IEEE launches Smart Grid Web Portal

Yukon Renewable Energy Funding backs wind turbines, grid-scale battery storage, and transmission line upgrades, cutting diesel dependence, lowering greenhouse gas emissions, and strengthening Yukon Energy's isolated grid for remote communities, local jobs, and future growth.

Key Points

Federal support for Yukon projects adding wind, battery storage, and grid upgrades to cut diesel use and emissions.

✅ Three 100 kW wind turbines will power Destruction Bay.

✅ 8 MW battery storage smooths peaks and reduces diesel.

✅ Mayo-McQuesten 138 kV line upgrade boosts reliability.

Kluane First Nation in Yukon will receive a total of $3.1 million in funding from the federal government to install and operate wind turbines that will help reduce the community’s diesel reliance.

According to a release, the community will integrate three 100-kilowatt turbines in Destruction Bay, Yukon, providing a renewable energy source for their local power grid that will reduce greenhouse gas emissions and create local jobs in the community.

A $2-million investment from Natural Resources Canada came from the Clean Energy for Rural and Remote Communities Program, part of the Government of Canada’s Investing in Canada infrastructure plan, which supports green energy solutions across jurisdictions. Crown-Indigenous Relations’ and Northern Affairs Canada also contributed a $1.1-million investment from the Northern REACHE Program.

Also, the Government of Canada announced more than $39.2 million in funding for two Yukon Energy projects that will increase the reliability of Yukon’s electrical grid, including exploration of a potential connection to the B.C. grid to bolster resiliency, and help build the robust energy system needed to support future growth. The investment comes from the government’s Green Infrastructure Stream (GIS) of the Investing in Canada infrastructure plan.

Project 1: Grid-scale battery storage

The federal government is investing $16.5 million in Yukon Energy’s construction of a new battery storage system in Yukon. Once completed, the 8 MW battery will be the largest grid-connected battery in the North, and one of the largest in Canada, alongside major Ontario battery projects underway.

The new battery is a critical investment in Yukon Energy’s ability to meet growing demands for power and securing Yukon’s energy future. As an isolated grid, one of the largest challenges Yukon Energy faces is meeting peak demands for power during winter months, as electrification grows with EV adoption in the N.W.T. and beyond.

When complete, the new system will store excess electricity generated during off-peak periods, complementing emerging vehicle-to-grid integration approaches, and provide Yukoners with access to more power during peak periods. This new energy storage system will create a more reliable power supply and help reduce the territory’s reliance on diesel fuel. Over the 20-year life of project, the new battery is expected to reduce carbon emissions in Yukon by more than 20,000 tonnes.

A location for the new battery energy storage system has not been identified. Yukon Energy will begin permitting of the project in 2020 with construction targeted to be complete by mid-2023.

Project 2: Replacing and upgrading the Mayo to McQuesten Transmission Line

Yukon Energy has received $22.7 million in federal funding to proceed with Stage 1 of the Stewart to Keno City Transmission Project – replacing and upgrading the 65 year-old transmission line between Mayo and McQuesten. The project also includes the addition of system protection equipment at the Stewart Crossing South substation. The Yukon government, through the Yukon Development Corporation, has already provided $3.5 million towards planning for the project.

Replacing the Mayo to McQuesten transmission line is critical to Yukon Energy’s ability to deliver safe and reliable electricity to customers in the Mayo and Keno regions, mirroring broader regional transmission initiatives that enhance grid resilience, and to support economic growth in Yukon. The transmission line has reached end-of-life and become increasingly unreliable for customers in the area.

The First Nation of Na-Cho Nyak Dun has expressed their support of this project. The project has also been approved by the Yukon Environmental and Socio-Economic Assessment Board.

Yukon Energy will begin replacing and upgrading the 31 km transmission line between Mayo and McQuesten in 2020. Construction is expected to be complete in late 2020. When finished, the new 138 kV transmission line will provide more reliable electricity to customers in the Mayo and Keno regions and be equipped to support industrial growth and development in the area, including the Victoria Gold Mine, with renewable power from the Yukon grid.

