Utility examines possible nuclear site in Idaho

By Idaho Statesman


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A large utility is considering building its first nuclear power plant in Payette County, northwest of Boise, a company official says.

"We're in a very preliminary due-diligence process to look at a potential energy project in Payette County," Bill Fehrman, president and chief nuclear officer for MidAmerican Nuclear Energy Co., told the Idaho Statesman.

The company is a subsidiary of MidAmerican Energy Holdings Co., based in Des Moines, Iowa. That company owns Rocky Mountain Power, which serves eastern Idaho, and PacifiCorp, Oregon's largest utility.

The company has built fossil fuel plants and renewable-energy projects, but not nuclear power plants.

Fehrman said the site in Idaho could provide power to MidAmerican's customers in Oregon and Idaho. He said there also is a good supply of workers in the area, and that Gov. C.L. "Butch" Otter supports nuclear power.

"I'm glad to see there is an interest in Idaho," said Paul Kjellander, administrator of Otter's Office of Energy Resources. "If you look at our energy future, nuclear has the potential to play a significant role. The governor supports the concept of nuclear energy, and that may make Idaho a little more attractive."

MidAmerican Nuclear Energy Co. has been doing geologic testing on 3,300 acres of private land about 70 miles north of Boise near Paddock Valley Reservoir.

Fehrman said the company hasn't bought the land, and the person who owns it doesn't want to be identified.

This is the second nuclear power plant being considered in Idaho. Alternate Energy Holdings has said it wants to build a nuclear plant on 4,000 acres in Owyhee County near Bruneau, about 65 miles southeast of Boise.

Fehrman said the land for the proposed plant north of Boise is being tested for seismic activity. He said the company also will need water for the project and transmission lines to distribute power.

He said the company will likely decide whether to buy the land late in 2008. Fehrman said that if the company decides to build a nuclear plant, it could take up to 12 years before it's running.

"This is a lengthy and detailed process and we understand that there might be questions from people who live in the area, and we will do the best we can within the process to keep Payette County residents informed," he said. "As soon as a formal announcement is made on what direction we are taking, we will be communicating and having meetings with residents."

He said the size of the plant would likely be between 1,100 and 1,600 megawatts.

The Snake River Alliance, an Idaho-based nuclear watchdog group, has come out against the proposed plant in Owyhee County but hasn't yet said whether it opposes the latest nuclear plant.

Ken Miller, an energy specialist with Snake River Alliance, said the plants will produce radioactive waste.

"We take a position that we should be developing renewable energies and getting serious about energy conservation before going down that road," Miller said.

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Calgary's electricity use soars in frigid February, Enmax says

Calgary Winter Energy Usage Surge highlights soaring electricity demand, added megawatt-hours, and grid reliability challenges driven by extreme cold, heating loads, and climate change, with summer air conditioning also shifting seasonal peaks.

 

Key Points

A spike in Calgary's power use from extreme cold, adding 22k MWh and testing reliability as heating demand rises.

✅ +22,000 MWh vs Feb 2018 amid fourth-coldest February

✅ Heating loads spike; summer A/C now drives peak demand

✅ Grid reliability monitored; more solar and green resources ahead

 

February was so cold in Calgary that the city used enough extra energy to power 3,400 homes for a whole year, echoing record-breaking demand in B.C. in 2021 during severe cold.

Enmax Power Corporation, the primary electricity utility in the city, says the city 's energy consumption was up 22,000 megawatt hours last month compared with Februray 2018.

"We've seen through this cold period our system has held up very well. It's been very reliable," Enmax vice-president Andre van Dijk told the Calgary Eyeopener on Friday. "You know, in the absence of a windstorm combined with cold temperatures and that sort of thing, the system has actually held up pretty well."

The past month was the fourth coldest in Calgary's history, and similar conditions have pushed all-time high demand in B.C. in recent years across the West. The average temperature for last month was –18.1 C. The long-term average for February is –5.4 C.

 

Watching use, predicting issues

The electricity company monitors demand and load on a daily basis, always trying to predict issues before they happen, van Dijk said, and utilities have introduced winter payment plans to help customers manage bills during prolonged cold.

One of the issues they're watching is climate change, and how extreme temperatures and weather affect both the grid's reliability, as seen when Quebec shattered consumption records during cold snaps, and the public's energy use.

