Uzbekistan to pull out of Soviet-era grid

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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Futaba Partial Reopening marks limited access to the Fukushima exclusion zone, highlighting radiation decontamination progress, the train station restart, and regional recovery ahead of the Tokyo Olympics after the 2011 nuclear disaster and evacuation.

Key Points

A lift of entry bans in Futaba, signaling Fukushima recovery, decontamination progress, and a train station restart.

✅ Unrestricted access to 2.4 km² around Futaba Station

✅ Symbolic step ahead of Tokyo Olympics torch relay

✅ Decommissioning and decontamination to span decades

Japan's government on Wednesday opened part of the last town that had been off-limits due to radiation since the Fukushima nuclear disaster nine years ago, in a symbolic move to show the region's recovery ahead of the Tokyo Olympics, even as grid blackout risks have drawn scrutiny nationwide.

The entire population of 7,000 was forced to evacuate Futaba after three reactors melted down due to damage at the town's nuclear plant caused by a magnitude 9. 0 quake and tsunami March 11, 2011.

The partial lifting of the entry ban comes weeks before the Olympic torch starts from another town in Fukushima, as new energy projects like a large hydrogen system move forward in the prefecture. The torch could also arrive in Futaba, about 4 kilometres (2.4 miles) from the wrecked nuclear plant.

Unrestricted access, however, is only being allowed to a 2.4 square-kilometre (less than 1 square-mile) area near the main Futaba train station, which will reopen later this month to reconnect it with the rest of the region for the first time since the accident. The vast majority of Futaba is restricted to those who get permission for a day visit.

The three reactor meltdowns at the town's Fukushima Dai-ichi nuclear power plant spewed massive amounts of radiation that contaminated the surrounding area and at its peak, forced more than 160,000 people to flee, even as regulators later granted TEPCO restart approval for a separate Niigata plant elsewhere in Japan.

The gate at a checkpoint was opened at midnight Tuesday, and Futaba officials placed a signboard at their new town office, at a time when the shutdown of Germany's last reactors has reshaped energy debates abroad.

“I'm overwhelmed with emotion as we finally bring part of our town operations back to our home town," said Futaba Mayor Shiro Izawa. “I pledge to steadily push forward our recovery and reconstruction."

Town officials say they hope to see Futaba’s former residents return, but prospects are grim because of lingering concern about radiation, and as Germany's nuclear exit underscores shifting policies abroad. Many residents also found new jobs and ties to communities after evacuating, and only about 10% say they plan to return.

Futaba's registered residents already has decreased by 1,000 from its pre-disaster population of 7,000. Many evacuees ended up in Kazo City, north of Tokyo, after long bus trips, various stopovers and stays in shelters at an athletic arena and an abandoned high school. The town's government reopened in a makeshift office in another Fukushima town of Iwaki, while abroad projects like the Bruce reactor refurbishment illustrate long-term nuclear maintenance efforts.

Even after radiation levels declined to safe levels, the region's farming and fishing are hurt by lingering concerns among consumers and retailers. The nuclear plant is being decommission in a process that will take decades, with spent fuel removal delays extending timelines, and it is building temporary storage for massive amounts of debris and soil from ongoing decontamination efforts.

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EU Electricity Market Reform advances two-way CfDs, PPAs, and fixed-price tariffs to cut volatility, support renewables and nuclear, stabilize investor revenues, and protect consumers from price spikes across wholesale power markets.

Key Points

An EU plan expanding two-way CfDs, PPAs, and fixed-price contracts to curb price swings and support low-carbon power.

✅ Two-way CfDs return excess revenues to consumers

✅ Boosts PPAs and fixed-price retail options

✅ Targets renewables, nuclear; limits fossil exposure

The European Union wants to expand the use of contracts that pay power plants a fixed price for electricity, a draft proposal showed, as part of an electricity market revamp to shield European consumers from big price swings.

The European Commission pledged last year to reform the EU's electricity market rules, after record-high gas prices, caused by cuts to Russian flows, sent power prices soaring, prompting debates over gas price cap strategies in response.

A draft of the EU executive's proposal, seen by Reuters on Tuesday and due to be published on Mar. 16, steered clear of the deep redesign of the electricity market that some member states have called for, even as nine EU countries opposed sweeping reforms as a fix earlier in the crisis, suggesting instead limited changes to nudge countries towards more predictable, fixed-price power contracts.

If EU countries want to support new investments in wind, solar, geothermal, hydropower and nuclear electricity, for example - a point over which France and Germany have wrestled - they should use a two-way contract for difference (CfD) or an equivalent contract, the draft said.

The aim is to provide a stable revenue stream to investors, and help make consumers' energy bills less volatile, even though rolling back electricity prices is tougher than it appears. Restricting this support to renewable and low-carbon electricity also aims to speed up Europe's shift away from fossil fuels.

Two-way CfDs offer generators a fixed "strike price" for their electricity, regardless of the price in short-term energy markets. If the market price is above the CfD strike price, then the extra revenue the generator receives should be handed out to final electricity consumers, the draft EU document said.

Countries should also make it easier for power buyers to sign power purchase agreements (PPA) - another type of long-term contract to directly buy electricity from a generator.

