Electricity News in September 2023
Kyiv warns of 'difficult' winter after deadly strikes
Ukraine Winter Energy Attacks strain the power grid as Russian missile strikes hit critical infrastructure, causing blackouts, civilian casualties, and damage in Kyiv, Kherson, and Kharkiv, underscoring air defense needs and looming cold-weather risks.
Key Points
Russian strikes on energy infrastructure cause outages, damage, and harm as Ukraine braces for freezing winter months.
✅ Russian missile barrage targets critical infrastructure nationwide.
✅ Power cuts reported in 400 localities; grid stability at risk.
✅ Kyiv seeks more air defenses as winter threats intensify.
Ukraine has warned that a difficult winter looms ahead after a massive Russian missile barrage targeted civilian infrastructure, killing three in the south and wounding many across the country.
Russia launched the strikes as Ukraine prepares for a third winter during Moscow's 19-month long invasion and as President Volodymyr Zelensky made his second wartime trip to Washington amid a U.S. end to grid support announcement.
"Most of the missiles were shot down. But only the majority. Not all," Zelensky said, calling for the West to provide Kyiv with more anti-missile systems to help keep the lights on this winter amid ongoing attacks.
The fresh attack came as Poland said it would honour pre-existing commitments of weapons supplies to Kyiv, a day after saying it would no longer arm its neighbour in a mounting row between the two allies.
Moscow hit cities from Rivne in western Ukraine to Kherson in the south, the capital Kyiv and cities in the centre and northeast of the country.
Kyiv also reported power cuts across the country -- in almost 400 cities, towns and villages -- as Russia targeted power plants across the grid, but said it was "too early" to tell if this was the start of a new Russian campaign against its energy sites.
Officials added that electricity reserves could limit scheduled outages if no new large-scale strikes occur.
Last winter many Ukrainians had to go without electricity and heating in freezing temperatures as Russia hit Kyiv's energy facilities.
"Difficult months are ahead: Russia will attack energy and critically important facilities," said Oleksiy Kuleba, the deputy head of Kyiv's presidential office.
Ukraine also said that it had struck a military airfield in Moscow-annexed Crimea, a claim denied by Russian-installed authorities.
'Ceilings fell down'
Russia's overnight strikes were deadliest in the southern Kherson, where three people were killed.
In Kyiv's eastern Darnitsky district, frightened residents of a dormitory woke up to their rooms with shattered windows and parked cars outside completely burnt out.
Communities have also adopted new energy solutions to cope with winter blackouts, from generators to shared warming points.
Debris from a downed missile in the capital wounded seven people, including a child.
"God, god, god," Maya Pelyukh, a cleaner who lives in the building, said as she looked at her living room covered in broken glass and debris on her bed.
Her windows and door were blown away, with the 50-year-old saying she crawled out from under a door frame.
Some residents outside were still in dressing gowns as they watched emergency workers put out a fire the authorities said had spread over 400 square meters (4,300 square feet).
In the northeastern city of Kharkiv seamstresses were clearing a damaged clothing factory, with a Russian missile hitting nearby.
"The ceilings fell down. Windows were blown out. There are chunks of the road inside," Yulia Barantsova said, as she cleared a sewing machine from dust and rubble.
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The German economy used to be the envy of the world. What happened?
Germany's Economic Downturn reflects an energy crisis, deindustrialization risks, export weakness, and manufacturing stress, amid Russia gas loss, IMF and EU recession forecasts, and debates over electricity price caps and green transition.
Key Points
An economic contraction from energy price shocks, export weakness, and bottlenecks in manufacturing and digitization.
✅ Energy shock after loss of cheap Russian gas
✅ Exports slump amid China slowdown and weak demand
✅ Policy gridlock on power price cap and permits
Germany went from envy of the world to the worst-performing major developed economy. What happened?
For most of this century, Germany racked up one economic success after another, dominating global markets for high-end products like luxury cars and industrial machinery, selling so much to the rest of the world that half the economy ran on exports.
Jobs were plentiful, the government’s financial coffers grew as other European countries drowned in debt, and books were written about what other countries could learn from Germany.
No longer. Now, Germany is the world’s worst-performing major developed economy, with both the International Monetary Fund and European Union expecting it to shrink this year.
It follows Russia’s invasion of Ukraine and the loss of Moscow’s cheap Russian gas that underpinned industry — an unprecedented shock to Germany’s energy-intensive industries, long the manufacturing powerhouse of Europe.
The sudden underperformance by Europe’s largest economy has set off a wave of criticism, handwringing and debate about the way forward.
Germany risks “deindustrialization” as high energy costs and government inaction on other chronic problems threaten to send new factories and high-paying jobs elsewhere, said Christian Kullmann, CEO of major German chemical company Evonik Industries AG.
From his 21st-floor office in the west German town of Essen, Kullmann points out the symbols of earlier success across the historic Ruhr Valley industrial region: smokestacks from metal plants, giant heaps of waste from now-shuttered coal mines, a massive BP oil refinery and Evonik’s sprawling chemical production facility.
These days, the former mining region, where coal dust once blackened hanging laundry, is a symbol of the energy transition, as the power sector’s balancing act continues with wind turbines and green space.
The loss of cheap Russian natural gas needed to power factories “painfully damaged the business model of the German economy,” Kullmann told The Associated Press. “We’re in a situation where we’re being strongly affected — damaged — by external factors.”
After Russia cut off most of its gas to the European Union, spurring an energy crisis in the 27-nation bloc that had sourced 40% of the fuel from Moscow, the German government asked Evonik to turn to coal by keeping its 1960s coal-fired power plant running a few months longer.
The company is shifting away from the plant — whose 40-story smokestack fuels production of plastics and other goods — to two gas-fired generators that can later run on hydrogen amid plans to become carbon neutral by 2030 and following the nuclear phase-out of recent years.
One hotly debated solution: a government-funded cap on industrial electricity prices to get the economy through the renewable energy transition, amid an energy crisis that even saw a temporary nuclear extension to stabilize supply.
The proposal from Vice Chancellor Robert Habeck of the Greens Party has faced resistance from Chancellor Olaf Scholz, a Social Democrat, and pro-business coalition partner the Free Democrats. Environmentalists say it would only prolong reliance on fossil fuels, while others advocate a nuclear option to meet climate goals.