The colder it gets, the higher you turn up the heat. The hotter it is, the more you use air conditioning.

He also noted that using fuels then contributes to climate change, creating a cycle.

​"We are seeing variations in temperature and we've seen large weather events across the continent, across the world, in fact, that impact electrical systems, whether that's flooding, as we've experienced here, or high winds, tornadoes," van Dijk said.

"Climate change and changing weather patterns have definitely had had an impact on us as an electrical industry."

In 2012, he said, Calgary switched from using the most power during winter to using the most during summer, in large part due to air conditioning, he said.

"Temperature is a strong influencer of energy consumption and of our demand," van Dijk said.

Christmas tree lights have also become primarily LED, van Dijk said, which cuts down on a big energy draw in the winter.

He said he expects more solar and other green resources will be added into the electrical system in the future to mitigate how much the increasingly levels of energy use impact climate change, and to help moderate electricity costs in Alberta over time.

 

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Bruce nuclear reactor taken offline as $2.1B project 'officially' begins

Bruce Power Unit 6 refurbishment replaces major reactor components, shifting supply to hydroelectric and natural gas, sustaining Ontario jobs, extending plant life to 2064, and managing radioactive waste along Lake Huron, on-time and on-budget.

 

Key Points

A 4-year, $2.1B reactor overhaul within a 13-year, $13B program to extend plant life to 2064 and support Ontario jobs.

✅ Unit 6 offline 4 years; capacity shift to hydro and gas

✅ Part of 13-year, $13B program; extends life to 2064

✅ Creates jobs; manages radioactive waste at Lake Huron

 

The world’s largest nuclear fleet, became a little smaller Monday morning. Bruce Power has began the process to take Unit 6 offline to begin a $2.1 billion project, supported by manufacturing contracts with key suppliers, to replace all the major components of the reactor.

The reactor, which produces enough electricity to power 750,000 homes and reflects higher output after upgrades across the site, will be out of service for the next four years.

In its place, hydroelectric power and natural gas will be utilized more.

Taking Unit 6 offline is just the “official” beginning of a 13-year, $13-billion project to refurbish six of Bruce Power’s eight nuclear reactors, as Ontario advances the Pickering B refurbishment as well on its grid.

Work to extend the life of the nuclear plant started in 2016, and the company recently marked an operating record while supporting pandemic response, but the longest and hardest part of the project - the major component replacement - begins now.

“The Unit 6 project marks the next big step in a long campaign to revitalize this site,” says Mike Rencheck, Bruce Power’s president and CEO.

The overall project is expected to last until 2033, and mirrors life extensions at Pickering supporting Ontario’s zero-carbon goals, but will extend the life of the nuclear plant until 2064.

Extending the life of the Bruce Power nuclear plant will sustain 22,000 jobs in Ontario and add $4 billion a year in economic activity to the province, say Bruce Power officials.

About 2,000 skilled tradespeople will be required for each of the six reactor refurbishments - 4,200 people already work at the sprawling nuclear plant near Kincardine.

It will also mean tons of radioactive nuclear waste will be created that is currently stored in buildings on the Bruce Power site, along the shores of Lake Huron.

Bruce Power restarted two reactors back in 2012, and in later years doubled a PPE donation to support regional health partners. That project was $2-billion over-budget, and three years behind schedule.

Bruce Power officials say this refurbishment project is currently on-time and on-budget.

 

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Texas's new set of electricity regulators begins to take shape in wake of deep freeze, power outages

Texas PUC Appointments signal post-storm reform as Gov. Greg Abbott taps Peter Lake and advances Will McAdams for Senate confirmation, affecting ERCOT oversight, grid reliability, wholesale power pricing, and securitization for co-ops.

 

Key Points

Texas PUC appointments add Peter Lake and Will McAdams to steer ERCOT, grid reliability, and market policy.

✅ Peter Lake nominated chair to replace Arthur D'Andrea.

✅ Will McAdams advances toward Senate confirmation.

✅ Focus on ERCOT oversight, price cap debate, grid resilience.

 

A new set of Texas electricity regulators began to take shape Monday, as Gov. Greg Abbott nominated a finance expert to be the next chairman of the Public Utility Commission while his earlier choice of a PUC member moved toward Senate confirmation.

