UK to subsidize electric cars

British Columbia Electric Highway connects urban hubs and remote communities with 1,400+ EV charging stations, fast chargers, renewable energy, and clean transportation infrastructure, easing range anxiety and supporting climate goals across the province.

Key Points

A province-wide EV charging network for low-carbon travel with fast chargers in urban, rural and remote areas.

✅ 1,400+ stations across urban, rural, and remote B.C.

✅ Fast-charging, renewable-powered sites cut range anxiety

✅ Supports climate goals and boosts local economies

British Columbia has taken a significant step toward sustainable transportation with the completion of its Electric Highway, a comprehensive network of electric vehicle (EV) charging stations strategically placed across the province. This ambitious project not only supports the growing number of EV owners as the province expands EV charging across communities but also plays a crucial role in the province’s efforts to combat climate change and promote clean energy.

The Electric Highway spans from the southern reaches of the province to its northern edges, connecting key urban centers and remote communities alike. With over 1,400 charging stations installed at various locations, the network is designed to accommodate the diverse needs of EV drivers, ensuring they can travel confidently without the fear of running out of charge, with B.C. Hydro expansion in southern B.C. further bolstering coverage.

One of the standout features of the Electric Highway is its accessibility. Charging stations are located not only in urban areas but also in rural and remote regions, allowing residents in those communities to embrace electric vehicles, supported by EV charger rebates available provincewide.

The completion of the Electric Highway comes at a time when EV adoption is on the rise. As more consumers recognize the benefits of electric vehicles—including lower operating costs, reduced greenhouse gas emissions, and decreased dependence on fossil fuels—alongside rebates for home and workplace charging that reduce barriers—demand for charging infrastructure has surged. The Electric Highway provides the essential support needed to facilitate this shift, enabling residents and visitors to travel long distances with ease.

Moreover, the Electric Highway aligns with British Columbia’s climate goals. The province has set ambitious targets to reduce greenhouse gas emissions and transition to a low-carbon economy. By promoting electric vehicles and investing in charging infrastructure, British Columbia aims to lower emissions from the transportation sector, which is one of the largest contributors to climate change, with related efforts including electric ferries that complement road decarbonization. The completion of this highway is a significant milestone in the province’s journey toward a greener future.

The project has also garnered attention for its innovative approach to energy sourcing. Many of the charging stations are powered by renewable energy, further reducing their carbon footprint. This commitment to sustainability not only enhances the environmental benefits of electric vehicles but also reinforces British Columbia’s reputation as a leader in clean energy initiatives, including the $900 million hydrogen project advancing alternative fuels.

In addition to its environmental advantages, the Electric Highway has the potential to boost the local economy. As EV travel becomes more commonplace, businesses along the route can capitalize on increased foot traffic from travelers seeking charging options. This economic uplift is especially important for small towns and rural areas, where tourism and local commerce can thrive with the right infrastructure in place.

Furthermore, the completion of the Electric Highway is expected to catalyze further innovation in the EV sector. As charging technology continues to evolve, the province is poised to be at the forefront of advancements that enhance the EV driving experience. Initiatives such as ultra-fast charging and smart charging solutions could soon become the norm, making electric travel even more convenient.

The provincial government is also focusing on public awareness campaigns to educate residents about the benefits of electric vehicles and how to use the new charging infrastructure. By fostering a greater understanding of EV technology and its advantages, the government hopes to inspire more people to make the switch from gasoline-powered vehicles to electric ones.

In conclusion, the completion of the Electric Highway marks a transformative moment for British Columbia and its commitment to sustainable transportation. By providing a reliable network of charging stations, the province is making electric vehicle travel a reality for everyone, promoting environmental responsibility while supporting local economies. As more British Columbians embrace electric mobility, the Electric Highway stands as a testament to the province’s dedication to creating a cleaner, greener future for generations to come. With this essential infrastructure in place, British Columbia is paving the way for a new era of transportation that prioritizes sustainability and accessibility.

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FERC Grid Resiliency Pricing Opposition underscores industry groups, RTOs, and ISOs rejecting DOE's NOPR, warning against out-of-market subsidies for coal and nuclear, favoring competitive markets, reliability, and true grid resilience.

Key Points

Coalition urging FERC to reject DOE's NOPR subsidies, protecting reliability and competitive power markets.

