54 new reactors under construction worldwide

Global Energy Electrification drives IEA targets as smart grids, storage, EVs, and demand-side management scale. Paris Agreement-aligned policies and innovation accelerate decarbonization, enabling flexible, low-carbon power systems and net-zero pathways by 2060.

Key Points

A shift to electricity across sectors via smart grids, storage, EVs, and policy to cut CO2 and improve energy security.

✅ Smart grids, storage, DSM enable flexible, resilient power.

✅ Aligns with IEA pathways and Paris Agreement goals.

✅ Drives EV adoption, building efficiency, and net-zero by 2060.

The global energy system is changing, with European electricity market trends highlighting rapid shifts. More people are connecting to the grid as living standards improve around the world. Demand for consumer appliances and electronic devices is rising. New and innovative transportation technologies, such as electric vehicles and autonomous cars are also boosting power demand.

The International Energy Agency's latest report on energy technologies outlines how these and other trends as well as technological advances play out in the next four decades to reshape the global energy sector.

Energy Technology Perspectives 2017 (ETP) highlights that decisive policy actions and market signals will be needed to drive technological development and benefit from higher electrification around the world. Investments in stronger and smarter infrastructure, including transmission capacity, storage capacity and demand side management technologies such as demand response programs are necessary to build efficient, low-carbon, integrated, flexible and robust energy system. 

Still, current government policies are not sufficient to achieve long-term global climate goals, according to the IEA analysis, and warnings about falling global energy investment suggest potential supply risks as well. Only 3 out of 26 assessed technologies remain “on track” to meet climate objectives, according to the ETP’s Tracking Clean Energy Progress report. Where policies have provided clean signals, progress has been substantial. However, many technology areas suffer from inadequate policy support. 

"As costs decline, we will need a sustained focus on all energy technologies to reach long-term climate targets," said IEA Executive Director Dr Fatih Birol. "Some are progressing, but too few are on track, and this puts pressure on others. It is important to remember that speeding the rate of technological progress can help strengthen economies, boost energy security while also improving energy sustainability."

ETP 2017’s base case scenario, known as the Reference Technology Scenario (RTS), takes into account existing energy and climate commitments, including those made under the Paris Agreement. Another scenario, called 2DS, shows a pathway to limit the rise of global temperature to 2ºC, and finds the global power sector could reach net-zero CO2 emissions by 2060.

A second decarbonisation scenario explores how much available technologies and those in the innovation pipeline could be pushed to put the energy sector on a trajectory beyond 2DS. It shows how the energy sector could become carbon neutral by 2060 if known technology innovations were pushed to the limit. But to do so would require an unprecedented level of policy action and effort from all stakeholders.

Looking at specific sectors, ETP 2017 finds that buildings could play a major role in supporting the energy system transformation. High-efficiency lighting, cooling and appliances could save nearly three-quarters of today’s global electricity demand between now and 2030 if deployed quickly. Doing so would allow a greater electrification of the energy system that would not add burdens on the system. In the transportation system, electrification also emerges as a major low-carbon pathway, with clean grids and batteries becoming key areas to watch in deployment.

The report finds that regardless of the pathway chosen, policies to support energy technology innovation at all stages, from research to full deployment, alongside evolving utility trends that operators need to watch, will be critical to reap energy security, environmental and economic benefits of energy system transformations. It also suggests that the most important challenge for energy policy makers will be to move away from a siloed perspective towards one that enables systems integration.

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EV Firefighter Cancer Risks: lithium-ion battery fires, toxic metals like nickel and chromium, hazardous smoke plumes, and prolonged exposure threaten first responders; SCBA use, decontamination, and evidence-based protocols help reduce occupational health impacts.

Key Points

Health hazards from EV battery fires exposing responders to toxic metals and smoke, elevating long-term cancer risk.