Kullmann is for it: “It was mistaken political decisions that primarily developed and influenced these high energy costs. And it can’t now be that German industry, German workers should be stuck with the bill.”
The price of gas is roughly double what it was in 2021, with a senior official arguing nuclear would do little to solve that gas issue, hurting companies that need it to keep glass or metal red-hot and molten 24 hours a day to make glass, paper and metal coatings used in buildings and cars.
A second blow came as key trade partner China experiences a slowdown after several decades of strong economic growth.
These outside shocks have exposed cracks in Germany’s foundation that were ignored during years of success, including lagging use of digital technology in government and business and a lengthy process to get badly needed renewable energy projects approved.
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UK must start construction of large-scale storage or fail to meet net zero targets.
UK Hydrogen Storage Caverns enable long-duration, low-carbon electricity balancing, storing surplus wind and solar power as green hydrogen in salt formations to enhance grid reliability, energy security, and net zero resilience by 2035 and 2050.
Key Points
They are salt caverns storing green hydrogen to balance wind and solar, stabilizing a low-carbon UK grid.
✅ Stores surplus wind and solar as green hydrogen in salt caverns
✅ Enables long-duration, low-carbon grid balancing and security
✅ Complements wind and solar; reduces dependence on flexible CCS
The U.K. government must kick-start the construction of large-scale hydrogen storage facilities if it is to meet its pledge that all electricity will come from low-carbon electricity sources by 2035 and reach legally binding net zero targets by 2050, according to a report by the Royal Society.
The report, "Large-scale electricity storage," published Sep. 8, examines a wide variety of ways to store surplus wind and solar generated electricity—including green hydrogen, advanced compressed air energy storage (ACAES), ammonia, and heat—which will be needed when Great Britain's electricity generation is dominated by volatile wind and solar power.
It concludes that large scale electricity storage is essential to mitigate variations in wind and sunshine, particularly long-term variations in the wind, and to keep the nation's lights on. Storing most of the surplus as hydrogen, in salt caverns, would be the cheapest way of doing this.
The report, based on 37 years of weather data, finds that in 2050 up to 100 Terawatt-hours (TWh) of storage will be needed, which would have to be capable of meeting around a quarter of the U.K.'s current annual electricity demand. This would be equivalent to more than 5,000 Dinorwig pumped hydroelectric dams. Storage on this scale, which would require up to 90 clusters of 10 caverns, is not possible with batteries or pumped hydro.
Storage requirements on this scale are not currently foreseen by the government, and the U.K.'s energy transition faces supply delays. Work on constructing these caverns should begin immediately if the government is to have any chance of meeting its net zero targets, the report states.
Sir Chris Llewellyn Smith FRS, lead author of the report, said, "The need for long-term storage has been seriously underestimated. Demand for electricity is expected to double by 2050 with the electrification of heat, transport, and industrial processing, as well as increases in the use of air conditioning, economic growth, and changes in population.
"It will mainly be met by wind and solar generation. They are the cheapest forms of low-carbon electricity generation, but are volatile—wind varies on a decadal timescale, so will have to be complemented by large scale supply from energy storage or other sources."
The only other large-scale low-carbon sources are nuclear power, gas with carbon capture and storage (CCS), and bioenergy without or with CCS (BECCS). While nuclear and gas with CCS are expected to play a role, they are expensive, especially if operated flexibly.
Sir Peter Bruce, vice president of the Royal Society, said, "Ensuring our future electricity supply remains reliable and resilient will be crucial for our future prosperity and well-being. An electricity system with significant wind and solar generation is likely to offer the lowest cost electricity but it is essential to have large-scale energy stores that can be accessed quickly to ensure Great Britain's energy security and sovereignty."
Combining hydrogen with ACAES, or other forms of storage that are more efficient than hydrogen, could lower the average cost of electricity overall, and would lower the required level of wind power and solar supply.
There are currently three hydrogen storage caverns in the U.K., which have been in use since 1972, and the British Geological Survey has identified the geology for ample storage capacity in Cheshire, Wessex and East Yorkshire. Appropriate, novel business models and market structures will be needed to encourage construction of the large number of additional caverns that will be needed, the report says.
Sir Chris observes that, although nuclear, hydro and other sources are likely to play a role, Britain could in principle be powered solely by wind power and solar, supported by hydrogen, and some small-scale storage provided, for example, by batteries, that can respond rapidly and to stabilize the grid. While the cost of electricity would be higher than in the last decade, we anticipate it would be much lower than in 2022, he adds.
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UK net zero policies: What do changes mean?
UK Net Zero Policy Delay shifts EV sales ban to 2035, eases boiler phase-outs, keeps ZEV mandate, backs North Sea oil and gas, accelerates onshore wind and grid upgrades while targeting 2050 emissions goals.
Key Points
Delay moves EV and heating targets to 2035, tweaks mandates, and shifts energy policy, keeping the 2050 net zero goal.
✅ EV sales ban shifts to 2035; ZEV mandate trajectory unchanged
✅ Heat pump grants rise to £7,500; boiler phase-out eased
✅ North Sea oil, onshore wind, grid and nuclear plans advance
British Prime Minister Rishi Sunak has said he would delay targets for changing cars and domestic heating to maintain the consent of the British people in the switch to net zero as part of the global energy transition under way.
Sunak said Britain was still committed to achieving net zero emissions by 2050, similar to Canada's race to net zero goals, and denied watering down its climate targets.
Here are some of the current emissions targets for Britain's top polluting sectors and how the announcement impacts them.
TRANSPORTATION
Transport accounts for more than a third (34%) of Britain's total carbon dioxide (CO2) emissions, the most of any sector.
Sunak announced a delay to introducing a ban on new petrol and diesel cars and vans. It will now come into force in 2035 rather than in 2030.
There were more than 1.1 million electric cars in use on UK roads as of April - up by more than half from the previous year to account for roughly one in every 32 cars, according to the country's auto industry trade body.
The current 2030 target was introduced in November 2020 as a central part of then-Prime Minister Boris Johnson's plans for a "green revolution". As recently as Monday, transport minister Mark Harper restated government support for the policy.
Britain’s independent climate advisers, the Climate Change Committee, estimated a 2030 phase out of petrol, diesel and hybrid vehicles could save up to 110 million tons of carbon dioxide equivalent emissions compared with a 2035 phase out.
ohnson's policy already allowed for the continued sale of hybrid cars and vans that can drive long stretches without emitting carbon until 2035.