The Republican governor put forward Peter Lake of Austin, who has spent more than five years as an Abbott appointee to the Texas Water Development Board, as his second commission pick in as many weeks.

“I am confident he will bring a fresh perspective and trustworthy leadership to the PUC,” Abbott said of Lake, who once worked as a trader of futures and derivatives for a firm belonging to the Chicago Mercantile Exchange and more recently has eagerly promoted bonds for the State Water Implementation Fund for Texas.

“Peter’s expertise in the Texas energy industry and business management will make him an asset to the agency,” Abbott, who has touted grid readiness in recent months, said in a written statement. “I urge the Senate to swiftly confirm Peter’s appointment.”

On Monday, the Senate appeared to be moving quickly to confirm Abbott’s April 1 selection for the PUC, Will McAdams, president of Associated Builders and Contractors of Texas and a former legislative aide who helped write policy for regulated industries such as electricity.

McAdams was among the 129 nominees that the Senate Nominations Committee voted out, 8-0. His nomination heads now to the Senate floor.

All three of Abbott’s handpicked PUC commissioners who were in place before and during February’s calamitous winter storm have since quit or said they’re resigning, even as Sierra Club criticism of Abbott's demands intensified in the aftermath.

February’s polar vortex left in its wake physical and financial wreckage after a nonprofit grid operator answering to the PUC, amid calls for market reforms to avoid blackouts, shut off electricity to more than 4 million Texans, causing the deaths of at least 125 people, 13 of them in the Dallas-Fort Worth area.

Gov. Greg Abbott on Thursday named Will McAdams to the embattled Public Utility Commission of Texas. McAdams is a construction industry lobbyist with strong ties to the GOP-controlled Legislature. In Feb. 17 file photo, winter storm's snowfall andn large electrical transmission lines in South Arlington are pictured.

In a 45-minute confirmation hearing, McAdams, as lawmakers discussed ways to improve electricity reliability statewide, drew praise – and few tough questions.

McAdams, who previously worked for three GOP senators, testified that had he been on the commission in February, he would not have kept in place a controversial, $9,000-per-megawatt hour price cap on wholesale power for about 32 hours on Feb. 18-19.

“I don’t see myself making that decision,” he said.

McAdams, though, hedged slightly, saying he’s not privy to all information that the Electric Reliability Council of Texas, or ERCOT, and the PUC may have had at their disposal during the crisis.

The comments were notable because Lt. Gov. Dan Patrick and the Senate have fought with Abbott and the House over $16 billion in overcharges that, according to an independent market monitor, wrongly accrued near the end of the Feb. 15-19 outages.

Sen. Charles Schwertner, R-Georgetown, said the commission’s former chairwoman, DeAnn Walker, and Bill Magness, president of ERCOT, decided to hold the high cap in place because there “was still great concern about grid stability, even though there was significant reserves.”

He pressed McAdams to call that incorrect, which McAdams did.

“Given the fact pattern that I’m privy to, senator,” it wasn’t the right move, he said. “But again, there may be other facts out there. There probably are.”

McAdams acknowledged many homeowners and businesses were traumatized.

“The public’s confidence in the ability of the PUC to effectively regulate our electric markets has been badly damaged and shaken,” he said.

McAdams spoke favorably of renewable energy, calling wind and solar “absolutely valuable resources,” as the electricity sector faces profound change nationwide. To whatever extent those are not available, the PUC should “firm that up” with “dispatchable forms of generation,” such as gas, coal and nuclear, McAdams said.

He also called for lawmakers to consider providing electricity market bailout through “securitization,” or low-interest bond financing, to rural electric co-ops that were unable to pay the massive wholesale power bills they racked up during the February crisis.

“It would prevent those systems from having to front-load those costs onto their own members and smooth that out over a term of years,” while preventing an “uplift” of costs to other market participants who wisely hedged against soaring prices, McAdams said.

Noting that more than 400 bills have been filed to change ERCOT and how it’s governed, and as Texans prepare to vote on grid modernization funding this year, McAdams told the Senate panel, “It is clear to me that the Legislature wants meaningful changes to the status quo – to ensure that something positive comes out of this tragedy.”

Lake, who if confirmed by the Senate would replace Arthur D’Andrea as PUC chairman, grew up in Tyler. He attended prep school in New England and earned an undergraduate degree from the University of Chicago and a master of business administration degree from Stanford University.