✅ Nickel and chromium in EV smoke linked to lung and sinus cancers

✅ Use SCBA, on-scene decon, and post-incident cleaning to cut exposure

✅ Adopt EV fire SOPs: cooling, monitoring, isolation, air monitoring

As electric vehicles (EVs) become more popular, the EV fire risks to firefighters are becoming an increasing concern. These fires, fueled by the high-capacity lithium-ion batteries in EVs, produce dangerous chemical exposures that could have serious long-term health implications for first responders.

Claudine Buzzo, a firefighter and cancer survivor, knows firsthand the dangers that come with the profession. She’s faced personal health battles, including rare pancreatic cancer and breast cancer, both of which she attributes to the hazards of firefighting. Now, as EV adoption increases and some research links adoption to fewer asthma-related ER visits in local communities, Buzzo and her colleagues are concerned about how EV fires might add to their already heavy exposure to harmful chemicals.

The fire risks associated with EVs are different from those of traditional gasoline-powered vehicles. Dr. Alberto Caban-Martinez, who is leading a study at the Sylvester Comprehensive Cancer Center, explains that the high concentrations of metals released in the smoke from an EV fire are linked to various cancers. For instance, nickel, a key component in EV batteries, is associated with lung, nasal, and laryngeal cancers, while chromium, another metal found in some EV batteries, is linked to lung and sinus cancers.

Research from the Firefighter Cancer Initiative indicates that the plume of smoke from an EV fire contains significantly higher concentrations of these metals than fires from traditional vehicles. This raises the risk of long-term health problems for firefighters who respond to such incidents.

While the Electric Vehicle Association acknowledges the risks associated with various types of vehicle fires, they maintain that the lithium-ion batteries in EVs may not present a significantly higher risk than other common fire hazards, even as broader assessments suggest EVs are not a silver bullet for climate goals. Nonetheless, the growing body of research is causing concern among health experts, urging for further studies into how these new types of fires could affect firefighter health and how upstream electricity generation, where 18% of electricity in 2019 came from fossil fuels in Canada, factors into overall risk perceptions.

Fire departments and health researchers are working to understand the full scope of these risks and are emphasizing the importance of protective gear, such as self-contained breathing apparatuses, to minimize exposure during EV fire responses, while also considering questions like grid impacts during charging operations and EV sustainability improvements in different regions.

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Snohomish PUD rate increase addresses storm recovery after a bomb cyclone and extended cold snap, stabilizing finances and grid reliability while offering assistance programs, payment plans, and energy efficiency for customers.

Key Points

Temp 5.8% residential hike in Feb 2025 to recover storm costs, meet cold snap demand, and uphold reliable service.

✅ 5.8% residential increase effective Feb 2025

✅ Driven by bomb cyclone damage and cold snap demand

✅ Aid includes payment plans, efficiency rebates, low income support

In early February 2025, the Snohomish County Public Utility District (PUD) announced a temporary increase in electricity rates to offset the financial impact of severe weather events, including a bomb cyclone and an extended cold snap, that occurred in late 2024. This decision aims to stabilize the utility's finances, a pattern seen at other utilities such as Florida Power & Light, which pursued a hurricane surcharge to recover storm costs, while ensuring continued service reliability for its customers.

Background of the Weather Events

In November 2024, the Pacific Northwest experienced a powerful bomb cyclone—a rapidly intensifying storm characterized by a significant drop in atmospheric pressure. This event brought heavy rainfall, strong winds, and widespread power outages across the region. Compounding the situation, a prolonged cold weather period in December 2024 and January 2025 led to increased energy demand, and similar conditions drove up Pennsylvania power rates in the same winter season, as residents and businesses relied heavily on heating systems.

Impact on Snohomish PUD

The combination of the bomb cyclone and the subsequent cold weather placed considerable strain on the Snohomish PUD's infrastructure and financial resources. The utility incurred substantial costs for emergency repairs, restoration efforts, and the procurement of additional electricity to meet the heightened demand during the cold snap. These unforeseen expenses prompted the PUD to seek a temporary rate adjustment to maintain financial stability and continue providing reliable service to its customers.