The transition is governed by a zero-emission vehicle (ZEV) mandate, a shift echoed by New Zealand's electricity transition debates, which means manufacturers must ensure an increasing proportion of the vehicles they sell in the UK are electric.
The current proposal is for 22% of a car manufacturer's sales to be electric in 2024, rising incrementally each year to 100% in 2035.
The government said on Wednesday that all sales of new cars from 2035 would still be zero emission.
Sunak said that proposals that would govern how many passengers people should have in a car, or proposals for new taxes to discourage flying, would be scrapped.
RESIDENTIAL
Residential emissions, the bulk of which come from heating, make up around 17% of the country's CO2 emissions.
The government has a target to reduce Britain's energy consumption from buildings and industry by 15% by 2030, and had set a target to phase out installing new and replacement gas boilers from 2035, as the UK moves towards heat pumps, amid an IEA report on Canada's power needs noting more electricity will be required.
Sunak said people would have more time to transition, and the government said that off-gas-grid homes could continue to install oil and liquefied petroleum gas boilers until 2035, rather than being phased out from 2026.
However, his announcements that the government would not force anyone to rip out an existing boiler and that people would only have to make the switch when replacing one from 2035 restated existing policy.
He also said there would be an exemption so some households would never have to switch, but the government would increase an upgrade scheme that gives people cash to replace their boilers by 50% to 7,500 pounds ($9,296.25).
Currently almost 80% of British homes are heated by gas boilers. In 2022, 72,000 heat pumps were installed. The government had set a target of 600,000 heat pump installations per year by 2028.
A study for Scottish Power and WWF UK in June found that 6 million homes would need to be better insulated by 2030 to meet the government's target to reduce household energy consumption, but current policies are only expected to deliver 1.1 million.
The study, conducted by Frontier Economics, added that 1.5 million new homes would still need heat pumps installed by 2030.
Sunak said that the government would subsidise people who wanted to make their homes energy efficient but never force a household to do it.
The government also said it was scrapping policies that would force landlords to upgrade the energy efficiency of their properties.
ENERGY
The energy sector itself is a big emitter of greenhouse gases, contributing around a quarter of Britain's emissions, though the UK carbon tax on coal has driven substantial cuts in coal-fired electricity in recent years.
In July, Britain committed to granting hundreds of licences for North Sea oil and gas extraction as part of efforts to become more energy independent.
Sunak said he would not ban new oil and gas in the North Sea, and that future carbon budgets for governments would have to be considered alongside the plans to meet them.
He said the government would shortly bring forward new plans for energy infrastructure to improve Britain's grid, including the UK energy plan, while speeding up planning.
Offshore wind power developers warned earlier this month that Britain's climate goals could be at risk, even as efforts like cleaning up Canada's electricity highlight the importance of power-sector decarbonization, after a subsidy auction for new renewable energy projects did not attract any investment in those planned off British coasts.
Britain is aiming to develop 50 gigawatts (GW) of offshore wind capacity by 2030, up from around 14 GW now.
Sunak highlighted that Britain is lifting a ban on onshore wind, investing in carbon capture and building new nuclear power stations.
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How France aims to discourage buying of Chinese EVs
France EV Bonus Eligibility Rules prioritize lifecycle carbon footprint, manufacturing emissions, battery sourcing, and transport impacts, reshaping electric car incentives and excluding many China-made EVs while aiming for WTO-compliant, low-emission industrial policy.
Key Points
France's EV bonus rules score lifecycle emissions to favor low-carbon models and limit incentives for China-made EVs.
✅ Scores energy, assembly, transport, and battery criteria
✅ Likely excludes China-made EVs with coal-heavy production
✅ Aims to align incentives with WTO-compliant climate goals
France has published new eligibility rules for electric car incentives to exclude EVs made in China, even though carmakers in Europe do not have more affordable rival models on the French market.
WHY IS FRANCE REVISING ITS EV BONUS ELIGIBILITY RULES?
The French government currently offers buyers a cash incentive of between 5,000 and 7,000 euros in cash for eligible models to get more electric cars on the road, at a total cost of 1 billion euros ($1.07 billion) per year.
However, in the absence of cheap European-made EVs, a third of all incentives are going to consumers buying EVs made in China, a French finance ministry source said. The trend has helped spur a Chinese EV push into Europe and a growing competitive gap with domestic producers.
The scheme will be revamped from Dec. 15 to take into account the carbon emitted in a model's manufacturing process.
President Emmanuel Macron and government ministers have made little secret that they want to make sure French state cash is not benefiting Chinese carmakers.
WHAT DO THE NEW RULES DO?
Under the new rules, car models will be scored against government-set thresholds for the amount of energy used to make their materials, in their assembly and transport to market, as well as what type of battery the vehicle has.
Because Chinese industry generally relies heavily on coal-generated electricity, the criteria are likely to put the bonus out of Chinese carmakers' reach.
The government, which is to publish in December the names of models meeting the new standards, says that the criteria are compliant with WTO rules because exemptions are allowed for health and environmental reasons, and similar Canada EV sales regulations are advancing as well.
WILL IT DO ANYTHING?
With Chinese cars estimated to cost 20% less than European-made competitors, the bonus could make a difference for vehicles with a price tag of less than 25,000 euros, amid an accelerating global transition to EVs that is reshaping price expectations.
But French car buyers will have to wait because Stellantis' (STLAM.MI) Slovakia-made e-C3 city car and Renault's (RENA.PA) France-made R5 are not due to hit the market until 2024.
Nonetheless, many EVs made in China will remain competitive even without the cash incentive, reflecting projections that within a decade many drivers could be in EVs.
With a starting price of 30,000 euros, SAIC group's (600104.SS) MG4 will be less expensive than Renault's equivalent Megane compact car, which starts at 38,000 euros - or 33,000 euros with a 5,000-euro incentive.
Since its 46,000-euro starting price is just below the 47,000-euro price threshold for the bonus, Tesla's (TSLA.O) Y model - one of the best selling electric vehicles in France - could in theory also be impacted by the new rules for vehicles made in China.
S&P Global Mobility analyst Lorraine Morard said that even if most Chinese cars are ineligible for the bonus they would probably get 7-8% of France's electric car market next year, even as the EU's EV share continues to rise, instead of 10% otherwise.