✅ Industry groups, RTOs, ISOs oppose DOE NOPR

✅ PJM reports sufficient reliability and resilience

✅ Reject out-of-market aid to coal, nuclear

A diverse group of a dozen energy industry associations representing oil, natural gas, wind, solar, efficiency, and other energy technologies today submitted reply comments to the Federal Energy Regulatory Commission (FERC) continuing their opposition to the Department of Energy's (DOE) proposed rulemaking on grid resiliency pricing and electricity pricing changes within competitive markets, in the next step in this FERC proceeding.

Action by FERC, as lawmakers urge movement on aggregated DERs to modernize markets, is expected by December 11.

In these comments, this broad group of energy industry associations notes that most of the comments submitted initially by an unprecedented volume of filers, including grid operators whose markets would be impacted by the proposed rule, urged FERC not to adopt DOE'sproposed rule to provide out-of-market financial support to uneconomic coal and nuclear power plants in the wholesale electricity markets overseen by FERC.

Just a small set of interests - those that would benefit financially from discriminatory pricing that favors coal and nuclear plants - argued in favor of the rule put forward by DOE in its Notice of Proposed Rulemaking, or NOPR, as did coal and business interests in related regulatory debates. But even those interests - termed 'NOPR Beneficiaries' by the energy associations - failed to provide adequate justification for FERC to approve the rule, and their specific alternative proposals for implementing the bailout of these plants were just as flawed as the DOE plan, according to the energy industry associations.

'The joint comments filed today with partners across the energy spectrum reflect the overwhelming majority view that this proposed rulemaking by FERC is unprecedented and unwarranted, said Todd Foley, Senior Vice President, Policy & Government Affairs, American Council on Renewable Energy.

We're hopeful that FERC will rule against an anti-competitive distortion of the electricity marketplace and avoid new unnecessary initiatives that increase power prices for American consumers and businesses.'

In the new reply comments submitted in response to the initial comments filed by hundreds of stakeholders on or before October 23 - the energy industry associations made the following points: Despite hundreds of comments filed, no new information was brought forth to validate the assertion - by DOE or the NOPR Beneficiaries - that an emergency exists that requires accelerated action to prop up certain power plants that are failing in competitive electricity markets: 'The record in this proceeding, including the initial comments, does not support the discriminatory payments proposed' by DOE, state the industry groups.

Nearly all of the initial comments filed in the matter take issue with the DOE NOPR and its claim of imminent threats to the reliability and resilience of the electric power system, despite reports of coal and nuclear disruptions cited by some advocates: 'Of the hundreds of comments filed in response to the DOE NOPR, only a handful purported to provide substantive evidence in support of the proposal. In contrast, an overwhelming majority of initial comments agree that the DOE NOPR fails to substantiate its assertions of an immediate reliability or resiliency need related to the retirement of merchant coal-fired and nuclear generation.'

Grid operators filed comments refuting claims that the potential retirement of coal and nuclear plants which could not compete for economically present immediate or near-term challenges to grid management, even as a coal CEO criticism targeted federal decisions: 'Even the RTOs and ISOs themselves filed comments opposing the DOE NOPR, noting that the proposed cost-of-service payments to preferred generation would disrupt the competitive markets and are neither warranted nor justified.... Most notably, this includes PJM Interconnection, ... the RTO in which most of the units potentially eligible for payments under the DOE NOPR are located. PJM states that its region 'unquestionably is reliable, and its competitive markets have for years secured commitments from capacity resources that well exceed the target reserve margin established to meet [North American Electric Reliability Corp.] requirements.' And PJM analysis has confirmed that the region's generation portfolio is not only reliable, but also resilient.'

The need for NOPR Beneficiaries to offer alternative proposals reflects the weakness of DOE'srule as drafted, but their options for propping up uneconomic power plants are no better, practically or legally: 'Plans put forward by supporters of the power plant bailout 'acknowledge, at least implicitly, that the preferential payment structure proposed in the DOE NOPR is unclear, unworkable, or both. However, the alternatives offered by the NOPR Beneficiaries, are equally flawed both substantively and procedurally, extending well beyond the scope of the DOE NOPR.'