Details of the Rate Increase

Effective February 2025, the Snohomish PUD implemented a temporary electricity rate increase of 5.8% for residential customers, compared with a 3% BC Hydro increase in the same region for context. This adjustment is designed to recover the additional costs incurred during the severe weather events. The PUD has communicated that this rate increase is temporary and will be reevaluated after a specified period to determine if further adjustments are necessary.

Customer Impact and Assistance Programs

While the rate increase is intended to be temporary, it may still pose a financial burden for some customers, even as some markets expect rates to stabilize in 2025 in other jurisdictions. To mitigate this impact, the Snohomish PUD has outlined several assistance programs:

• Payment Plans: Customers facing financial hardship can enroll in extended payment plans to spread the cost of the increased rates over a longer period.

• Energy Efficiency Programs: The PUD offers incentives and resources to help customers reduce energy consumption, potentially lowering their overall bills.

• Low-Income Assistance: Eligible low-income customers may qualify for additional support through state and federal assistance programs.

The utility encourages customers to contact their customer service department to explore these options and find the best solutions for their individual circumstances.

Community Response and Future Considerations

The announcement of the rate increase has elicited mixed reactions from the community. Some residents express understanding, recognizing the necessity of maintaining infrastructure and service reliability. Others have voiced concerns about the financial impact, particularly among vulnerable populations, a debate also seen with higher BC Hydro rates in nearby British Columbia.

Looking ahead, the Snohomish PUD is committed to enhancing its infrastructure to better withstand future extreme weather events, an approach aligned with other utilities' multi-year rate proposals to fund upgrades. This includes investing in grid modernization, implementing advanced weather forecasting tools, and developing comprehensive emergency response plans. The utility also plans to engage with the community through public forums and surveys to gather feedback and collaboratively develop strategies that balance financial sustainability with customer affordability.

The temporary electricity rate increase by the Snohomish County Public Utility District reflects the financial challenges posed by severe weather events and parallels regional trends, including BC Hydro's 3.75% over two years adjustments, and underscores the importance of proactive infrastructure investment and community engagement. While the rate adjustment aims to stabilize the utility's finances, the PUD remains focused on supporting its customers through assistance programs and ongoing efforts to enhance service reliability and resilience against future climate-related events.

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Turkey Net Metering Suspension freezes regulator reviews, stalling rooftop solar permits and grid interconnections amid COVID-19, pausing licensing workflows, EPC pipelines, and electricity bill credits that drive commercial and household prosumer adoption.

Key Points

A pause on technical reviews freezing net metering applications and slowing rooftop solar deployment in Turkey.

✅ Monthly technical committee meetings suspended indefinitely

✅ Rooftop solar permits and grid interconnections on hold

✅ EPC firms urge remote evaluations for transparency

The decision by the Turkish Energy Market Regulatory Authority to halt part of the system of processing net metering applications risks bringing the only vibrant segment of the nation’s solar industry to a grinding halt, a risk amplified as global renewables face Covid-19 disruptions across markets.

The regulator has suspended monthly meetings of the committee which makes technical evaluations of net metering applications, citing concerns about the spread of Covid-19, which has already seen U.S. utility-scale solar face delays this year.

The availability of electricity bill credits for net-metering-approved households which inject surplus power into the grid, similar to how British households can sell power back to energy firms, has seen the rooftop projects the scheme is typically associated with remain the only source of new solar generation capacity in Turkey of late.

However the energy regulator’s decision to suspend technical evaluation committee meetings until further notice has seen the largely online licensing process for new solar systems practically cease; by contrast, Berlin is being urged to remove PV barriers to keep projects moving.

The Turkish solar industry has claimed the move is unnecessary, with solar engineering, procurement and construction services businesses pointing out the committee could meet to evaluate projects remotely. It has been argued such a move would streamline the application process and make it more transparent, regardless of the current public health crisis.