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US Dept. of Energy awards Washington state $23.4 million to strengthen infrastructure
Washington Grid Resilience Grant funds DOE-backed modernization to harden Washington's electric grid against extreme weather, advancing clean energy, affordable and reliable electricity, and community resilience under the Bipartisan Infrastructure Law via projects and utility partnerships.
Key Points
A $23.4M DOE grant to modernize Washington's grid, boost weather resilience, and deliver clean, reliable power.
✅ Targets outages, reliability, and community resilience statewide.
✅ Prioritizes disadvantaged areas and quality clean energy jobs.
✅ Backed by Bipartisan Infrastructure Law and DOE funding.
Washington state has received a $23.4 million Grid Resilience State and Tribal Formula Grant from the U.S. Department of Energy (DOE) to modernize the electric grid through smarter electricity infrastructure and reduce impacts due to extreme weather and natural disasters. Grid Resilience State and Tribal Formula Grants aim to ensure the reliability of power sector infrastructure so that communities have access to affordable, reliable, clean electricity.
“Electricity is an essential lifeline for communities. Improving our systems by reducing disruptive events is key as we cross the finish line of a 100% clean electricity grid and ensure equitable benefits from the clean energy economy reach every community,” said Gov. Jay Inslee.
The federal funding for energy resilience will enhance and expand ongoing current grid modernization and resilience efforts throughout the state. For example, working directly with rural and typical end-of-the-line customers to develop resilience plans and collaborating with communities and utilities, including smart city efforts in Spokane as examples, on building resilient and renewable infrastructure for essential services.
“This is a significant opportunity to supplement our state investments in building a robust, resilient electric grid that supports our long-term vision for clean, affordable and reliable electricity – the foundation for economic growth and job creation that strengthens our communities and keeps Washington globally competitive. It shows once again that we are maximizing the federal funding being made available by the Biden-Harris Administration to invest in the country’s infrastructure,” said Washington State Department of Commerce Director Mike Fong.
Across the border, British Columbia's clean energy shift adds regional momentum for resilient, low-carbon power.
Goals include:
Reducing the frequency, duration and impact of outages as climate change impacts on the grid intensify while enhancing resiliency in historically disadvantaged communities.
Strengthening prosperity by expanding well-paying, safe clean energy jobs accessible to all workers and ensuring investments have a positive effect on quality job creation and equitable economic development.
Building a community of practice and maximizing project scalability by identifying pathways for scaling innovations such as integrating solar into the grid across programs.
“The Grid Resilience Formula Grants will enable communities in Washington to protect households and businesses from blackouts or power shutdowns during extreme weather,” said Maria Robinson, Director, Grid Deployment Office, U.S. Department of Energy. “Projects selected through this program will benefit communities by creating good-paying jobs to deliver clean, affordable, and reliable energy across the country.”
DOE has also announced $34 million for grid improvements to bolster reliability nationwide.
“An innovative, reliable, and efficient power grid is vital to Washington’s continued economic growth and for community resilience especially in disadvantaged areas,” said U.S. Rep. Strickland, Co-Lead of the bipartisan Grid Innovation Caucus. “The funding announced today will invest in our energy grid, support good-paying jobs, and means a cleaner, more energy-efficient future.”
Funded through the Bipartisan Infrastructure Law and administered by DOE’s Grid Deployment Office, with related efforts such as California grid upgrades advancing nationwide, the Grid Resilience State and Tribal Formula Grants distribute funding to states, territories, and federally recognized Indian Tribes, over five years based on a formula that includes factors such as population size, land area, probability and severity of disruptive events, and a locality’s historical expenditures on mitigation efforts. Priority will be given to projects that generate the greatest community benefit providing clean, affordable, and reliable energy.
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Texas produces and consumes the most electricity in the US
Texas ERCOT Power Grid leads U.S. wind generation yet faces isolated interconnection, FERC exemption, and high industrial energy use, with distinct electricity and natural gas prices managed by a single balancing authority.
Key Points
The state-run interconnection that balances Texas electricity, isolated from FERC oversight and other U.S. grids.
✅ Largest U.S. wind power producer, high industrial demand
✅ Operates one balancing authority, independent interconnection
✅ Pays lower electricity, higher natural gas vs national average
For nearly two decades, the Lone Star State has generated more wind-sourced electricity than any other state in the U.S., according to the Energy Information Administration, or EIA.
In 2022, EIA reported Texas produced more electricity than any other state and generated twice as much as second-place Florida.
However, Texas also leads the country in another category. According to EIA, Texas is the largest energy-consuming state in the nation across all sectors with more than half of the state’s energy being used by the industrial sector.
As of May 2023, Texas residents paid 43% more for natural gas and around 10% less for electricity compared to the national average, according to EIA, and in competitive areas shopping for electricity is getting cheaper as well. Commercial and industrial sectors on average for the same month paid 25% less for electricity compared to the national average.
U.S. electric system compared to Texas
The U.S. electric system is essentially split into three regions called interconnections and are managed by a total of 74 entities called balancing authorities that ensure that power supply and demand are balanced throughout the region to prevent the possibility of blackouts, according to EIA.
The three regions (Interconnections):
Eastern Interconnection: Covers all U.S. states east of the Rocky Mountains, a portion of northern Texas, and consists of 36 balancing authorities.
Western Interconnection: Covers all U.S. states west of the Rockies and consists of 37 balancing authorities.
ERCOT: Covers the majority of Texas and consists of one balancing authority (itself).
During the 2021 winter storm, Texas electric cooperatives were credited with helping maintain service in many communities.
“ERCOT is unique in that the balancing authority, interconnection, and the regional transmission organization are all the same entity and physical system,” according to EIA, a structure often discussed in analyses of Texas power grid challenges today.
With this being the case, Texas is the only state in the U.S. that balances itself, the only state that is not subject to the jurisdiction of the Federal Energy Regulatory Commission, or FERC, and the only state that is not synchronously interconnected to the grid in the rest of the United States in the event of tight grid conditions, highlighting ongoing discussions about improving Texas grid reliability before peak seasons, according to EIA.
Every other state in the U.S. is connected to a web of multiple balancing authorities that contribute to ensuring power supply and demand are met.
