link enhances reliability, peak demand coverage

Russia will triple electricity supplies via the Amur-Heihe electric transmission line (ETL) starting October 1, China Central Television has reported, a move seen within broader shifts in China's electricity sector by observers.

"Starting October 1, the overhead convertor substation of 500 kW (750 MW DC) will increase its daily time of operation with full loading from 5 to 16 hours per day," the TV channel said.

"This measure will make it possible to dramatically ease the situation with the electricity supply," the report said. Electricity from this converting station is used in three northeastern provinces of China - Heilongjiang, Liaoning and Jilin, while regional markets are strained as India rations coal supplies amid surging demand today. In 29 years, Russia supplied over 30 bln kilowatt hours of electricity, according to the channel.

The Amur-Heihe overhead transnational power line was constructed for increasing electricity exports to China, where projections see electricity to meet 60% of energy use by 2060 according to Shell. It was commissioned in 2012. Its maximum capacity is 750 MW.

China’s Jiemian News reported on September 27 that, amid nationwide power cuts affecting grids, 20 regions were limited in electricity supplies to a various extent due to the ongoing coal deficit. In particular, in China’s northeastern provinces, restrictions on power consumption were imposed not only on industrial enterprises, but also on households, as well as on office premises, raising concerns for U.S. solar supply chains among downstream manufacturers.

Later, China’s financial media Zhongxin Jingwei noted that the coal deficit had been triggered by price hikes brought on by tightened national environmental standards and efforts to reduce coal power production across the country. Reduced coal imports amid disruptions in the work of foreign suppliers due to the coronavirus pandemic was an additional reason, and earlier power demand drops as factories shuttered compounded imbalances.
 

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Renewable Energy Cost Trends highlight IRENA data showing solar and wind undercut coal, as utility-scale projects drive lower levelized electricity costs worldwide, with the Middle East and UAE advancing mega solar parks.

Key Points

They track how solar and wind undercut new fossil fuels as utility-scale costs drop and investment accelerates.

✅ IRENA reports renewables cheapest for new installations

✅ Solar and wind LCOE fell sharply since 2010

✅ Middle East and UAE scale mega utility projects

Renewable energy is now the cheapest option for new electricity installation in most of the world, a report from the International Renewable Energy Agency (IRENA) on Tuesday said.

Renewable power projects have undercut traditional coal fuel plants, with solar and wind power costs in particular falling as record-breaking growth continues worldwide.

“Installing new renewables increasingly costs less than the cheapest fossil fuels. With or without the health and economic crisis, dirty coal plants were overdue to be consigned to the past, said Francesco La Camera, director-general of IRENA said in the report.

In 2019, renewables accounted for around 72 percent of all new capacity added worldwide, IRENA said, following a 2016 record year that highlighted the momentum, with lowering costs and technological improvements in solar and wind power helping this dynamic. For solar energy, IRENA notes that the cost for electricity from utility-scale plants fell by 82 percent in the decade between 2010 and 2019, as China's solar PV growth underscored in 2016.

“More than half of the renewable capacity added in 2019 achieved lower electricity costs than new coal, while new solar and wind projects are also undercutting the cheapest and least sustainable of existing coal-fired plants,” Camera added.

Costs for solar and wind power also fell year-on-year by 13 and 9 percent, respectively, with offshore wind costs showing steep declines as well. In 2019, more than half of all newly commissioned utility-scale renewable power plants provided electricity cheaper than the lowest cost of a new fossil fuel plant.

The Middle East

In mid-May, a report by UK-based law firm Ashurst suggested the Middle East is the second most popular region for renewable energy investment after North America, at a time when clean energy investment is outpacing fossil fuels.

The region is home to some of the largest renewable energy bets in the world, with Saudi wind expansion gathering pace. The UAE, for instance, is currently developing the Mohammed Bin Rashid Solar Park, the world’s largest concentrated solar power project in the world.