Net metering 

Turkey introduced net metering for rooftop installations last May and pv magazine has reported the specifics of the scheme, amid debates like New England's grid upgrade costs over who pays.

National grid operator Teias confirmed recently the country added 109 MW of new solar capacity in the first quarter, most of it net-metered rooftop systems, even as Australian distributors warn excess solar can strain local networks.

Net metering has been particularly attractive to commercial electricity users because the owners of small and medium-sized businesses pay more for power, as solar reshapes electricity prices in Northern Europe, than either households or large scale industrial consumers.

Until the recent technical committee decision by the regulator, the chief obstacle to net metering adoption had been the nation’s economic travails. The Turkish lira has lost 14% of its value since January and around 36% over the last two years. The central bank has been using its foreign reserves to support state lenders and the lira but the national currency slipped near an all-time low on Friday and foreign analysts predict the central bank reserves could run dry in July.

The level of exports shipped last month was down 41% on April last year and imports fell 28% by the same comparison, further depressing the willingness of companies to make capital investments such as rooftop solar.

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Nova Scotia Power Rate Increase Settlement faces UARB scrutiny as regulators weigh electricity rates, fuel costs, storm rider provisions, Bill 212 limits, and Muskrat Falls impacts on ratepayers and affordability for residential and industrial customers.

Key Points

A deal proposing 13.8% electricity hikes for 2023-2024, before the UARB, covering fuel costs, a storm rider, and Bill 212.

✅ UARB review may set different rates than the settlement

✅ Fuel cost prepayment and hedging incentives questioned

✅ Storm rider shifts climate risk onto ratepayers

Nova Scotia Premier Tim Houston is calling on provincial regulators to reject a settlement agreement between Nova Scotia Power and customer groups that would see electricity rates rise by nearly 14% electricity rate hike over the next two years.

"It is our shared responsibility to protect ratepayers and I can't state strongly enough how concerned I am that the agreement before you does not do that," Houston wrote in a letter to the Nova Scotia Utility and Review Board late Monday.

Houston urged the three-member panel to "set the agreement aside and reach its own conclusion on the aforementioned application."

"I do not believe, based on what I know, that the proposed agreement is in the best interest of ratepayers," he said.

The letter does not spell out what his Progressive Conservative government would do if the board accepts the settlement reached last week between Nova Scotia Power and lawyers representing residential, small business and large industrial customer classes.

Other groups also endorsed the deal, although Nova Scotia Power's biggest customer — Port Hawkesbury Paper — did not sign on.

'We're protecting the ratepayers'
Natural Resources Minister Tory Rushton said the province was not part of the negotiations leading up to the settlement.

"As a government or department we had no intel on those conversations that were taking place," he said Tuesday. "So, we saw the information the same as the public did late last week, and right now we're protecting the ratepayers of Nova Scotia, even though the province cannot order Nova Scotia Power to lower rates under current law. We want to make sure that that voice is still heard at the UARB level."

Rushton said he didn't want to presuppose what the UARB will say.

"But I think the premier's been very loud and clear and I believe I have been, too. The ratepayers are at the top of our mind. We have different tools at our [disposal] and we'll certainly do what we can and need to [do] to protect those ratepayers."

The settlement agreement
If approved by regulators, rates would rise by 6.9 per cent in 2023 and 6.9 per cent in 2024 — almost the same amount on the table when hearings before the review board ended in September.

The Houston government later intervened with legislation, known as Bill 212, that capped rates to cover non-fuel costs by 1.8 per cent. It did not cap rates to cover fuel costs or energy efficiency programs.

In a statement announcing the agreement, Nova Scotia Power president Peter Gregg claimed the settlement adhered "to the direction provided by the provincial government through Bill 212."