California, for example, was the fourth largest electricity producer and the third largest electricity consumer in the nation in 2022, according to EIA, and California imports the most electricity from other states while Pennsylvania exports the most.
Although California produces significantly less electricity than Texas, it has the ability to connect with more than 10 neighboring balancing authorities within the Western Interconnection to interchange electricity, a dynamic that can see clean states importing dirty electricity under certain market conditions. ERCOT being independent only has electricity interchange with two balancing authorities, one of which is in Mexico.
Regardless of Texas’ unique power structure compared to the rest of the nation, the vast majority of the U.S. risked electricity supplies during this summer’s high heat, as outlined in severe heat blackout risks reports, according to EIA.
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Space-based solar power, once for science fiction, is gaining interest.
Space-Based Solar Power enables wireless energy transfer from orbital solar arrays, using microwave beaming to rectennas on Earth, delivering clean baseload power beyond weather and night limits, as demonstrated by Caltech and NASA.
Key Points
Space-based solar power beams microwaves from arrays to rectennas, delivering clean electricity beyond weather and night.
✅ Caltech demo proved wireless power transfer in space.
✅ Microwaves beam to rectennas for grid-scale clean energy.
✅ Operates above clouds, enabling continuous baseload supply.
Ali Hajimiri thinks there’s a better way to power the planet — one that’s not getting the attention it deserves. The Caltech professor of electrical engineering envisages thousands of solar panels floating in space, unobstructed by clouds and unhindered by day-night cycles, effectively generating electricity from the night sky for continuous delivery, wirelessly transmitting massive amounts of energy to receivers on Earth.
This year, that vision moved closer to reality when Mr. Hajimiri, together with a team of Caltech researchers, proved that wireless power transfer in space was possible: Solar panels they had attached to a Caltech prototype in space successfully converted electricity into microwaves and beamed those microwaves to receivers, as a demonstration of beaming power from space to devices about a foot away, lighting up two LEDs.
The prototype also beamed a tiny but detectable amount of energy to a receiver on top of their lab’s building in Pasadena, Calif. The demonstration marks a first step in the wireless transfer of usable power from space to Earth, and advances in low-cost solar batteries could help store and smooth that power flow — a power source that Mr. Hajimiri believes will be safer than direct sun rays. “The beam intensity is to be kept less than solar intensity on earth,” he said.
Finding alternative energy sources is one of the topics that will be discussed by leaders in business, science and public policy, including wave energy, during The New York Times Climate Forward event on Thursday. The Caltech demonstration was a significant moment in the quest to realize space-based solar power, amid policy moves such as a proposed tenfold increase in U.S. solar that would remake the U.S. electricity system — a clean energy technology that has long been overshadowed by other long-shot clean energy ideas, such as nuclear fusion and low-cost clean hydrogen.
If space-based solar can be made to work on a commercial scale, said Nikolai Joseph, a NASA Goddard Space Flight Center senior technology analyst, and integrate with peer-to-peer energy sharing networks, such stations could contribute as much as 10 percent of global power by 2050.
The idea of space-based solar energy has been around since at least 1941, when the science-fiction writer Isaac Asimov set one of his short stories, “Reason,” on a solar station that beamed energy by microwaves to Earth and other planets.
In the 1970s, when a fivefold increase in oil prices sparked interest in alternative energy, NASA and the Department of Energy conducted the first significant study on the topic. In 1995, under the direction of the physicist John C. Mankins, NASA took another look and concluded that investments in space-launch technology were needed to lower the cost and move closer to cheap abundant electricity before space-based solar power could be realized.
“There was never any doubt about it being technically feasible,” said Mr. Mankins, now president of Artemis Innovation Management Solutions, a technology consulting group. “The cost was too prohibitive.”
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Building begins on facility linking Canada hydropower to NYC
Champlain Hudson Power Express Converter Station brings Canadian hydropower via HVDC to Queens, converting 1,250 MW to AC for New York City's grid, replacing a retired fossil site with a zero-emission, grid-scale clean energy hub.
Key Points
A Queens converter turning 1,250 MW HVDC hydropower into AC for NYC's grid, repurposing an Astoria fossil site.
✅ 340-mile underwater/underground HVDC link from Quebec to Queens
✅ 1,250 MW DC-AC conversion feeding directly into NY grid by 2026
✅ Replaces Astoria oil site; supports NY's 70% renewables by 2030
New York Governor Kathy Hochul has announced the start of construction on the converter station of the Champlain Hudson Power Express transmission line, a project to bring electricity generated from Canadian hydropower to New York City.
The 340 mile (547 km) transmission line is a proposed underwater and underground high-voltage direct current power transmission line to deliver the power from Quebec, Canada, to Queens, New York City. The project is being developed by Montreal-based public utility Hydro-Quebec (QBEC.UL) and its U.S. partner Transmission Developers, while neighboring New Brunswick has signed NB Power deals to bring more Quebec electricity into the province.
The converter station for the line will be the first-ever transformation of a fossil fuel site into a grid-scale zero-emission facility in New York City, its backers say.
Workers have already removed six tanks that previously stored 12 million gallons (45.4 million liters) of heavy oil for burning in power plants and nearly four miles (6.44 km) of piping from the site in the Astoria, Queens neighborhood, echoing Hydro-Quebec's push to wean the province off fossil fuels as regional power systems decarbonize.
The facility is expected to begin operating in 2026, even as the Ontario-Quebec power deal was not renewed elsewhere in the region. Once the construction is completed, it will convert 1,250 megawatts of energy from direct current to alternating current power that will be fed directly into the state's power grid, helping address transmission constraints that have impeded incremental Quebec-to-U.S. power deliveries.
“Renewable energy plays a critical role in the transformation of our power grid while creating a cleaner environment for our future generations,” Hochul said. The converter station is a step towards New York’s target for 70% of the state’s electricity to come from renewable sources by 2030, as neighboring Quebec has closed the door on nuclear power and continues to lean on hydropower.
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California's future with income-based flat-fee utility bills is getting closer
California Income-Based Utility Fees would overhaul electricity bills as CPUC weighs fixed charges tied to income, grid maintenance costs, AB 205 changes, and per-kilowatt-hour rates, shifting from pure usage pricing to hybrid utility rate design.
Key Points
Income-based utility fees are fixed monthly charges tied to earnings, alongside per-kWh rates, to help fund grid costs.