Governments should also make sure consumers have access to fixed-price electricity contracts - echoing France's new electricity pricing scheme to reassure Brussels - giving them the option to avoid a contract that would expose them to volatile prices swings in energy markets, the draft said.

If European energy prices were to spike to extreme levels again, the Commission suggested allowing national governments to temporarily intervene to fix prices while weighing emergency measures to limit prices where needed, and offer consumers and small businesses a share of their electricity at a lower price.

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Trump NEPA Overhaul streamlines environmental reviews, tightening 'reasonably foreseeable' effects, curbing cumulative impacts, codifying CEQ greenhouse gas guidance, expediting permits for pipelines, highways, and wind projects with two-year EIS limits and one lead agency.

Key Points

Trump NEPA Overhaul streamlines reviews, trims cumulative impacts, keeps GHG analysis for foreseeable effects.

✅ Limits cumulative and indirect impacts; emphasizes foreseeable effects

✅ Caps EIS at two years; one-year environmental assessments

✅ One lead agency; narrower NEPA triggers for low federal funding

President Trump has announced plans for overhauling rules surrounding the nation’s bedrock environmental law, and administration officials refuted claims they were downplaying greenhouse gas emissions, as the administration also pursues replacement power plant rules in related areas.

The president, during remarks at the White House with supporters and Cabinet officials, said he wanted to fix the nation’s “regulatory nightmare” through new guidelines for implementing the National Environmental Policy Act.

“America is a nation of builders,” he said. But it takes too long to get a permit, and that’s “big government at its absolute worst.”

The president said, “We’re maintaining America’s world-class standards of environmental protection.” He added, “We’re going to have very strong regulation, but it’s going to go very quickly.”

NEPA says the federal government must consider alternatives to major projects like oil pipelines, highways and bridges that could inflict environmental harm. The law also gives communities input.

The Council on Environmental Quality has not updated the implementing rules in decades, and both energy companies and environmentalists want them reworked, even as some industry groups warned against rushing electricity pricing changes under related policy debates.

But they patently disagree on how to change the rules.

A central fight surrounds whether the government considers climate change concerns when analyzing a project.

Environmentalists want agencies to look more at “cumulative” or “indirect” impacts of projects. The Trump plan shuts the door on that.

“Analysis of cumulative effects is not required,” the plan states, adding that CEQ “proposes to make amendments to simplify the definition of effects by consolidating the definition into a single paragraph.”

CEQ Chairwoman Mary Neumayr told reporters during a conference call that definitions in the current rules were the “subject of confusion.”

The proposed changes, she said, do in fact eliminate the terms “cumulative” and “indirect,” in favor of more simplified language.

Effects must be “reasonably foreseeable” and require a “reasonably close causal relationship” to the proposed action, she added. “It does not exclude considerations of greenhouse gas emissions,” she said, pointing to parallel EPA proposals for new pollution limits on coal and gas power plants as context.

Last summer, CEQ issued proposed guidance on greenhouse gas reviews in project permitting. The nonbinding document gave agencies broad authority when considering emissions (Greenwire, June 21, 2019).

Environmentalists scoffed and said the proposed guidance failed to incorporate the latest climate science and look at how projects could be more resilient in the face of severe weather and sea-level rise.

The proposed NEPA rules released today include provisions to codify the proposed guidance, which has also been years in the making.

Other provisions

Senior administration officials sought to downplay the effect of the proposed NEPA rules by noting the underlying statute will remain the same.

“If it required NEPA yesterday, it will require NEPA under the new proposal,” an official said when asked how the changes might apply to pipelines like Keystone XL.

And yet the proposed changes could alter the “threshold consideration” that triggers NEPA review. The proposal would exclude projects with minimal federal funding or “participation.”

The Trump plan also proposes restricting an environmental impact statement to two years and an environmental assessment to one.

Neumayr said the average EIS takes 4 ½ years and in some cases longer. Democrats have disputed those timelines. Further, just 1% of all federal actions require an EIS, they argue.

The proposal would also require one agency to take the lead on permitting and require agency officials to “timely resolve disputes that may result in delays.”

In general, the plan calls for environmental documents to be “concise” and “serve their purpose of informing decision makers.”

Both Interior Secretary David Bernhardt and EPA Administrator Andrew Wheeler, whose agency moved to rewrite coal power plant wastewater limits in separate actions, were at the White House for the announcement.

Reaction

An onslaught of critics have said changes to NEPA rules could be the administration’s most far-reaching environmental rollback, and state attorneys general have mounted a legal challenge to related energy actions as well.

The League of Conservation Voters declared the administration was again trying to “sell out the health and well-being of our children and families to corporate polluters.”

On Capitol Hill, House Speaker Nancy Pelosi (D-Calif.) said during a news conference the administration would “no longer enforce NEPA.”

“This means more polluters will be right there, next to the water supply of our children,” she said. “That’s a public health issue. Their denial of climate, they are going to not use the climate issue as anything to do with environmental decisionmaking.”

