EV Smart outdoes combustion cousins

Nuclear Waste Corrosion accelerates as stainless steel, glass, and ceramics interact in aqueous conditions, driving localized corrosion in repositories like Yucca Mountain, according to Nature Materials research on high-level radioactive waste storage.

Key Points

Degradation of waste forms and canisters from water-driven chemistry, causing accelerated, localized corrosion in storage.

✅ Stainless steel-glass contact triggers severe localized attack

✅ Ceramics and steel co-corrosion observed under aqueous conditions

✅ Yucca Mountain-like chemistry accelerates waste form degradation

The materials the United States and other countries plan to use to store high-level nuclear waste, even as utilities expand carbon-free electricity portfolios, will likely degrade faster than anyone previously knew because of the way those materials interact, new research shows.

The findings, published today in the journal Nature Materials (https://www.nature.com/articles/s41563-019-0579-x), show that corrosion of nuclear waste storage materials accelerates because of changes in the chemistry of the nuclear waste solution, and because of the way the materials interact with one another.

"This indicates that the current models may not be sufficient to keep this waste safely stored," said Xiaolei Guo, lead author of the study and deputy director of Ohio State's Center for Performance and Design of Nuclear Waste Forms and Containers, part of the university's College of Engineering. "And it shows that we need to develop a new model for storing nuclear waste."

Beyond waste storage, options like carbon capture technologies are being explored to reduce atmospheric CO2 alongside nuclear energy.

The team's research focused on storage materials for high-level nuclear waste -- primarily defense waste, the legacy of past nuclear arms production. The waste is highly radioactive. While some types of the waste have half-lives of about 30 years, others -- for example, plutonium -- have a half-life that can be tens of thousands of years. The half-life of a radioactive element is the time needed for half of the material to decay.

The United States currently has no disposal site for that waste; according to the U.S. General Accountability Office, it is typically stored near the nuclear power plants where it is produced. A permanent site has been proposed for Yucca Mountain in Nevada, though plans have stalled. Countries around the world have debated the best way to deal with nuclear waste; only one, Finland, has started construction on a long-term repository for high-level nuclear waste.

But the long-term plan for high-level defense waste disposal and storage around the globe is largely the same, even as the U.S. works to sustain nuclear power for decarbonization efforts. It involves mixing the nuclear waste with other materials to form glass or ceramics, and then encasing those pieces of glass or ceramics -- now radioactive -- inside metallic canisters. The canisters then would be buried deep underground in a repository to isolate it.

At the generation level, regulators are advancing EPA power plant rules on carbon capture to curb emissions while nuclear waste strategies evolve.

In this study, the researchers found that when exposed to an aqueous environment, glass and ceramics interact with stainless steel to accelerate corrosion, especially of the glass and ceramic materials holding nuclear waste.

In parallel, the electrical grid's reliance on SF6 insulating gas has raised warming concerns across Europe.

The study qualitatively measured the difference between accelerated corrosion and natural corrosion of the storage materials. Guo called it "severe."

"In the real-life scenario, the glass or ceramic waste forms would be in close contact with stainless steel canisters. Under specific conditions, the corrosion of stainless steel will go crazy," he said. "It creates a super-aggressive environment that can corrode surrounding materials."

To analyze corrosion, the research team pressed glass or ceramic "waste forms" -- the shapes into which nuclear waste is encapsulated -- against stainless steel and immersed them in solutions for up to 30 days, under conditions that simulate those under Yucca Mountain, the proposed nuclear waste repository.

Those experiments showed that when glass and stainless steel were pressed against one another, stainless steel corrosion was "severe" and "localized," according to the study. The researchers also noted cracks and enhanced corrosion on the parts of the glass that had been in contact with stainless steel.

Part of the problem lies in the Periodic Table. Stainless steel is made primarily of iron mixed with other elements, including nickel and chromium. Iron has a chemical affinity for silicon, which is a key element of glass.

The experiments also showed that when ceramics -- another potential holder for nuclear waste -- were pressed against stainless steel under conditions that mimicked those beneath Yucca Mountain, both the ceramics and stainless steel corroded in a "severe localized" way.