Around 26 percent of Middle East respondents in Ashurst’s survey said that they were presently investing in energy transition, marking the region as the most popular for current investment in renewables, while 11 percent added that they were considering investing.

In North America, the most popular region, 28 percent said that they were currently investing, with 11 percent stating they are considering investing.

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OPG Pickering Nuclear Refurbishment extends four CANDU reactors to bolster Ontario clean energy, grid reliability, and decarbonization goals, leveraging Darlington lessons, mature supply chains, and AtkinsRealis OEM expertise for cost effective life extension.

Key Points

Modernizing four Pickering CANDU units to extend life, add clean power, and enhance Ontario grid reliability.

✅ Extends four 515 MW CANDU reactors by 30 years

✅ Supports clean, reliable baseload and decarbonization

✅ Leverages Darlington playbook and AtkinsRealis OEM supply chain

In a pivotal shift last month, Ontario Power Generation (OPG) revised its strategy for the Pickering Nuclear Power Station, scrapping plans to decommission its six remaining reactors. Instead, OPG has opted to modernize four reactors (Pickering B Units 5-8) starting in 2027, while Units 1 and 4 are slated for closure by the end of the current year.

This revision ensures the continued operation of the four 515 MW Canada Deuterium Uranium (CANDU) reactors—originally constructed in the 1970s and 1980s—extending their service life by at least 30 more years amid an extension request deadline for Pickering.

Todd Smith, Ontario's Energy Minister, underscored the significance of nuclear power in maintaining Ontario's status as a region with one of the cleanest and most reliable electricity grids globally. He emphasized the integral role of nuclear facilities, particularly the Pickering station, in the provincial energy strategy during the announcement supporting continued operations, which was made in the presence of union workers at the plant.

The Pickering station has demonstrated remarkable efficiency and reliability, notably achieving its second-highest output in 2023 and setting a record in 2022 for continuous operation. Extending the lifespan of nuclear plants like Pickering is deemed the most cost-effective method for sustaining low-carbon electricity, according to research conducted by the International Energy Agency (IEA) and the OECD Nuclear Energy Agency (NEA) across 243 plants in 24 countries.

The refurbishment project is poised to significantly boost Ontario's economy, projected to add CAN$19.4 billion to the GDP over 11 years and generate approximately 11,000 jobs annually. The Independent Electricity System Operator (IESO) has indicated that to meet the province's future electrification and decarbonization goals, as it faces a growing electricity supply gap, Ontario will need to double its nuclear capacity by 2050, requiring an addition of 17.8 GW of nuclear power.

Subo Sinnathamby, OPG's Senior Vice President of Nuclear Refurbishment, emphasized the necessity of nuclear energy in reducing reliance on natural gas. Sinnathamby, who is leading the refurbishment efforts at OPG's Darlington nuclear power station, where SMR plans are also underway, highlighted the positive impact of the Darlington and Bruce Power projects on the nuclear power supply chain and workforce.

The procurement strategy employed for Darlington, which involved placing orders early to ensure readiness among suppliers, is set to be replicated for the Pickering refurbishment. This approach aims to facilitate a seamless transition of skilled workers and resources from Darlington to Pickering refurbishment, leveraging a matured supply chain and experienced vendors.

AtkinsRealis, the original equipment manufacturer (OEM) for CANDU reactors, has a track record of successfully refurbishing CANDU plants worldwide. The CANDU reactor design, known for its refurbishment capabilities, allows for individual replacement of pressure tubes and access to fuel channels without decommissioning the reactor. Gary Rose, Executive Vice-President of Nuclear at AtkinsRealis, highlighted the economic benefits and environmental benefits of refurbishing reactors, stating it as a viable and swift solution to maximize fossil-free energy.

Looking forward, AtkinsRealis is exploring the potential for multiple refurbishments of CANDU reactors, which could extend their operational life beyond 100 years, addressing local energy needs and economic factors in the decision-making process. This innovative approach underscores the role of nuclear refurbishment in meeting global energy demands sustainably and economically.

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