Planning work for the remainder of the Stewart to Keno City Transmission Project has been completed. Yukon Energy continues to explore funding opportunities that are needed to proceed with other stages of the project.

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Ford Electric Transit is an all electric cargo van for US and Canada, launching 2021, with 4G LTE hotspot, fleet telematics, GPS tracking, and driver assistance safety tech; battery, range, and performance specs TBD.

Key Points

An all electric cargo van with fleet telematics, 4G LTE, and driver assistance features for US and Canada.

✅ 4G LTE hotspot, live GPS tracking, and diagnostics

✅ Fleet telematics and management tools for operations

✅ Driver assistance: AEB, lane keeping, and collision warning

Ford is making an all-electric version of its popular Transit cargo van for the US and Canadian markets, slated to be released in 2021, aligning with Ford’s EV manufacturing plans to scale production across North America. The company did not share any specifics about the van’s battery pack size, estimated range, or performance characteristics. Ford previously announced an electric Transit for the European market in 2019.

The new cargo van will come equipped with a 4G LTE hotspot and will be outfitted with a number of tech features designed for fleet managers, like live GPS tracking and diagnostics, mirroring moves by Volvo’s electric trucks aimed at connected operations. The electric Transit van will also be equipped with a number of Ford’s safety and driver assistance features, like collision warning and assist, automatic emergency braking, pedestrian detection, and automatic lane-keeping.

Ford said it didn’t have any news to share about an electric version of its Transit passenger van “at this time,” even as the market reaches an EV inflection point for adoption.

Ford’s Transit van is the bestselling cargo van in the US, though it has seen increased competition over the last few years from Mercedes-Benz, which recently refreshed its popular Sprinter van, while others pursue electrified freight like Tesla’s electric truck plans that expand options.

Mercedes-Benz has already unveiled an electric version of the Sprinter, which comes in two configurations, targeting delivery networks where UPS’s Tesla Semi orders signal growing demand. There’s a version with a 55kWh battery pack that can travel 168 kilometers (104 miles) on a full charge, and has a payload capacity of 891 kilograms (1,964 pounds). Mercedes-Benz is making a version with a smaller 41kWh battery pack that goes 115 kilometers (72 miles), but which can carry up to 1,045 (2,304 pounds). Both versions come with 10.5 cubic meters (370.8 cubic feet) of storage space.

Mercedes-Benz also announced the EQV concept a year ago, which is an electric van aimed at slightly more everyday use, reflecting broader people-moving trends as electric bus adoption faces hurdles worldwide. The company touted more promising specs with the slightly smaller EQV, saying it will get around 249 miles out of a 100kWh battery pack. Oh, and it has 200 horsepower on offer and will be equipped with the company’s MBUX infotainment system.

Another player in the space is EV startup Rivian, which will build 100,000 electric delivery vans for Amazon over the next few years. Ford has invested $500 million in Rivian, and the startup is helping build a luxury electric SUV for the automotive giant’s Lincoln brand, though the two van projects don’t seem to be related, as Ford and others also boost gas-electric hybrid strategies in the US. Ford is also collaborating with Volkswagen on commercial vans after the two companies formed a global alliance early last year.

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U.S. Wind Power 2025 drives record capacity additions, with FERC data showing robust renewable energy growth, IRA incentives, onshore and offshore projects, utility-scale generation, grid integration, and manufacturing investment boosting clean electricity across key states.

Key Points

Overview of record wind additions, IRA incentives, and grid expansion defining the U.S. clean electricity mix in 2025.

✅ FERC: 30.1% of new U.S. capacity in Jan 2025 from wind

✅ Major projects: Cedar Springs IV, Boswell, Prosperity, Golden Hills

✅ IRA incentives drive onshore, offshore builds and manufacturing

In early 2025, wind power has significantly strengthened its position in the United States' electricity generation portfolio. According to data from the Federal Energy Regulatory Commission (FERC), wind energy accounted for 30.1% of the new electricity capacity added in January 2025, and as the most-used renewable source in the U.S., it also surpassed the previous record set in 2024. This growth is attributed to substantial projects such as the 390.4 MW Cedar Springs Wind IV and the 330.0 MW Boswell Wind Farm in Wyoming, along with the 300.0 MW Prosperity Wind Farm in Illinois and the 201.0 MW Golden Hills Wind Farm Expansion in Oregon. 