Other Ohio State researchers involved in this study include Gopal Viswanathan, Tianshu Li and Gerald Frankel.

This work was funded in part by the U.S. Department of Energy Office of Science.

Meanwhile, U.S. monitoring shows potent greenhouse gas declines confirming the impact of control efforts across the energy sector.

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OEB Hydro One Rate Decision 2023-2027 sets approved transmission and distribution rates in Ontario, with a settlement reducing revenue requirement, modest bill impacts, higher productivity factors, inflation certainty, DVA credits, and First Nations participation measures.

Key Points

OEB-approved Hydro One 2023-2027 transmission and distribution rates settlement, lowering costs and limiting bill impacts.

✅ $482.7M revenue reductions vs. original proposal

✅ Avg bill impact: +$0.69 trans., +$2.43 distr. per month

✅ Faster DVA refunds; productivity and efficiency incentives

The Ontario Energy Board (OEB) issued its Decision and Order on an application filed by Hydro One Networks Inc. (Hydro One) on August 5, 2021 seeking approval for changes to the rates it charges for electricity transmission and distribution, beginning January 1, 2023 and for each subsequent year through to December 31, 2027. 

The proceeding resulted in the filing of a settlement proposal that the OEB has now approved after concluding that it is in the public interest. 

The negotiated reductions in Hydro One's transmission and distribution revenue requirements over the 2023 to 2027 period total $482.7 million compared to the requests made by Hydro One in its application.

The OEB found that the reductions in Hydro One's proposed capital expenditure and operating, maintenance and administration costs were reasonable, and should not compromise the safety and reliability of Hydro One's transmission and distribution systems. It also concluded that the estimated bill impacts for both transmission and distribution customers are reasonable, and that the January 1, 2023 implementation and effective date of the new rates is appropriate.

In the broader Canadian context, pressures on utility finances at other companies, such as Manitoba Hydro's debt provide additional background for stakeholders.

Bill Impacts

This proceeding related to both transmission and distribution operations.

Transmission

The new transmission revenue requirement will affect Ontario electricity consumers across the province because it will be incorporated into updated transmission rates, which are paid by electricity distributors and other large consumers connected directly to the transmission system, and distributors then pass this cost on to their customers.

As a result of the settlement approved on the transmission portion of the application, it is estimated that for a typical Hydro One residential customer with a monthly consumption of 750 kWh, the total bill impact averaged over the 2023-2027 period will be an increase of $0.69 per month or 0.5%, which follows the 2021 electricity rate reductions that affected many businesses.

Distribution

The new OEB-approved distribution rates will affect Hydro One's distribution customers, including areas served through acquisitions such as the Peterborough Distribution sale which expanded its customer base.

As a result of the settlement reached on the distribution portion of the application, it is estimated that for a typical residential distribution customer of Hydro One with a monthly consumption of 750 kWh, the total bill impact averaged over the 2023-2027 period will be an increase of $2.43 per month or 1.5%.
This proceeding included 24 approved intervenors representing a wide variety of customer classes and other interests. Representatives of 18 of those intervenors participated in the settlement conference. Having this diversity of perspective enriches the already thorough examination of evidence and argument that the OEB routinely undertakes when considering an application.

Other features of the settlement proposal include:

• A commitment by Hydro One to include, in future operational and capital investment plans, a discussion of how the proposed spending will directly support the achievement of Hydro One's climate change policy.
• Eliminating further updates to reflect changes to inflation in 2022 and 2023 as originally proposed, to provide Hydro One's customers with greater certainty as to the potential impacts of inflation on their bills.
• Increases in the productivity factors and supplemental stretch factors for both the distribution and transmission business segments which will provide Hydro One with additional incentives to achieve greater efficiencies during the 2023 to 2027 period.
• Undertaking certain measures to seek economic participation or equity investment opportunities from First Nations.
• Disposition of net credit balances in deferral and variance accounts (DVAs) owed to customers will be returned over a shorter period of time:
• Transmission DVA – $22.5M over a one-year period in 2023 (versus five years)
• Distribution DVA – $85.9M over a three-year period – 2023-2025 (versus five years)
• Undertaking certain measures to continue examining cost-effective transmission and distribution line losses
• In the decision, the OEB acknowledged the efforts involved by parties to participate in this entire proceeding, including the settlement conference, considering the number of participants, the complexity of the issues, and the challenging logistics of a "virtual" proceeding. The OEB commended the parties and OEB staff for achieving a comprehensive settlement on all issues.