✅ CPUC considers fixed charges by income under AB 205
✅ Separates grid costs from per-kWh energy charges
✅ Could shift rooftop solar and EV charging economics
Electricity bills in California are likely to change dramatically in 2026, with major changes under discussion statewide.
The California Public Utilities Commission (CPUC) is in the midst of an unprecedented overhaul of the way most of the state’s residents pay for electricity, as it considers revamping electricity rates to meet grid and climate goals.
Utility bills currently rely on a use-more pay-more system, where bills are directly tied to how much electricity a resident consumes, a setup that helps explain why prices are soaring for many households.
California lawmakers are asking regulators to take a different approach, and some are preparing to crack down on utility spending as oversight intensifies. Some of the bill will pay for the kilowatt hours a customer uses and a monthly fixed fee will help pay for expenses to maintain the electric grid: the poles, the substations, the batteries, and the wires that bring power to people’s homes.
The adjustments to the state’s public utility code, section 739.9, came about because of changes written into a sweeping energy bill passed last summer, AB 205, though some lawmakers now aim to overturn income-based charges in subsequent measures.
A stroke of a pen, a legislative vote, and the governor’s signature created a move toward unprecedented income-based fixed charges across the state.
“This was put in at the last minute,” said Ahmad Faruqui, a California economist with a long professional background in utility rates. “Nobody even knew it was happening. It was not debated on the floor of the assembly where it was supposedly passed. Of course, the governor signed it.”
Faruqui wonders who was responsible for legislation that was added to the energy bill during the budget writing process. That process is not transparent.
“It’s a very small clause in a very long bill, which is mostly about other issues,” Faruqui said.
But that small adjustment could have a massive impact on California residents, because it links the size of a monthly flat fee for utility service to a resident’s income. Earn more money and pay a higher flat fee.
That fee must be paid even before customers are charged for how much power they draw.
Regulators interpreted legislative change as a mandate, but Faruqui is not sold.
“They said the commission may consider or should consider,” Faruqui said. “They didn’t mandate it. It’s worth re-reading it.”
In fact, the legislative language says the commission “may” adopt income-based flat fees for utilities. It does not say the commission “should” adopt them.
Nevertheless, the CPUC has already requested and received nine proposals for how a flat fee should be implemented, as regulators face calls for action amid soaring electricity bills.
The suggestions came from consumer groups, environmentalists, the solar industry and utilities.
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'For now, we're not touching it': Quebec closes door on nuclear power
Quebec Energy Strategy focuses on hydropower, energy efficiency, and new dams as Hydro-Qu e9bec pursues Churchill Falls deals and the Champlain Hudson Power Express to New York, while nuclear power remains off the agenda.
Key Points
Quebec's plan prioritizes hydropower, efficiency, and new dams, excludes nuclear, and expands exports via CHPE.
✅ Nuclear power shelved; focus on renewables and dams
✅ Hydro-Qu e9bec pursues Churchill Falls and Gull Island talks
✅ CHPE line to New York advances; export contract with NYSERDA
Quebec Premier François Legault has closed the door on nuclear power, at least for now.
"For the time being, we're not touching it," said Legault when asked about the subject at a press scrum in New York on Tuesday.
The government is looking for new sources of energy as Hydro-Québec begins talks on a $185-billion strategy to wean the province off fossil fuels. In an interview with The Canadian Press at Quebec's official residence in New York, Legault said there are a number of avenues to explore:
- Energy efficiency.
- Negotiations with Newfoundland and Labrador over Churchill Falls and Gull Island.
- Upgrading existing dams and building new ones.
"Nuclear power is not on the agenda," he said.
Yet the premier seemed open to the nuclear question some time ago. In August, Radio-Canada reported that he had raised the idea of nuclear power in front of dozens of MNAs at the National Assembly last April.
Also in August, Hydro-Québec was evaluating the possibility of reopening the Gentilly-2 nuclear power plant, which has been closed since 2012.
Asked about his leader's statement on Tuesday, the Minister of the Economy, Pierre Fitzgibbon, maintained his line: "At the moment, we're looking at everything that's possible because we know that we have a significant deficit in the supply of green energy," he said.
Another step forward for the Quebec-New York line
Premier Legault took part in Tuesday morning's announcement that construction had begun on the New York converter station of the Champlain Hudson Power Express line. New York State Governor Kathy Hochul was present at the announcement.
In November 2021, Hydro-Québec signed a contract with the New York State Energy Research and Development Authority (NYSERDA) to export 10.4 terawatt-hours of electricity to the American metropolis over 25 years, while Ontario declined to renew a deal with Quebec.
At a time when the Quebec government is constantly asserting that more energy will be needed for future economic projects -- particularly the battery industry -- Legault sees no contradiction in selling electricity to the Americans and to neighboring provinces such as NB Power deals to import Hydro-Québec power.
"Whether it's this contract or the contract for companies coming to set up in Quebec, it's out of the surplus we currently have in Quebec. Now, we have dozens of investment project proposals in Quebec where we need additional electricity," he explained.
The line will supply 20 per cent of New York City's electricity needs, despite transmission constraints on Quebec-to-U.S. deliveries. Commissioning is scheduled for May 2026. The spin-offs are estimated at $30 billion, according to the premier.
Will this money be used to finance new dams, such as the La Romaine hydroelectric complex built in recent years?
"It's certain that future projects will cost several tens of billions of dollars. Hydro-Québec has the capacity to borrow. It's a very healthy company. There's no doubt that these revenues will improve Hydro-Québec's image," he said.
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5,000 homes would be switched to geothermal energy free of charge
Manitoba NDP Geothermal Conversion Program offers full-cost heat pump installation for 5,000 homes, lowering electricity bills, funding contractor training and rebates, and cutting greenhouse gas emissions via geothermal energy administered by Efficiency Manitoba.
Key Points
A plan funding 5,000 home heat pump conversions to cut electricity bills, reduce emissions, and expand installer capacity.
✅ Covers equipment and installation for 5,000 homes
✅ Cuts electricity bills up to 50% vs electric heat
✅ Administered by Efficiency Manitoba; trains contractors
An NDP government would cover the entire cost for 5,000 families to switch their homes to geothermal energy, New Democrats have promised.
If elected on Oct. 3, the NDP will pay for the equipment and installation of new geothermal systems at 5,000 homes, St. James candidate Adrien Sala announced outside a St. Boniface home that previously made the switch.