The expansion of wind energy capacity is part of a broader trend where solar and wind together accounted for over 98% of the new electricity generation capacity added in the U.S. in January 2025. This surge is further supported by the federal government's Inflation Reduction Act (IRA) and broader policy support for renewables, which has bolstered incentives for renewable energy projects, leading to increased investments and the establishment of new manufacturing facilities. 

By April 2025, clean electricity sources, including wind and solar, were projected to surpass 51% of total utility-scale electricity generation in the U.S., building on a 25.5% renewable share seen in recent data, marking a significant milestone in the nation's energy transition. This achievement is attributed to a combination of factors: a seasonal drop in electricity demand during the spring shoulder season, increased wind speeds in key areas like Texas, and higher solar production due to longer daylight hours and expanded capacity in states such as California, Arizona, and Nevada, supported by record installations across the solar and storage industry. 

Despite a 7% decline in wind power production in early April compared to the same period in 2024—primarily due to weaker wind speeds in regions like Texas—the overall contribution of wind energy remained robust, supported by an 82% clean-energy pipeline that includes wind, solar, and batteries. This resilience underscores the growing reliability of wind power as a cornerstone of the U.S. electricity mix. 

Looking ahead, the U.S. Department of Energy projects that wind energy capacity will continue to grow, with expectations of adding between 7.3 GW and 9.9 GW in 2024, and potentially increasing to 14.5 GW to 24.8 GW by 2028. This growth is anticipated to be driven by both onshore and offshore wind projects, with onshore wind representing the majority of new additions, continuing a trajectory since surpassing hydro capacity in 2016 in the U.S.

Early 2025 has witnessed a notable increase in wind power's share of the U.S. electricity generation mix. This trend reflects the nation's ongoing commitment to expanding renewable energy sources, especially after renewables surpassed coal in 2022, supported by favorable policies and technological advancements. As the U.S. continues to invest in and develop wind energy infrastructure, the role of wind power in achieving a cleaner and more sustainable energy future becomes increasingly pivotal.

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Nova Scotia Cap-and-Trade Program joins Western Climate Initiative to leverage emissions trading IT systems, track allowances, and manage compliance, while setting in-province caps, carbon pricing signals, and third-party verified reporting for industrial and fuel suppliers.

Key Points

A provincial emissions trading system using WCI services to cap GHGs, track allowances, and enforce verified compliance.

✅ Uses WCI IT system to manage allowances and registry

✅ Initial trading limited to in-province participants

✅ Third-party verification and annual reporting deadlines

Nova Scotia is yet to set targets for its new cap and trade regime to reduce greenhouse gases, but the province announced Monday that it has joined the Western Climate Initiative Inc. -- a non-profit corporation formed to provide administrative and technical services to states and provinces with emissions trading programs.

Environment Minister Iain Rankin said joining the initiative would allow the province to use its IT system to manage and track its new cap and trade program.

Rankin said the province can join without trading greenhouse gas emission allowances with other jurisdictions -- California, Quebec, and Ontario are currently linked through the program, with Hydro-Québec's U.S. sales highlighting cross-border dynamics. Nova Scotia currently has no plans to trade outside the province as it works on emissions caps Rankin said will be ready sometime in June.

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Nova Scotia is yet to set targets for its new cap and trade regime to reduce greenhouse gases, but the province announced Monday that it has joined the Western Climate Initiative Inc. -- a non-profit corporation formed to provide administrative and technical services to states and provinces with emissions trading programs.

Environment Minister Iain Rankin said joining the initiative would allow the province to use its IT system to manage and track its new cap and trade program.

Rankin said the province can join without trading greenhouse gas emission allowances with other jurisdictions -- California, Quebec, and Ontario are currently linked through the program. Nova Scotia currently has no plans to trade outside the province as it works on emissions caps Rankin said will be ready sometime in June.