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Newfoundland and Labrador electricity rate hike examines a proposed 18.6% increase under the PUB's Rate Stabilization Plan, driven by oil prices at Holyrood, with Consumer Advocate concerns over rate shock and use of RSP balances.

Key Points

A proposed 18.6% July 2017 increase under the RSP, driven by oil prices, now under PUB review for potential mitigation.

✅ PUB flags potential rate shock from proposed adjustment

✅ RSP balances cited to offset increases without depleting fund

✅ Oil-fired Holyrood volatility drives fuel cost uncertainty

How much of a rate hike is reasonable for users of electricity in Newfoundland and Labrador?

That's a question before the Public Utilities Board (PUB) as it examines an application by Newfoundland and Labrador Hydro, which could see consumers pay up to 18.6 per cent more as of July 1, reflecting regional pressures seen in Nova Scotia, where regulators approved a 14% rate hike earlier this year.

"The estimated rate increase for July 2017 is such a significant increase that it may be argued that it would cause rate shock," said the PUB, asking the company to revise its application.

NL Hydro said the price adjustment is part of what happens every year through the Rate Stabilization Plan (RSP), which is used to offset the ups and downs of oil prices.

"The cost of fuel is volatile and as long as we rely on oil-fired generation at Holyrood, customers will continue to be impacted by this electricity price uncertainty," said the company in a statement to CBC News.

It noted that customers received a break from RSP adjustments in 2015 and 2016, even as costs from the Muskrat Falls project begin to be reflected.

The PUB noted that under the rate stabilization plan, prices have gone up or down by about 10 per cent in the past.

The regulatory board said the impact of the latest request would be a 27.6 per cent hike to Newfoundland Power, with "an estimated average end customer impact of 18.6 per cent."

Hydro's estimates are based on an average price for oil of $81.40 per barrel from July 2017 to June 2018, according to the PUB.

'Unacceptable' burden: Consumer Advocate

"To burden ratepayers with an 18 per cent rate increase is unacceptable," said Consumer Advocate Dennis Browne, echoing pushback in Nova Scotia, where the premier urged regulators to reject a 14% hike at the time.

Browne is arguing that there is money in the RSP to reduce the proposed increase, including the possibility of a lump-sum bill credit for customers.

"These ratepayer balances — which, according to NL Power, totals $77.4 million — are not the property of Hydro," he wrote in a letter to the PUB.

"No utility has the right to squirrel away ratepayers' money to be used by that utility for some future purpose. The Board has jurisdiction over those balances," Browne said.

Browne also wants the RSP overhauled so that it can be applied to price fluctuations every quarter, as opposed to annually.

Hydro has expressed concern that depleting the rate stabilization fund would lead to other, more significant, rate increases in the future.

It said several alternatives to mitigate high rates have been provided to the PUB, which has final say, similar to how Manitoba Hydro scaled back a planned increase in the next year.

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U.S. Hybrid Vehicle Sales Outlook highlights rising hybrid demand as an EV bridge, driven by emissions rules, range anxiety, charging infrastructure gaps, and automaker strategies from Ford, Toyota, and Stellantis across U.S. markets.

Key Points

Forecast of U.S. hybrid sales shaped by EV adoption, emissions rules, charging access, and automaker strategies.

✅ S&P sees hybrids at 24% of U.S. sales by 2028

✅ Bridges ICE to EV amid range and charging concerns

✅ Ford, Toyota, Stellantis expand U.S. hybrid lineups

Hybrid gasoline-electric vehicles may not be dying as fast as some predicted in the auto sector’s rush to develop all-electric models.