He then worked for a commodities trading firm, a behavioral health company and as a business consultant before he became director of business development for Tyler-based Lake Ronel Oil Co. in 2014.

In late 2015, Abbott named Lake to the Texas Water Development Board and in February 2018 picked him to be the chairman of the three-member board that seeks to ensure water supplies for a fast-growing state.

Lake has steered the water board as it rolled out additional loans for water projects, approved by the Legislature and voters in 2013, and took the lead after Hurricane Harvey on flood control planning and infrastructure financing.

He’s posted exuberantly on Twitter as he toured agricultural water installations, lakes in West Texas and river authorities.

If confirmed, Lake and McAdams each would make $189,500 a year.

 

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Current Model For Storing Nuclear Waste Is Incomplete

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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Two-thirds of the U.S. is at risk of power outages this summer

Home Energy Independence reduces electricity costs and outage risks with solar panels, EV charging, battery storage, net metering, and smart inverters, helping homeowners offset tiered rates and improve grid resilience and reliability.

 

Key Points

Home Energy Independence pairs solar, batteries, and smart EV charging to lower bills and keep power on during outages.

✅ Offset rising electricity rates via solar and net metering

✅ Add battery storage for backup power and peak shaving

✅ Optimize EV charging to avoid tiered rate penalties

 

The Department of Energy recently warned that two-thirds of the U.S. is at risk of losing power this summer. It’s an increasingly common refrain: Homeowners want to be less reliant on the aging power grid and don’t want to be at the mercy of electric utilities due to rising energy costs and dwindling faith in the power grid’s reliability.

And it makes sense. While the inflated price of eggs and butter made headlines earlier this year, electricity prices quietly increased at twice the rate of overall inflation in 2022, even as studies indicate renewables aren’t making power more expensive overall, and homeowners have taken notice. In fact, according to Aurora Solar’s Industry Snapshot, 62% expect energy prices will continue to rise.

Homeowners aren’t just frustrated that electricity is pricey when they need it, they’re also worried it won’t be available at all when they feel the most vulnerable. Nearly half (48%) of homeowners are concerned about power outages stemming from weather events, or grid imbalances from excess solar in some regions, followed closely by outages due to cyberattacks on the power grid.

These concerns around reliability and cost are creating a deep lack of confidence in the power grid. Yet, despite these growing concerns, homeowners are increasingly using electricity to displace other fuel sources.

The electrification of everything
From electric heat pumps to electric stoves and clothes dryers, homeowners are accelerating the electrification of their homes. Perhaps the most exciting example is electric vehicle (EV) adoption and the need for home charging. With major vehicle makers committing to ambitious electric vehicle targets and even going all-electric in the future, EVs are primed to make an even bigger splash in the years to come.

The by-product of this electrification movement is, of course, higher electric bills because of increased consumption. Homeowners also risk paying more for every unit of energy they use if they’re part of a tiered pricing utility structure, where energy-insecure households often pay 27% more on electricity because customers are charged different rates based on the total amount of energy they use. Many new electric vehicle owners don’t realize this until they are deep into purchasing their new vehicle, or even when they open that first electric bill after the car is in their driveway.

Sure, this electrification movement can feel counterintuitive given the power grid concerns. But it’s actually the first step toward energy independence, and emerging models like peer-to-peer energy sharing could amplify that over time.

Balancing conflicting movements
The fact is that electrification is moving forward quickly, even among homeowners who are concerned about electricity prices and power grid reliability, and about why the grid isn’t yet 100% renewable in the U.S. This has the potential to lead to even more discontent with electric utilities and growing anxiety over access to electricity in extreme situations. There is a third trend, though, that can help reconcile these two conflicting movements: the growth of solar.

The popularity of solar is likely higher than you think: Nearly 77% of homeowners either have solar panels on their homes or are interested in purchasing solar. The Aurora Solar Industry Snapshot report also showed a nearly 40% year-over-year increase in residential solar projects across the U.S. in 2022, as the country moves toward 30% power from wind and solar overall, aligning with the Solar Energy Industries Association’s (SEIA) Solar Market Insight Report, which found, “Residential solar had a record year [in 2022] with nearly 6 GWdc of installations, representing 40% growth over 2021.”

