Future of Vermont Yankee looks bleak

By Huffington Post


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Vermont's piece of the nuclear age, launched four decades ago, seems to be coming to a close, even as advocates push for a renaissance of nuclear power in the United States.

The Vermont Yankee nuclear plant's initial 40-year license expires March 21, 2012, less than 15 months from now. And despite a safety and performance record no worse than many of the other 61 reactors that have won 20-year license extensions from the federal Nuclear Regulatory Commission, the Vernon power plant's future looks short.

That's largely because it's located in the only state in the country with a law saying both houses of its legislature have to give their approval before Vermont regulators can issue a state license for the plant to continue operating.

The Vermont Senate voted 26-4 last February against letting the Public Service Board issue the new state license. That vote came a month after it was revealed that Vermont Yankee was leaking tritium, a radioactive isotope of hydrogen, into soil and groundwater surrounding the reactor on the banks of the Connecticut River. It also followed revelations that senior plant personnel had misled state officials about whether Vermont Yankee had the sort of underground pipes that carried radioactive tritium.

Entergy Corp., the New Orleans-based utility giant that owns Vermont Yankee, thinks it can turn its fortunes around.

"We continue to undertake the work to receive the approvals necessary to operate the plant past March" of 2012, Mike Burns, spokesman for the plant's owner, New Orleans-based Entergy Corp., said in an e-mail.

Rep. Tony Klein, an East Montpelier Democrat and chairman of the state House Natural Resources and Energy committee, has been a key player in issues related to Vermont's lone reactor in recent years. He does not see Vermont Yankee operating beyond its shutdown date.

"I don't think there's any chance in hell.... If they've got a game plan, it's a strange one to me."

Thirty-seven of the nation's 104 nuclear reactors have had leaks like the ones reported at Vermont Yankee last winter. None of the tritium or other radioactive substances reported to have leaked later have turned up in public water supplies, and plant and state officials have said throughout there's no threat to public health and safety. Vermont long has been known nationally as a hotspot for anti-nuclear sentiment, and the combination of the leaks and misstatements to state officials quickly made the political atmosphere toxic for Entergy.

Newly elected Gov. Peter Shumlin, then the president pro tem of the state Senate, orchestrated February's vote to block Yankee's re-licensing. In his gubernatorial campaign, he referred throughout his campaign to "Entergy Louisiana," emphasizing Vermont Yankee's out-of-state ownership.

Shumlin, who grew up less than 25 miles from Vermont Yankee in Putney, said he didn't give it much thought when the plant split its first atoms three days before his 16th birthday. Now he firmly believes the plant should close when its 40 years are up.

He called Entergy "a company we can't trust. The plant is old and leaking. There's no place to store the radioactive waste. The world has changed and we need to change with it. It's time for it to sleep."

The tritium troubles weren't the first black eye the plant had given itself in recent years.

In 2007, a cooling tower at the reactor in Vernon, in Vermont's southeast corner, collapsed, producing a spectacular photo of thousands of gallons of water spewing from a 6-foot-wide pipe onto a pile of rubble on the ground below.

Robert Stannard said seeing the photo prompted him to leave his job as head of a Bennington development group and go to work lobbying for an anti-nuclear group, Vermont Citizens' Action Network.

"If this company allowed degradation in maintenance to a degree that the plant was falling down, I felt I had to do something about it," Stannard said.

Others hold out hope Vermont Yankee will continue to operate.

William Driscoll, vice president of the manufacturers' group Associated Industries of Vermont, said he hoped the Legislature would repeal the law giving itself the power to decide the nuclear plant's fate.

"We would hope they would put this decision in the hands of the Public Service Board, which is where we believe it would be the best handled."

Driscoll pointed to a report issued last August by ISO-New England, which dispatches electric power around the six-state region, saying that losing Vermont Yankee could cause parts of the electric grid to become less reliable.

Nuclear critics scoff at that, noting the lights don't go out when the plant has an unscheduled outage because of mechanical or other problems.

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Nova Scotia regulator approves 14% electricity rate hike, defying premier

Nova Scotia Power Rate Increase 2023-2024 approved by the UARB lifts electricity rates 14 percent, citing fuel costs and investments, despite Bill 212; includes ROE 9 percent, decarbonization deferral, and a storm cost recovery rider.

 

Key Points

An approved UARB rate case raising electricity bills about 14% over 2023-2024, with ROE 9% and cost recovery tools.