Ford Motor is the latest of several top automakers, including Toyota and Stellantis, planning to build and sell hundreds of thousands of hybrid vehicles in the U.S. over the next five years, industry forecasters told Reuters.

The companies are pitching hybrids as an alternative for retail and commercial customers who are seeking more sustainable transportation, but may not be ready to make the leap to a full electric vehicle.

"Hybrids really serve a lot of America," said Tim Ghriskey, senior portfolio strategist at New York-based investment manager Ingalls & Snyder. "Hybrid is a great alternative to a pure electric vehicle (and) it's an easier sell to a lot of customers."

Interest in hybrids is rebounding as consumer demand for pure electrics has not accelerated as quickly as expected, with EV market share dipping in Q1 2024 according to some analyses. Surveys cite a variety of reasons for tepid EV demand, from high initial cost and concerns about range to lengthy charging times and a shortage of public charging infrastructure in many regions.

“With the tightening of emissions requirements, hybrids provide a cleaner fleet without requiring buyers to take the leap into pure electrics,” said Sam Fiorani, vice president at AutoForecast Solutions.

S&P Global Mobility estimates hybrids will more than triple over the next five years, accounting for 24% of U.S. new vehicle sales in 2028. Sales of pure electrics will claim about 37%, supported by strong U.S. EV sales into 2024 momentum, leaving combustion vehicles — including so-called “mild” hybrids — with a nearly 40% share.

S&P estimates hybrids will account for just 7% of U.S. sales this year, and pure electrics 9%, underscoring that EV sales still lag gas cars as internal combustion engine (ICE) vehicles take more than 80%.

Historically, hybrids have accounted for less than 10% of total U.S. sales, with Toyota’s long-running Prius among the most popular models. The Japanese automaker has consistently said hybrids will play a key role in the company's long-range electrification plans as it slowly ramps up investment in pure EVs.

Ford is the latest to roll out more aggressive hybrid plans. On its second-quarter earnings call in late July, Chief Executive Jim Farley surprised analysts, saying Ford expects to quadruple its hybrid sales over the next five years after earlier promising an aggressive push into all-electric vehicles.

“This transition to EVs will be dynamic,” Farley told analysts. “We expect the EV market to remain volatile until the winners and losers shake out.”

Among Ford’s competitors, General Motors appears to have little interest in hybrids in the U.S., while Stellantis will follow Toyota and Ford’s hedge by offering U.S. buyers a choice of different powertrains, including hybrids, until sales of pure electric vehicles start to take off after mid-decade, a potential EV inflection point according to forecaster GlobalData.

In a statement, GM said it, echoing leadership's view that EVs won't go mainstream until key issues are addressed, "continues to be committed to its all-electric future ... While we will have hybrid vehicles in our global fleet, our focus remains on transitioning our portfolio to electric by 2030.”

Stellantis said hybrids now account for 36% of Jeep Wrangler sales and 19% of Chrysler Pacifica sales. In addition to new pure electric models coming soon, "we are very bullish on hybrids going forward," a spokesperson said.

This year, manufacturers are marketing more than 60 hybrids in the U.S. Toyota and its premium Lexus brand are selling at least 18 different hybrid models, enabling the Japanese automaker to maintain its stranglehold on the sector.

Hyundai and sister brand Kia offer seven hybrid models, with Ford and Lincoln six. Stellantis offers just three, and GM’s sole entry, due out later this year, is a hybrid version of the Chevrolet Corvette sports car.

But hybrids remain in short supply at many U.S. dealerships.

Andrew DiFeo, dealer principal at Hyundai of St. Augustine, south of Jacksonville, FL, doesn't see EV adoption hitting the levels the Biden administration wants until EV charging networks are as ubiquitous as gas stations.

"Hybrids are a great bridge to whatever the future holds,” said DiFeo, adding, “I've got zero in stock (and) I've got customers that want all of them."

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Labrador Island Link Reliability faces scrutiny as Nalcor Energy and General Electric address software issues; Liberty Consulting warns of Holyrood risks, winter outages, grid stability concerns, and PUB oversight for Newfoundland and Labrador.