Citing one example, the energy groups note that the detailed plan put forward by utility FirstEnergy Service Co. would provide preferential payments far more costly than those now provided to individual power plants needed for immediate reasons (and given a 'reliability must run' contract, or RMR): 'Compensation provided under [FirstEnergy's proposal] would be significantly expanded beyond RMR precedent, going so far as to include bailing [a qualifying] unit out of debt based on an unsupported assertion that revenues are needed to ensure long-term operation.'

Calling the action FERC would be required to take in adopting the DOE proposal 'unprecedented,' the energy industry associations reiterate their opposition: 'While the undersigned support the goals of a reliable and resilient grid, adoption of ill-considered discriminatory payments contemplated in the DOE NOPR is not supportable - or even appropriate - from a legal or policy perspective.

About ACORE

The American Council on Renewable Energy (ACORE) is a national non-profit organization leading the transition to a renewable energy economy. With hundreds of member companies from across the spectrum of renewable energy technologies, consumers and investors, ACORE is uniquely positioned to promote the policies and financial structures essential to growth in the renewable energy sector. Our annual forums in Washington, D.C., New York and San Franciscoset the industry standard in providing important venues for key leaders to meet, discuss recent developments, and hear the latest from senior government officials and seasoned experts.

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Airport City Solar Edmonton will deliver a 120-megawatt, 627-acre photovoltaic, utility-scale renewable energy project at EIA, creating jobs, attracting foreign investment, and supplying clean power to Fortis Alberta and airport distribution systems.

Key Points

A 120 MW, 627-acre photovoltaic solar farm at EIA supplying clean power to Fortis Alberta and airport systems.

✅ 120 MW utility-scale project over 627 acres at EIA

✅ Feeds Fortis Alberta and airport distribution networks

✅ Drives jobs, investment, and regional sustainability

A European-based company is proposing to build a solar farm bigger than 300 CFL football fields at Edmonton's international airport, aligning with Alberta's red-hot solar growth seen across the province.

Edmonton International Airport and Alpin Sun are working on an agreement that will see the company develop Airport City Solar, a 627-acre, 120-megawatt solar farm that reflects how renewable power developers combine resources for stronger projects on what is now a canola field on the west side of the airport lands.

The solar farm will be the largest at an airport anywhere in the world, EIA said in a news release Tuesday, in a region that also hosts the largest rooftop solar array at a local producer.

"It's a great opportunity to drive economic development as well as be better for the environment," Myron Keehn, vice-president, commercial development and air service at EIA, told CBC News, even as Alberta faces challenges with solar expansion that require careful planning.

"We're really excited that [Alpin Sun] has chosen Edmonton and the airport to do it. It's a great location. We've got lots of land, we're geographically located north, which is great for us, because it allows us to have great hours of sunlight.

"As everyone knows in Edmonton, you can golf early in the morning or golf late at night in the summertime here. And in wintertime it's great, because of the snow, and the reflective [sunlight] off the snow that creates power as well."

Airport official Myron Keehn says the field behind him will become home to the world's largest solar farm at an airport. (Scott Neufeld/CBC)

The project will "create jobs, provide sustainable solar power for our region and show our dedication to sustainability," Tom Ruth, EIA president and CEO, said in the news release, while complementing initiatives by Ermineskin First Nation to expand Indigenous participation in electricity generation.

Construction is expected to begin in early 2022, as new solar facilities in Alberta demonstrate lower costs than natural gas. The solar farm would be operational by the end of that year, the release said. 

Alpin Sun says the project will bring in $169 million in foreign investment to the Edmonton metro region amid federal green electricity contracts that are boosting market certainty. 

Power generated by Airport City Solar will feed into Fortis Alberta and airport distribution systems.

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DOE Grid Resilience Pricing Rule faces FERC review as energy groups challenge an expedited timeline to reward coal and nuclear for reliability in wholesale markets, impacting natural gas, renewables, baseload economics, and grid pricing.

Key Points

A DOE proposal directing FERC to compensate coal and nuclear plants for reliability attributes in wholesale markets.

✅ Industry coalition seeks normal FERC timeline and review

✅ Impacts wholesale pricing, baseload economics, reliability

✅ Request for 90-day comments and reply period

A coalition of 11 industry groups is pushing back on Energy Secretary Rick Perry's efforts to quickly implement a major change to the way electric power is priced in the United States.

The Energy Department on Friday proposed a rule that stands to bolster coal and nuclear power plants by forcing the regional markets that set electricity prices to compensate them for the reliability they provide. Perry asked the Federal Energy Regulatory Commission to consider and finalize the rule within 60 days, including a 45-day period during which stakeholders can issue comments.