It makes sense that finding ways to tamp down—even eliminate—growing bills caused by the electrification of homes is accelerating interest in solar, as more households weigh whether residential solar is worth it for their budgets, and residential solar installers are seeing this firsthand. The link between EVs and solar is a great proof point: Almost 80% of solar professionals said EV adoption often drives new interest in solar. 

 

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Nova Scotia's last paper mill seeks new discount electricity rate

Nova Scotia Power Active Demand Control Tariff lets the utility direct Port Hawkesbury Paper load, enabling demand response, efficiency, and industrial electricity rates, while regulators assess impacts on ratepayers, grid reliability, mill viability, and savings.

 

Key Points

A four-year tariff letting the utility control the mill load for demand response, efficiency, and lower costs.

✅ Utility can increase or reduce daily consumption at the mill

✅ Projected savings of $10M annually for other ratepayers to 2023

✅ Regulators reviewing cost allocation, monitoring, and viability

 

Nova Scotia Power is scheduled to appear before government regulators Tuesday morning seeking approval for a unique discount rate for its largest customer.

Under the four-year plan, Nova Scotia Power would control the supply of electricity to Port Hawkesbury Paper, a move referenced in a grid operations report that urges changes, with the right to direct the company to increase or reduce daily consumption throughout the year.

The rate proposal is supported by the mill, which says it needs to lower its power bill to keep its operation viable.

The rate went into effect on Jan. 1 on a temporary basis, pending the outcome of a hearing this week before the Nova Scotia Utility and Review Board, amid broader calls for an independent body to lead electricity planning.

The mill accounts for 10 per cent of the provincial electricity load, even as a neighbouring utility pursues more Quebec power for the region, producing glossy paper used in magazines and catalogs.

Nova Scotia Power says controlling how much electricity the mill uses — and when — will allow it to operate the system much more efficiently, as it expands biomass generation initiatives, saving other customers $10 million a year until the rate expires in 2023.

Ceding control 'not an easy decision'
In its opening statement that was filed in advance, Port Hawkesbury Paper said ceding the control of its electrical supply to Nova Scotia Power was "not an easy decision" to make, but the company is confident the arrangement will work.

In September 2019, Nova Scotia Power and the mill jointly applied for an "extra large active demand control tariff," which would provide electricity to the mill for about $61 per megawatt hour, well below the full cost of generating the electricity.

The utility said "fully allocating costs" would result in "prices in excess of $80/MWh ... and [would] not [be] financially viable for the mill."

In its statement, Port Hawkesbury Paper said since the initial filing "there have been greater near term declines in market demand and pricing for PHP's product than was forecast at that time, continuing to put pressure on our business and further highlighting the need to maintain the balance provided for in the new tariff."

Consumer advocate sees 'advantage,' but will challenge
Bill Mahody represents Nova Scotia Power's 400,000 residential customers before the review board. He wants proof the mill will pay enough toward the cost of generating the electricity it uses, amid concerns over biomass use in the province today.

"We filed evidence, as have others involved in the proceeding, that would call into question whether or not the rate design is capturing all of those costs and that will be a significant issue before the board," Mahody said.

Still, he sees value in the proposal.

The proposed new rate went into effect on Jan. 1 on a temporary basis. (The Canadian Press)
"This proposed rate gives Nova Scotia Power the ability to control that sizable Port Hawkesbury Paper load to the advantage of other ratepayers, as the province pursues more wind and solar projects, because Nova Scotia Power would be reducing the costs that other ratepayers are going to face," he said.

Mahody is also calling for a mechanism to monitor whether the mill's position actually improves to the point where it could pay higher rates.

"An awful lot can change during a four-year period, with new tidal power projects underway, and I think the board ought to have the ability to check in on this and make sure that their preferential rate continues to be justified," he said.

Major employer
Port Hawkesbury Paper, owned by Stern Partners in Vancouver, has received discounted power rates since it bought the idled mill in 2012. But the "load retention tariff" as it was called, expired at the end of 2019.

Regulators have accepted Nova Scotia Power's argument that it would cost other customers more if the mill ceased to operate.

The mill said it spends between $235 million and $265 million annually, employing 330 people directly and supporting 500 other jobs indirectly.

The Nova Scotia government pledged $124 million in financial assistance as part of the reopening in 2012.

 

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