Consumer advocate Bill Mahody, representing residential customers, told CBC News the proposed 13.8 per cent increase was "a reasonable rate increase given the revenue requirement that was testified to at the hearing."

Settlement 'remarkably' similar to NSP application
The premier disagrees, noting that the settlement and rate application that triggered the rate cap are "remarkably consistent."

He objects to the increased amount of fuel costs rolled into rates next year before the annual true up of actual fuel costs, which are automatically passed on to ratepayers.

"If Nova Scotia Power is effectively paid in advance, what motive do they have to hedge and mitigate the adjustment eventually required," Houston asked in his letter.

He also objected to the inclusion of a storm rider in rates to cover extreme weather, which he said pushed the risk of climate change on to ratepayers.

Premier second-guesses Muskrat Falls approval
Houston also second-guessed the board for approving Nova Scotia Power's participation in the Muskrat Falls hydro project in Labrador.

"The fact that Nova Scotians have paid over $500 million for this project with minimal benefit, and no one has been held accountable, is wrong," he said. "It was this board of the day that approved the contracts and entered the final project into rates."

Ratepayers are committed to paying $1.7 billion for the Maritime Link to bring the green source of electricity into the province, while rate mitigation talks in Newfoundland lack public details for their customers.

Although the Maritime Link was built on time and on budget by an affiliated company, only a fraction of Muskrat Falls hydro has been delivered because of ongoing problems in Newfoundland, including an 18% electricity rate hike deemed unacceptable by the province's consumer advocate.

"I find it remarkable that those contracts did not include different risk sharing mechanisms; they should have had provisions for issues in oversight of project management. Nevertheless, it was approved, and is causing significant harm to ratepayers in the form of increased rates."

Houston notes that because of non-delivery from Muskrat Falls, Nova Scotia Power has been forced to buy much more expensive coal to burn to generate electricity.

Opposition reaction
Opposition parties in Nova Scotia reacted to Houston's letter.

NDP Leader Claudia Chender dismissed it as bluster.

"It exposes his Bill 212 as not really helping Nova Scotians in the way that he said it would," she said. "Nothing in the settlement agreement contravenes that bill. But it seems that he's upset that he's been found out. And so here we are with another intervention in an independent regulatory body."

Liberal Leader Zach Churchill said the government should intervene to help ratepayers directly.

"We just think that it makes more sense to do that directly by supporting ratepayers through heating assistance, lump-sum electricity credits, rebate programs and expanding the eligibility for that or to provide funding directly to ratepayers instead of intervening in the energy market in this way," he said.

The premier's office said that no one was available when asked about an interview on Tuesday.

"The letter speaks for itself," the office responded.

Nova Scotia Power issued a statement Tuesday. It did not directly address Houston's claims.

"The settlement agreement is now with the NS Utility and Review Board," the utility said.

"The UARB process is designed to ensure customers are represented with strong advocates and independent oversight. The UARB will determine whether the settlement results in just and reasonable rates and is in the public interest."

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Australian Electric Vehicle Sales tripled in 2019 amid expanding charging infrastructure and more models, but market share remains low, constrained by limited government policy, weak incentives, and absent emissions standards despite growing ultra-fast chargers.

Key Points

EV units sold in Australia; in 2019 they tripled to 6,718, but market share was just 0.6%.

✅ Sales rose from 2,216 (2018) to 6,718 (2019); ~80% were BEVs.

✅ Public charging sites reached 2,307; fast chargers up 40% year-on-year.

✅ Policy gaps and absent standards limit model supply and EV uptake.

Sales of electric vehicles in Australia tripled in 2019 despite a lack of government support, according to the industry’s peak body.

The country’s network of EV charging stations was also growing, the Electric Vehicle Council’s annual report found, including a rise in the number of faster charging stations that let drivers recharge a car in about 15 minutes.

But the report, released on Wednesday, found the market share for electric vehicles was still only 0.6% of new vehicle sales – well behind the 2.5% to 5% in other developed countries.