Key Points

It is the expected dependability of the link this winter, currently uncertain due to GE software and Holyrood risks.

✅ GE software delays may hinder reliable in-service by mid-November.

✅ Holyrood performance issues increase winter outage risk.

✅ PUB directs Hydro to plan contingencies and improve assets.

An independent consultant is questioning if the brand new Labrador Island link can be counted on to supply power to Newfoundland this coming winter.

In June, Nalcor Energy confirmed it had successfully sent power from Churchill Falls to the Avalon Peninsula through its more than 1500-kilometre link, but now the Liberty Consulting Group says it doesn't expect the link will be up and running consistently this winter.

"What we have learned supports a conclusion that the Labrador Island Link is unlikely to be reliably in commercial operation at the start of the winter," says the report dated Aug. 30, 2018.

The link relies on software provided by General Electric but Liberty says there are lingering questions about GE's ability to ensure the necessary software will be in place this fall.

"At an August meeting, company representatives did not express confidence in GE's ability to meet an in-service date for the Labrador Island Link of mid-November," says the report.

Liberty also says testing the link for a brief period this spring and fall doesn't demonstrate long-term reliability.

"The link will remain prone to the uncertainties any new major facility faces early in its operating life, especially one involving technology new to the operating company," according to the report.

Holyrood trouble

The report goes on to say island residents should also be worried about the reliability of the troubled Holyrood facility — a facility that's important when demand for energy is high during winter months.

Liberty says "poor performance at the Holyrood thermal generating station increases the risk of outages considerably."

The group's report concludes the deteriorating condition of Holyrood is a major threat to the island's power supply and Liberty says that threat "could produce very severe consequences when the Labrador Island Link is unavailable."

The consultant says questions about the Labrador Island Link's readiness combined with concerns about the reliability of Holyrood may mean power outages, and for vulnerable customers, debates over hydro disconnections policies often intensify during winter.

"This all suggests that, for at least part of this winter, the island interconnected system may be at the mercy of the weather, where severe events can test utilities' storm response efforts further."

The consultant's report also includes five recommendations to the PUB, reflecting the kind of focused nuclear alert investigation follow-up seen elsewhere.

In essence, Liberty is calling for the board to direct Newfoundland and Labrador Hydro to make plans for the possibility that the link won't be available this winter. It's also calling on hydro to do more to improve the reliability of its other assets, such as Holyrood, as some operators have even contemplated locking down key staff to maintain operations during crises.

Response to Liberty's report

Nalcor CEO Stan Marshall defended the Crown corporation's winter preparedness in an email statement to CBC.

"The right level of planning and investment has been made for our existing equipment so we can continue to meet all of our customer electricity needs for this coming winter season," he wrote.

Regarding the Labrador Island Link, Marshall called for patience.

"This is new technology for our province and integrating the new transmission assets into our current electricity system is complex work that takes time," he said.

There is also a more detailed response from Newfoundland and Labrador Hydro which was sent to the province's Public Utiltiies Board.

Hydro says it will keep testing the Labrador Island Link and increasing the megawatts that are wheeled through it. It also says in October it will begin to give the PUB regular reports on the link's anticipated in-service date.

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Berlin Electric Utility APPA Safety Award recognizes Gold Designation performance in public power, highlighting OSHA-aligned incident rates, robust safety culture, worker safety training, and operational reliability that keeps the community's electric service resilient.

Key Points

A national honor for Berlin's Gold Designation recognizing safety performance, worker protection, and reliable service.

✅ Gold Designation in 15,000-29,999 worker hours APPA category

✅ OSHA-based incident rate and robust safety culture

✅ Training, PPE, and reliability focus in public power operations

The Town of Berlin Electric Utility Department has been recognized for its outstanding safety practices with the prestigious Safety Award of Excellence from the American Public Power Association (APPA), a distinction also reflected in Medicine Hat Electric Utility for health and safety excellence, highlighting industry-wide commitment to worker protection.