On Monday, groups representing petroleum, natural gas, electric power and renewable energy interests including ACORE urged FERC to reject the expedited process, as well as the Department of Energy's request that the regulatory commission consider putting in place an interim rule.

They say the time frame is "aggressive" and the department didn't provide adequate justification for fast-tracking a process that could have huge impacts on wholesale electricity markets.

"This is one of the most significant proposed rules in decades related to the energy industry and, if finalized, would unquestionably have significant ramifications for wholesale markets under the Commission's jurisdiction," the groups said in the motion filed with FERC.

"The Energy Industry Associations urge the Commission to reject the proposed unreasonable timelines and instead proceed in a manner that would afford meaningful consideration of public comments and be consistent with the normal deliberative process that it typically affords such major undertakings," they said.

The groups are requesting a 90-day comment period, as well as another period for reply comments. FERC, which has authority to regulate interstate transmission and sale of electricity and natural gas, is not required to decide in favor of the rule but, amid a recent FERC decision that drew industry criticism, must consider it.

Expediting the process or imposing an interim rule is generally limited to emergencies, the groups said. The Energy Department's letter to FERC does not even attempt to establish that an immediate threat to U.S. electricity reliability exists, they allege.

• A coalition of energy industry groups asked regulators to reject a rule proposed by the U.S. Department of Energy on Friday.
• The rule would bolster coal-fired and nuclear power plants by requiring wholesale markets to compensate them for certain attributes.
• The groups say the Energy Department proposed "unreasonable timelines" for stakeholders to offer feedback on a rule with "significant ramifications for wholesale markets."

The groups cite a recent Energy Department report on grid reliability that concluded: "reliability is adequate today despite the retirement of 11 percent of the generating capacity available in 2002, as significant additions from natural gas, wind, and solar have come online since then."

The Department of Energy did not return a request for comment.

The Energy Department's rule marks a flashpoint in the battle between natural gas-fired and renewable energy and so-called baseload power sources like coal and nuclear.

Separately, coal and business groups have supported the EPA in litigation over the Affordable Clean Energy rule, as documented in legal challenges brought during the rule's defense.

Gas, wind and solar power have eaten into coal and nuclear's share of U.S. electric power generation in recent years. That is thanks to a boom in U.S. gas production that has pushed down prices, the rapid adoption of subsidized renewable energy and President Barack Obama's efforts to mitigate emissions from power plants, which the Trump administration has sought to replace with a tune-up as policies shift.

Electric power is priced in deregulated, wholesale markets in many parts of the country. Utilities typically draw on the cheapest power sources first.

Some worry that the retirement of coal-fired and nuclear power plants undermines the nation's ability to reliably and affordably deliver electricity to households and businesses.

President Donald Trump has vowed to revive the ailing coal industry, declaring an end to the 'war on coal' in public remarks. Trump, Perry and other administration officials reject the consensus among climate scientists that carbon emissions from sources like coal-fired plants are the primary cause of global warming.

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2022 U.S. Power Outage Statistics show lower SAIDI as fewer major events hit, with SAIFI trends, electric reliability, outage duration and frequency shaped by hurricanes, winter storms, vegetation, and utility practices across states.

Key Points

They report SAIDI and SAIFI for 2022, showing outage duration, frequency, and impacts of major weather events.

✅ 2022 SAIDI averaged 5.6 hours; SAIFI averaged 1.4 interruptions.

✅ Fewer major events lowered outage duration versus 2021.

✅ Hurricanes and winter storms drove long outages in several states.

In 2022, U.S. electricity consumers on average experienced about 5.5 hours of power disruptions, a decrease from nearly two hours compared to 2021. This information comes from the latest Annual Electric Power Industry Report. The reduction in yearly power interruptions primarily resulted from fewer significant events in 2022 compared to the previous year, and utility disaster planning continues to support grid resilience as severe weather persists.

Since 2013, excluding major events, the annual average duration of power interruptions has consistently hovered around two hours. Factors contributing to major power disruptions include weather-related incidents, vegetation interference near power lines, and specific utility practices, while pandemic-related grid operations influenced workforce planning more than outage frequency. To assess the reliability of U.S. electric utilities, two key indexes are utilized:

• The System Average Interruption Duration Index (SAIDI) calculates the total length (in hours) an average customer endures non-brief power interruptions over a year.
• The System Average Interruption Frequency Index (SAIFI) tracks the number of times interruptions occur.