The chief executive of the council, Behyad Jafari, said the rise in sales was down to more models becoming available. There are now 28 electric models on sale, with eight priced below $65,000.

Six more were due to arrive before the end of 2021, including two priced below $50,000, the council’s report said.

“We have repeatedly heard from car companies that they were planning to bring vehicles here, but Australia doesn’t have that policy support.”

The Morrison government promised a national electric vehicle strategy would be finalised by the middle of this year, but the policy has been delayed. The prime minister, Scott Morrison, last year accused Labor of wanting to “end the weekend” and force people out of four-wheel drives after the opposition set a target of 50% of new car sales being electric by 2030.

Jafari cited the Kia e-Niro – an award-winning electric SUV that was being prepared for an Australian launch, but is now reportedly on hold because the manufacturer favoured shipping to countries with emissions standards.

The council’s members include BMW, Nissan, Hyundai and Harley Davidson, as well as energy, technology and charging infrastructure companies.

Sales of electric vehicles – which include plug-in hybrids – went from 2,216 in 2018 to 6,718 in 2019, the report said. Jafari said about 80% of those sales were all-electric vehicles.

There have been 3,226 electric vehicles sold in 2020, the report said, despite an overall drop of 20% in vehicle sales due to the Covid-19 pandemic, while U.S. EV sales have surged into 2024.

Jafari said: “Our report is showing that Australian consumers want these cars.

“There is no controversy that the future of the industry is electric, but at the moment the industry is looking at different markets. We want policies that show [Australia] is going on this journey.”

Government agency data has forecast that half the new cars sold will be electric by 2035, underscoring that the age of electric cars is arriving even if there is no policy to support their uptake.

Manufacturers currently selling electric cars in Australia are Nissan, Hyundai, Mitsubishi, Tesla, Volvo, Porsche, Audi, BMW, Mercedes, Jaguar and Renault, the report said.

Jafari said most G20 countries had emissions standards in place for vehicles sold and incentives in place to support electric vehicles, such as rebates or exemptions from charges. This hadn’t happened in Australia, he said.

The report said: “Globally, carmakers are rolling out more electric vehicle models as the electric car market expands, but so far production cannot keep up with demand. This means that without policy signals, Australians will continue to be denied access to the full global range of electric vehicles.”

On Tuesday, one Australian charging provider, Evie Networks, opened an ultra-fast station at a rest stop at Campbell Town in Tasmania – between Launceston and Hobart.

The company said the station would connect EV owners in the state’s north and south and the two 350kW chargers could recharge a vehicle in 15 minutes, highlighting whether grids have the power to charge EVs at scale. Two more sites were planned for Tasmania, the company said.

A Tasmanian government grant to support electric vehicle charging had helped finance the site. Evie was also supported with a $15m grant from the federal government’s Australian Renewable Energy Agency.

According to the council report, Australia now has 2,307 public charging stations, including 357 fast chargers – a rise of 40% in the past year.

A survey of 2,900 people in New South Wales, the ACT, Victoria and South Australia, carried out by NRMA, RACV and RAA on behalf of the council, found the main barriers to buying an electric vehicle were concerns over access to charging points, higher prices and uncertainty over driving range.

Consumers favoured electric vehicles because of their environmental footprint, lower maintenance costs and vehicle performance.

The report said the average battery range of electric vehicles available in Australia was 400km, but almost 80% of people thought the average was less.

According to the survey, 56% of Australians would consider an electric car when they next bought a vehicle, and in the UK, EV inquiries soared during a fuel supply crisis.

“We are far behind, but it is surmountable,” Jafari said.

The council report also rated state and territories on the policies that supported its industry and found the ACT was leading, followed by NSW and Queensland.

A review of commercial electric vehicle use found public electric bus trials were planned or under way in Queensland, NSW, WA, Victoria and ACT. There are now more than 400,000 electric buses in use around the globe.

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