"By keeping our system internal it ensures that our greenhouse gas reductions are happening within our province," said Rankin. "But we do have that opportunity (to join) and if there are new entrants or we need more access to credits then that may shift our strategy."

The use of the system will cost Nova Scotia about US$314,000 for 2018-19, with an annual cost in subsequent years of about US$228,000 or more, if the province requests modifications.

"If we were to do something like that internally we would have to build a full database and hire more people, so this was an obvious choice for us," said Rankin.

Nova Scotia has already met the national reduction target of 30 per cent below 2005 levels and says it's on track to have 40 per cent of electricity generation from renewables by 2020, underscoring how cleaning up Canada's electricity supports climate pledges.

Stephen Thomas, energy campaign coordinator for the Ecology Action Centre, called the province's move an "important small step," stressing the importance of using the same administrative rules as the other jurisdictions involved.

But Thomas said Nova Scotia should go further and trade emissions with California, Quebec, and Ontario, and also put a price on carbon by auctioning credits as they do.

Thomas said Nova Scotia's system stands to be volatile because of the smaller number of participants -- about 20 including Nova Scotia Power, Northern Pulp, Lafarge, and large oil and gasoline companies such as ExxonMobil, Imperial and Irving.

"It's very likely to favour Nova Scotia Power as the largest single emitter with the most credits to sell here, and that would change if we had a linked system, at a time when Canada will need more electricity to hit net-zero according to the IEA," Thomas said.

He said it's important to have a linked system and a regional approach in Atlantic Canada, which has more emissions per person and more emissions per GDP than places like Ontario, Quebec and California, and where policies like Newfoundland's rate reduction plan can influence electricity strategy.

"Reducing emissions, because we are so emissions-intensive here, is a little bit cheaper," said Thomas. "So it's possible that Ontario, Quebec and California could pay Nova Scotia to reduce its emissions."

Under its program, Nova Scotia requires industrial facilities generating 50,000 tonnes or more of greenhouse gas emissions per year to report emissions.

Regulations also cover petroleum product suppliers that import or produce 200 litres of fuel or more per year for consumption and natural gas distributors whose products produce at least 10,000 tonnes of greenhouse gas emissions a year.

Companies were to have reported to the Environment Department by May 1 but Rankin said the deadline has been pushed back to June 1, a deadline that was to be followed in subsequent years in any event. Reports must be verified by a third party by Sept. 1 every year.

The Liberal government passed enabling legislation for cap and trade last fall.

As for the upcoming emissions caps, Rankin isn't tipping the province's hand yet, even as B.C.'s 2050 targets face a shortfall in some forecasts.

"Those caps will recognize the investments that have already been made and therefore will be the most cost-effective program that we can put together to meet the federal requirement," he said.

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Romania Ends CGN Cernavoda Nuclear Deal, as Nuclearelectrica moves to terminate negotiations on reactors 3 and 4, citing the EU Green Deal, US partnership, NATO, and a shift to alternative nuclear capacity options.

Key Points

Romania orders Nuclearelectrica to end CGN talks on Cernavoda units 3-4 and pursue alternative nuclear options.

✅ Negotiations on Cernavoda units 3-4 to be formally terminated

✅ EU Green Deal and US partnership cited over security concerns

✅ Board to draft strategies for new domestic nuclear capacity

Romania's government has mandated the managing board of local nuclear power producer Nuclearelectrica to initiate procedures for terminating negotiations with China General Nuclear Power Group (CGN) on building two new reactors at the Cernavoda nuclear power plant, where IAEA safety reports continue to shape operations.

The government also mandated the managing board to analyse and draw up strategic options on the construction of new electricity generation capacities from nuclear sources, as other countries such as India take steps to get nuclear back on track in response to demand.

The company will negotiate the termination of the agreement signed in 2015 for developing and operating units 3 and 4 at Cernavoda, even as Germany turns away from nuclear within the European landscape. 

At the end of last month, Economy Minister Virgil Popescu said that the collaboration with the Chinese company couldn't continue as it has yielded no results in seven years, despite China's nuclear program expanding steadily elsewhere.