The homes that switch to geothermal energy could save as much as 50 per cent on their electricity bills, Sala said.
"It will save you money, it will grow our economy and it will reduce greenhouse gas emissions. And I think we can safely call that a win, win, win," Sala said.
Geothermal energy is derived from heat that is generated within the Earth.
The NDP said each conversion to geothermal heating and cooling would cost an estimated $26,000, and comes as new turbine investments advance in Manitoba, and it would take four years to complete all 5,000 conversions.
The program would be administered through Efficiency Manitoba, the Crown corporation responsible for conserving energy, as Manitoba Hydro's new president navigates changes at the utility. The NDP estimates it will cost $32.5 million annually over the four years, at a time of red ink at Manitoba Hydro as new power generation needs loom. Some of that money would support the training of more contractors who could install geothermal systems.
Subsidies get low pickup: NDP
Sala wouldn't say Wednesday which homeowners or types of homes would be eligible.
He said the NDP's plan would be a first in Canada, even as Ontario's energy plan seeks to address growing demand elsewhere.
"What we've seen elsewhere is where other jurisdictions have used a strict subsidy model, where they try to reduce the cost of geothermal, and while Ontario reviews a halt to natural gas generation to cut emissions, approaches differ across provinces. We really haven't seen a lot of uptake in those other jurisdictions," Sala said.
"This is an attempt at dealing with one of those key barriers for homeowners."
Efficiency Manitoba runs a subsidy program for geothermal energy through ground source heat pumps, supporting using more electricity for heat across the province, valued at up to $2.50 per square foot. It is estimated a 1,600 sq. ft. home switching from an electric furnace to geothermal will receive a rebate of around $4,000 and save around $900 annually on their electricity bills, the Crown corporation said.anitoba homeProgressive Conservative spokesperson Shannon Martin questioned how NDP Leader Wab Kinew can afford his party's numerous election promises.
"He will have no choice but to raise taxes, and history shows the NDP will raise them all," said Martin, the McPhillips MLA who isn't seeking re-election.
Wednesday's announcement was the first for the NDP in which Kinew wasn't present. The party has criticized the Progressive Conservatives for leader Heather Stefanson showing up for only a few announcements a week.
Sala said Kinew was busy preparing for the debate later in the day.
"This stuff is near and dear to Wab's heart, and frankly, I think he's probably hurting that he's not here with us right now."
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0 to 180 km in 10 minutes: B.C. Hydro rolls out faster electric vehicle charging
B.C. Hydro fast EV charging stations roll out 180 kW DC fast chargers, power sharing, and rural network expansion in Surrey, Manning Park, Mackenzie, and Tumbler Ridge to ease range anxiety across northern B.C.
Key Points
180 kW DC chargers with power sharing, expanding B.C.'s rural EV network to cut range anxiety and speed up recharging.
✅ 180 kW DC fast charging: ~180 km added in about 10 minutes
✅ Power sharing enables two vehicles to use one unit simultaneously
✅ Expands rural charging coverage to cut range anxiety for northern B.C.
B.C. Hydro has unveiled plans to install new charging stations it says can add as much as 180 kilometres worth of range to the average electric vehicle in 10 minutes.
The utility says the new 180-kilowatt units will be added to its network, expanding stations in southern B.C. as soon as this fall, with even more scheduled to arrive in 2024.
The first communities to get the new faster-charge stations are Surrey, Manning Park and, north of Prince George, Mackenzie and Tumbler Ridge, while the Lillooet fast-charging site is already operational.
B.C. Hydro president Chris O'Riley says both current and prospective electric vehicle owners have said they want improved coverage in more rural parts of the province in order to address range anxiety, as the utility has warned of a potential EV charging bottleneck if demand outpaces infrastructure.
"We are listening to feedback from our customers," he said.
The new stations will also be the first from B.C. Hydro to offer power sharing, which lets two different vehicles use the same unit to charge at the same time.
The adoption of electric vehicles in B.C. is much higher in southern urban areas than rural, northern ones, according to statistics from the provincial government made available in 2022, as the province leads the country in going electric according to recent reports.
The figures showed about one in every 45 people owns a zero-emission vehicle in the southwest regions of the province, but that number drops to one in 232 in the Kootenays, where the region makes electric cars a priority through local initiatives, and one in 414 in northern B.C.
The number of public charging stations closely corresponds to the number of zero-emission vehicles in various regions.
The Vancouver area has more than 500 fast-charging ports, according to ChargeHub, a website that tracks charging stations in North America.
In contrast, the route from Prince George to Fort Nelson via Dawson Creek along Highway 97, part of the B.C. Electric Highway network connecting the region — a distance of more than 800 kilometres — has just three locations where a vehicle can be charged to 80 per cent power in an hour or less, creating challenges for people hoping to travel the route.
The disparity is also clear in a just-published analysis from the non-profit Community Energy Association, which acts as an advisory group to government associations.
It found that while there is roughly one charging port every three square kilometres in Metro Vancouver, the number drops to one every 250 square kilometres in the Regional District of East Kootenay and one every 3,500 square kilometres in the Peace River Regional District, in the province's northeast.
"The more infrastructure we can get across the region ... the more the adoption of electric vehicles will increase," said the association's director of transportation initiatives, Danielle Weiss.
"We are excited to hear that B.C. Hydro is also viewing rural areas as a key focus for their new, enhanced charging technology."
B.C. Hydro says it currently has 153 charging units at 84 locations across the province with plans to add an additional 3,000 ports over the next 10 years, with provincial EV charger rebates supporting home and workplace installations as well.
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Battery energy storage system eyed near Woodstock
Oxford Battery Energy Storage Project will store surplus renewable power near South-West Oxford and Woodstock, improving grid stability, peak shaving, and reliability, pending IESO approval and Hydro One transmission interconnection in Ontario.
Key Points
A Boralex battery project in South-West Oxford storing surplus power for Woodstock at peak demand pending IESO approval.
✅ 2028 commercial operation target
✅ Connects to Hydro One transmission line
✅ Peak shaving to stabilize grid costs
A Quebec-based renewable energy company is proposing to build a battery energy storage system in Oxford County near Woodstock.