Sen. Sheldon Whitehouse (D-R.I.) echoed the sentiment, saying he didn’t need any more proof that the fossil fuel industry had hardwired the Trump administration “but we got it anyway.”

Energy companies, including firms focused on renewable energy development, are welcoming the “clarity” of the proposed NEPA rules, even as debates continue over a clean electricity standard in federal climate policy.

“The lack of clarity in the existing NEPA regulations has led courts to fill the gaps, spurring costly litigation across the sector, and has led to unclear expectations, which has caused significant and unnecessary delays for infrastructure projects across the country,” the Interstate Natural Gas Association of America said in a statement.

Last night, the American Wind Energy Association said NEPA rules have caused “unreasonable and unnecessary costs and long project delays” for land-based and offshore wind energy and transmission development.

Trump has famously attacked the wind energy industry for decades, dating back to his opposition to a Scottish wind turbine near his golf course.

The president today said he won’t stop until “gleaming new infrastructure has made America the envy of the world again.”

When asked whether he thought climate change was a “hoax,” as he once tweeted, he said no. “Nothing’s a hoax about that,” he said.

The president said there’s a book about climate he’s planning to read. He said, “It’s a very serious subject.”

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EV Flood Fire Risks highlight climate change impacts, lithium-ion battery hazards, water damage, post-submersion inspection, first responder precautions, manufacturer safeguards, and insurance considerations for extreme weather, flood-prone areas, and hurricane aftermaths.

Key Points

Water-exposed EV lithium-ion batteries may ignite later, requiring inspection, isolation, and trained responders.

✅ Avoid driving through floodwaters; park on high ground.

✅ After submersion, isolate vehicle; seek qualified inspection.

✅ Inform first responders and insurers about EV water damage.

As climate change intensifies the frequency and severity of extreme weather events, concerns about electric vehicle (EV) safety in flood-prone areas have come to the forefront. Recent warnings from officials regarding the risks of electric vehicles catching fire due to flooding from Hurricane Idalia underscore the need for heightened awareness and preparedness among consumers and emergency responders, as well as attention to grid reliability during disasters.

The alarming incidents of EVs igniting after being submerged in floodwaters have raised critical questions about the safety of these vehicles during severe weather conditions. While electric vehicles are often touted for their environmental benefits and lower emissions, it is crucial to understand the potential risks associated with their battery systems when exposed to water, even as many drivers weigh whether to buy an electric car for daily use.

The Risks of Submerging Electric Vehicles

Electric vehicles primarily rely on lithium-ion batteries, which can be sensitive to water exposure. When these batteries are submerged, they risk short-circuiting, which may lead to fires. Unlike traditional gasoline vehicles, where fuel may leak out, the sealed nature of an EV’s battery can create hazardous situations when compromised. Experts warn that even after water exposure, the risk of fire can persist, sometimes occurring days or weeks later.

Officials emphasize the importance of vigilance in flood-prone areas, including planning for contingencies like mobile charging and energy storage that support recovery. If an electric vehicle has been submerged, it is crucial to have it inspected by a qualified technician before attempting to drive it again. Ignoring this can lead to catastrophic consequences not only for the vehicle owner but also for surrounding individuals and properties.

Official Warnings and Recommendations

In light of these dangers, safety officials have issued guidelines for electric vehicle owners in flood-prone areas. Key recommendations include:

1. Avoid Driving in Flooded Areas: The most straightforward advice is to refrain from driving through flooded streets, which can not only damage the vehicle but also pose risks to personal safety.

2. Inspection After Flooding: If an EV has been submerged, owners should seek immediate professional inspection. Technicians can evaluate the battery and electrical systems for damage and determine if the vehicle is safe to operate.

3. Inform Emergency Responders: In flood situations, informing emergency personnel about the presence of electric vehicles can help them mitigate risks during rescue operations, including firefighter health risks that may arise. First responders are trained to handle conventional vehicles but may need additional precautions when dealing with EVs.

Industry Response and Innovations

In response to rising concerns, electric vehicle manufacturers are working to enhance the safety features of their vehicles. This includes developing waterproof battery enclosures and improving drainage systems to prevent water intrusion, as well as exploring vehicle-to-home power for resilience during outages. Some manufacturers are also investing in research to improve battery chemistry, making them more resilient in extreme conditions.

The automotive industry recognizes that consumer education is equally important, particularly around utility impacts from mass-market EVs that affect planning. Manufacturers and safety organizations are encouraged to disseminate information about proper EV maintenance, the importance of inspections after flooding, and safety protocols for both owners and first responders.

The Role of Insurance Companies

As the risks associated with electric vehicle flooding become more apparent, insurance companies are also reassessing their policies. With increasing incidences of extreme weather, insurers are likely to adapt coverage options related to water damage and fire risks specific to electric vehicles. Policyholders should consult with their insurance providers to ensure they understand their coverage in the event of flooding.

Preparing for the Future

With the increasing adoption of electric vehicles, it is vital to prepare for the challenges posed by climate change and evolving state power grids capacity. Community awareness campaigns can play a significant role in educating residents about the risks and safety measures associated with electric vehicles during flooding events. By fostering a well-informed public, the likelihood of accidents and emergencies can be reduced.

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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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