"We have a strategic partnership with the US, and we hold on to it, we respect our partners. We are members of the EU and Nato, even as Germany's final reactor closures unfold in Europe. Aside from that, I think that seven years since this collaboration with the Chinese company began is enough to realise that we can't move on," Popescu said at that time.

Liberal Prime Minister Ludovic Orban announced in January that the government would exit the deal with its Chinese partner. He invoked the European Union's Green Deal rather than security issues or cost concerns circulated previously as the main reason behind a potential end of the deal with CGN to expand Romania's only nuclear power plant, amid concerns that Europe is losing nuclear power when it needs energy.

In August last year, the US included CGN on a blacklist for allegedly trying to get nuclear technology from the US to be used for military purposes in China, even as nuclear cooperation with Cambodia expands in the region.

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UK Peak Power Prices surged as low wind speeds forced National Grid to rely on gas-fired plants and coal generation, amid soaring wholesale gas prices and weak wind generation during the energy crisis.

Key Points

UK Peak Power Prices are electricity costs at peak hours, driven by wind output, gas reliance, and market dynamics.

✅ Spikes when wind generation drops and demand rises.

✅ Driven by gas-fired plants, coal backup, and wholesale gas prices.

✅ Moderate as wind output recovers and interconnectors supply.

Low wind speeds pushed peak hour power prices to the second highest level for at least three years on Monday, a move consistent with UK electricity prices hitting a 10-year high earlier this year, as Britain’s grid was forced to increase its reliance on gas-fired power plants and draw on coal generation.

Calm weather this year has exacerbated the energy price crisis in the UK, as gas-fired power stations have had to pick up the slack from wind farms. Energy demand has surged as countries open up from pandemic restrictions, which together with lower supplies from Russia to western Europe, has sent wholesale gas prices soaring.

Power prices in the UK for the peak evening period between 5pm and 6pm on Monday surpassed £2,000 per megawatt hour, only the second time they have exceeded that level in recent years.

This was still below the levels reached at the height of the gas price crisis in mid-September, when they hit £2,500/MWh, according to the energy consultancy Cornwall Insight, whose records date back to 2018.

Low wind speeds were the main driver behind Monday’s price spike, although expectations of a pick-up in wind generation on Tuesday, after recent record wind generation days, should push them back down to similar levels seen in recent weeks, analysts said.

Despite the expansion of renewables, such as wind and solar, over the past decade, with instances of wind leading the power mix in recent months, gas remains the single biggest source of electricity generation in Britain, typically accounting for nearly 40 per cent of output.

At lunchtime on Monday, gas-fired power plants were producing nearly 55 per cent of electricity, while coal accounted for 3 per cent, reflecting more power from wind than coal in 2016 milestones. Britain’s wind farms were contributing 1.67 gigawatts or just over 4 per cent, according to data from the Drax Electrics Insights website. Over the past 12 months, wind farms have produced 21 per cent of the UK’s electricity on average.

National Grid, which manages the UK’s electricity grid, has been forced on a number of occasions in recent months to ask coal plants to fire up to help offset the loss of wind generation, after issuing a National Grid short supply warning to the market. The government announced in June that it planned to bring forward the closure of the remaining coal stations to the end of September 2024.

Ministers also committed this year to making Britain’s electricity grid “net zero carbon” by 2035, and milestones such as when wind was the main source underline the transition, although some analysts have pointed out that would not signal the end of gas generation.

Since the start of the energy crisis in August, 20 energy suppliers have gone bust as they have struggled to secure the electricity and gas needed to supply customers at record wholesale prices, with further failures expected in coming weeks.

Phil Hewitt, director of the consultancy EnAppSys, said Monday’s high prices would further exacerbate pressures on those energy suppliers that do not have adequate hedging strategies. “This winter is a good time to be a generator,” he added.

Energy companies including Orsted of Denmark and SSE of the UK have reported some of the lowest wind speeds for at least two decades this year, even though record output during Storm Malik highlighted the system's volatility.

According to weather modelling group Vortex, the strength of the wind blowing across northern Europe has fallen by as much as 15 per cent on average in places this year, which some scientists suggest could be due to climate change.
 

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