Recognition for Excellence

In an era when workplace safety is a critical concern, with organizations highlighting leadership in worker safety across the sector, the Town of Berlin Electric Utility Department’s achievement stands out. The department earned the Gold Designation award in the category for utilities with 15,000 to 29,999 worker hours of annual worker exposure. This category is part of the APPA’s annual Safety Awards, which are designed to recognize the safety performance of public power utilities across the United States.

Out of more than 200 utilities that participated in the 2024 Safety Awards, Berlin's Electric Utility Department distinguished itself with an exemplary safety record. The utility’s ranking was based on its low incidence of work-related injuries and illnesses, alongside its robust safety programs and strong safety culture.

What the Award Represents

The Safety Award of Excellence is given to utilities that demonstrate effective safety protocols and practices over the course of the year. The APPA evaluates utilities based on their incident rate, which is calculated using the number of work-related reportable injuries or illnesses relative to worker hours. This measurement adheres to guidelines established by the Occupational Safety and Health Administration (OSHA), ensuring a standardized approach to assessing safety.

For the Town of Berlin Electric Utility Department, achieving the Gold Designation award signifies a year of outstanding safety performance. The award reflects the department’s dedication to preventing accidents and creating a work environment where safety is prioritized at every level.

Why Safety Matters

For utilities like the one in Berlin, safety is not just about preventing injuries—it's about fostering a culture of care and responsibility. Electric utility workers face unique and significant risks, ranging from the dangers of working with high-voltage systems, including hazards near downed power lines that require extreme caution, to the physical demands of the job. A utility’s ability to minimize these risks and keep its workforce safe is a direct reflection of its safety practices, training, and overall management.

The commitment to safety extends beyond just the immediate work environment. Utilities that place a high value on safety typically invest in ongoing training, safety gear, and processes, and even contingency measures like staff living on site during outbreaks, that ensure all employees are well-prepared to handle the challenges of their roles. The Town of Berlin Electric Utility Department has taken these steps seriously, providing its workers with the resources they need to stay safe while maintaining the power supply for the local community.

The Importance of Worker Safety in Public Power

The American Public Power Association’s Safety Award program highlights the best practices in public utilities, which, as the U.S. grid overseer's pandemic warning reminded the sector, play a crucial role in providing essential services to communities across the country. Public power utilities, like Berlin’s, are governed by local or municipal entities rather than for-profit corporations, which often allows them to have a closer relationship with their communities. As a result, these utilities often go above and beyond when it comes to worker safety, understanding that the well-being of employees directly impacts the quality of service provided to residents.

For the Town of Berlin, this award not only highlights the utility's commitment to its employees but also reinforces the importance of the work that public utilities do in keeping communities safe and powered. Berlin's recognition underscores the significance of maintaining a safe work environment, especially when the safety of first responders and utility workers, as seen when nuclear plant workers raised concerns over virus precautions, directly impacts the public’s access to reliable services.

What’s Next for Berlin’s Electric Utility Department

Receiving the Safety Award of Excellence is a remarkable achievement, but for the Town of Berlin Electric Utility Department, it’s not the end of their safety journey—it’s just one more step in their ongoing commitment to improvement. The department’s leadership, including the safety team, has emphasized the importance of continually evaluating and enhancing safety protocols to stay ahead of potential risks. This includes adopting new safety technologies, refining training programs, and ensuring that all employees are involved in the process of safety.

As the Town of Berlin looks forward to the future, its focus on worker safety will remain a top priority. Maintaining this level of safety is not only crucial for the health and well-being of employees but also for ensuring the continued success of the community’s utility services.

Community Impact

This recognition also serves as an example for other utilities in the region and across the country. By prioritizing safety, the Town of Berlin Electric Utility Department sets a standard that other utilities can aspire to. In a time when worker safety is more important than ever, Berlin’s commitment to best practices provides a model for others to follow.

Ultimately, the safety of utility workers is a reflection of a community’s dedication to its workforce and its commitment to providing reliable, uninterrupted services. For the residents of Berlin, the recognition of their local electric utility department’s safety practices means that they can continue to rely on a safe, secure, and resilient power infrastructure, while staying mindful of home risks such as overheated power strips that can spark fires.

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