The Oxford battery energy storage project put forward by Boralex Inc., if granted approval, would be ready for commercial operation in 2028. The facility would be in the Township of South-West Oxford, but also would serve Woodstock businesses and residences, supported by provincial disconnect moratoriums for customers, due to the city’s proximity to the site.
Battery storage systems charge when energy sources produce more energy than customers need, and, complementing Ontario’s energy-efficiency programs across the province, discharge during peak demand to provide a reliable, steady supply of energy.
Darren Suarez, Boralex’s vice-president of public affairs and communications in North America, said, “The system we’re talking about is a very large battery that will help at times when the electric grid has too much energy on the system. We’ll be able to charge our batteries, and when there’s a need, we can discharge the batteries to match the needs of the electric grid.”
South-West Oxford is a region Boralex has pinpointed for a battery storage project. “We look at grid needs as a whole, and where there is a need for battery storage, and we’ve identified this location as being a real positive for the grid, to help with its stability, a priority underscored by the province’s nuclear alert investigation and public safety focus,” Suarez said.
Suarez could not provide an estimated cost for the proposed facility but said the project would add about 75 jobs during the construction phase, in a sector where the OPG credit rating remains stable. Once the site is operational, only one or two employees will be necessary to maintain the facility, he said.
Boralex requires approval from the Independent Electricity System Operator (IESO), the corporation that co-ordinates and integrates Ontario’s electricity system operations across the province, for the Oxford battery energy storage project.
Upon approval, the project will connect with an existing Hydro One transmission line located north of the proposed site. “[Hydro One] has a process to review the project and review the location and ensure we are following safety standards and protocols in terms of integrating the project into the grid, with broader policy considerations like Ottawa’s hydro heritage also in view, but they are not directly involved in the development of the project itself,” Suarez said.
The proposal has been presented to South-West Oxford council. South-West Oxford Mayor David Mayberry said, “(Council) is still waiting to see what permits are necessary to be addressed if the proposal moves forward.”
Mayberry said the Ministry of Natural Resources and Forestry also would be reviewing the proposed project.
Thornton Sand and Gravel, the location of the proposed facility, was viewed positively by Mayberry. “From a positive perspective, they’re not using farmland. There is a plus we’re not using farmland, but there is concern something could leak into the aquifer. These questions need to be answered before it can be to the satisfaction of the community,” Mayberry said.
An open house was held on Sept. 14 to provide information to residents. Suarez said about 50 people showed up and the response was positive. “Many people came out to see what we planned for the project and there was a lot of support for the location because of where it actually is, and how it integrates into the community. It’s considered good use of the land by many of the people that were able to join us on that day,” Suarez said.
The Quebec-based energy company has been operating in Ontario for nearly 15 years and has wind farms in the Niagara and Chatham-Kent regions.
Boralex also is involved in two other battery storage projects in Ontario. The Hagersville project is a 40-minute drive northwest of Hamilton, and the other is in Tilbury, a community in Chatham-Kent. Commercial operation for both sites is planned to begin in 2025.
South-West Oxford and Woodstock will see some financial benefits from the energy storage system, Suarez said.
“It will help to stabilize energy costs. It will contribute to really shaving the most expensive energy on the system off the system. They’re going to take electricity when it’s the least costly, taking advantage of Ontario’s ultra-low overnight pricing options and utilize that least costly energy and displace the most costly energy.”
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Hydro One launches Ultra-Low Overnight Electricity Price Plan
Ultra-Low Overnight Price Plan delivers flexible electricity pricing from Hydro One and the Ontario Energy Board, with TOU, tiered options, off-peak EV charging savings, balanced billing, and an online calculator to optimize bills.
Key Points
An Ontario pricing option with ultra-low night rates, helping Hydro One customers save by shifting usage to off-peak.
✅ Four periods with ultra-low overnight rate for EV charging
✅ Compare TOU vs tiered with Hydro One's online calculator
✅ Balanced billing and due date choice support budget control
Hydro One has announced that customers have even more choice and flexibility when it comes to how they are billed for electricity with the company's launch of the Ontario Energy Board's new Ultra-Low Overnight Electricity Price Plan for customers. A new survey of Ontario customers, conducted by Innovative Research Group, shows that 74 per cent of Ontarians find having choice between electricity pricing plans useful.
"As their trusted energy advisor, we want our customers to know we have the insights and tools to help them make the right choice when it comes to their electricity plans," said Teri French, Executive Vice President, Safety, Operations and Customer Experience. "We know that choice and flexibility are important to our customers, and we are proud to now offer them a third option so they can select the plan that best fits their lifestyle."
The same survey revealed that fewer than half of Ontarians are familiar with either tiered or the new ultra-low overnight price plans. To better support its customers Hydro One is providing an online calculator to help them choose which pricing plan best suits their lifestyle. The company also offers additional flexibility and assistance in managing household budgets by providing customers with the ability to choose their billing due date and flatten usage spikes from temperature fluctuations through balanced billing.
During the pandemic, Ontario introduced electricity relief to support families, small businesses and farms, complementing these customer options.
"By offering families and small businesses more choice, we are putting them back in control of their energy bills," said Todd Smith, Minister of Energy. "Starting today Hydro One customers have a new option - the Ultra-Low Electricity Price Plan - which could help them save money each year, while making our province's grid more efficient."
Electricity price plan options
- New Ultra-Low Overnight price plan (ULO): Designed for customers who use more electricity at night, such as those who charge their electric vehicle, this new price plan can help customers keep costs down and take control of their electricity bill by shifting usage to the ultra-low overnight price period and related off-peak electricity rates when province-wide electricity demand is lower.
- This plan has four price periods that are the same in the summer as they are in the winter and includes an ultra-low overnight rate.
- Time-of-Use price plan (TOU): TOU provides customers with more control over their electricity bill by adjusting their usage habits with time-of-use rates used in other jurisdictions as well.
- In this plan, electricity prices change throughout each weekday, when demand is on-peak, and peak hydro rates can affect overall costs.
- Tiered price plan (RPP): Tiered pricing provides customers with the flexibility to use electricity at any time of day at the same low price up until the threshold is exceeded during the month, after that usage is charged at a higher price.
- For residential customers, the winter period (November 1 – April 30) threshold is 1,000 kWh per month and the summer period (May 1 – October 31) threshold is 600 kWh per month.
- For small business customers, the threshold is 750 kWh throughout the year, while broader stable electricity pricing supports industrial and commercial companies.