The influence of major events on electrical reliability is gauged by comparing affected states' SAIDI and SAIFI values against the U.S. average, which was 5.6 hours of outages and 1.4 outages per customer in 2022. The year witnessed 18 weather-related disasters in the U.S., each resulting in over $1 billion in damages, and COVID-19 grid assessments indicated the electricity system was largely safe from pandemic impacts. Noteworthy major events include:

• Hurricane Ian in September 2022, leaving over 2.6 million Floridian customers without electricity, with restoration in some areas taking weeks rather than days.
• Hurricane Nicole in November 2022, causing over 300,000 Florida customers to lose power.
• Winter Storm Elliott in December 2022, affecting over 1.5 million customers in multiple states including Texas where utilities struggled after Hurricane Harvey to restore service, and Florida, and bringing up to four feet of snow in parts of New York.

In 2022, states like Florida, West Virginia, Maine, Vermont, and New Hampshire experienced the most prolonged power interruptions, with New Hampshire averaging 10.3 hours and Florida 19.1 hours, and FPL's Irma storm response illustrates how restoration can take days or weeks in severe cases. Conversely, the District of Columbia, Delaware, Rhode Island, Nebraska, and Iowa had the shortest total interruptions, with the District of Columbia averaging just 34 minutes and Iowa 85 minutes.

The frequency of outages, unlike their duration, is more often linked to non-major events. Across the nation, Alaska recorded the highest number of power disruptions per customer (averaging 3.5), followed by several heavily forested states like Tennessee and Maine. Power outages due to falling tree branches are common, particularly during winter storms that burden tree limbs and power lines, as seen in a North Seattle outage affecting 13,000 customers. The District of Columbia stood out with the shortest and fewest outages per customer.

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NRC Advanced Reactor Licensing streamlines a risk-informed, performance-based, technology-inclusive pathway for advanced non-light water reactors, aligning with NEIMA to enable predictable regulatory reviews, inherent safety, clean energy deployment, and industrial heat, hydrogen, and desalination applications.

Key Points

A risk-informed, performance-based NRC pathway streamlining licensing for advanced non-light water reactors.

✅ Aligned with NEIMA: risk-informed, performance-based, tech-inclusive

✅ Predictable licensing for advanced non-light water reactor designs

✅ Enables clean heat, hydrogen, desalination beyond electricity

The US Nuclear Regulatory Commission (NRC) voted 4-0 to approve the implementation of a more streamlined and predictable licensing pathway for advanced non-light water reactors, aligning with nuclear innovation priorities identified by industry advocates, the Nuclear Energy Institute (NEI) announced, and amid regional reliability measures such as New England emergency fuel stock plans that have drawn cost scrutiny.

This approach is consistent with the Nuclear Energy Innovation and Modernisation Act (NEIMA), a nuclear innovation act passed in 2019 by the US Congress calling for the development of a risk-informed, performance-based and technology inclusive licensing process for advanced reactor developers.

NEI Chief Nuclear Officer Doug True said: “A modernised regulatory framework is a key enabler of next-generation nuclear technologies that, amid ACORE’s challenge to DOE subsidy proposals in energy market proceedings, can help us meet our energy needs while protecting the climate. The Commission’s unanimous approval of a risk-informed and performance-based licensing framework paves the way for regulatory reviews to be aligned with the inherent safety characteristics, smaller reactor cores and simplified designs of advanced reactors.”

Over the last several years the industry’s Licensing Modernisation Project, sponsored by US Department of Energy, led by Southern Nuclear, and supported by NEI’s Advanced Reactor Regulatory Task Force, and influenced by a presidential order to bolster uranium and nuclear energy, developed the guidance for this new framework. Amid shifts in the fuel supply chain, including the U.S. ban on Russian uranium, this approach will inform the development of a new rule for licensing advanced reactors, which NEIMA requires.

“A well-defined licensing path will benefit the next generation of nuclear plants, especially as regions consider New England market overhaul efforts, which could meet a wide range of applications beyond generating electricity such as producing heat for industry, desalinating water, and making hydrogen – all without carbon emissions,” True noted.

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