✅ UARB approves average 6.9% annual increases for 2023 and 2024.

✅ Maintains 9% ROE; sets storm cost rider trial and decarbonization deferral.

✅ Government opposed via Bill 212, but settlement mostly upheld.

 

Nova Scotia regulators approved a 14 per cent electricity rate hike on Thursday, defying calls by Premier Tim Houston to reject the increase.

Rates will rise on average by 6.9 per cent each year in 2023 and 2024.

In Newfoundland and Labrador, the NL Consumer Advocate called an 18 per cent electricity rate hike unacceptable amid affordability concerns.

The Nova Scotia Utility and Review Board (UARB) issued a 203-page decision ratifying most of the elements in a settlement agreement reached between Nova Scotia Power and customer groups after Houston's government legislated a rate, spending and profit cap on the utility in November.

The board said approval was in the public interest and the increase is "reasonable and appropriate."

"The board cannot simply disallow N.S. Power's reasonable costs to make rates more affordable. These principles ensure fair rates and the financial health of a utility so it can continue to invest in the system providing services to its customers," the three-member panel wrote.

"While the board can (and has) disallowed costs found to be imprudent or unreasonable, absent such a finding, N.S. Power's costs must be reflected in the rates."

In addition to the 14 per cent hike, the board maintained Nova Scotia Power's current return on equity of 9 per cent, with an earnings band of 8.75 to 9.25 per cent. It agreed in principle to establish a decarbonization deferral account to pay for the retirement of coal plants and related decommissioning costs, and implemented a storm cost recovery rider for a three-year trial period.

The board rejected several items in the agreement, including rolling some Maritime Link transmission capital projects into consumers' rates.

Nova Scotia Power welcomed the ruling in a statement, describing it as "the culmination of an extensive and transparent regulatory process over the past year."

Natural Resources and Renewables Minister Tory Rushton, who has said the government cannot order lower power rates in Nova Scotia, stated the UARB decision was not what the government wanted, but he did not indicate the government has any plans to bring forward legislation to overturn it. 

"We're disappointed by the decision today. We've always been very clear that we were standing by ratepayers right from the get-go but we also respect the independent body of the UARB and their decision today."


Pressure from the province
Houston claimed the settlement breached his government's legislation, known as Bill 212 in Nova Scotia, which he said was intended to protect ratepayers. It 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.

Bill 212 was passed after the board concluded weeks of public hearings into Nova Scotia Power's request for an electricity rate increase, its first general rate application in 10 years. Nova Scotia Power is a subsidiary of Halifax-based Emera, which is a publicly traded company.

The legislation triggered credit downgrades from two credit rating agencies who said it compromised the independence of the Nova Scotia Utility and Review Board.

In Newfoundland and Labrador, electricity users have begun paying for Muskrat Falls as project costs flow through rates, highlighting broader pressures on Atlantic Canada utilities.

In its decision, the board accepted that legislation was intended to protect ratepayers but did not preclude increases in rates.

"Given the exclusion of fuel and purchased power costs when these were expected to cause significant upward pressure on rates, it also did not preclude large increases in rates. Instead, the protection afforded by the Public Utilities Act amendments appears to be focused on N.S. Power's non-fuel costs, with several amendments targeting N.S. Power's cost of capital and earnings."

The board noted the province was the only intervenor in the rate case to object to the settlement.


Opposition reaction
Rushton said despite the outcome, Bill 212 achieved its goal, which was to protect ratepayers.

"Without Bill 212 the rates would have actually been higher," he said. "It would have double-digit rates for this year and next year and now it's single digits."

NDP Leader Claudia Chender said the end result is that Nova Scotians are still facing "incredibly unaffordable power."

Similar criticism emerged in Saskatchewan after an 8 per cent SaskPower increase, which the NDP opposed during provincial debates.

"It's really unfortunate for a lot of Nova Scotians who are heading into a freezing weekend where heat is not optional."

Chender said a different legislative approach is needed to change the regulatory system, and more needs to be done to help people pay their electricity bills.

Liberal MLA Kelly Regan echoed that sentiment.

"There are lots of people who can absorb this. There are a lot of people who cannot, and those are the people that we should be worried about right now. This is why we've been saying all along the government needs to actually give money directly to Nova Scotians who need help with power rates."

Rushton said the government has introduced programs to help Nova Scotians pay for heat, including raising the income threshold to access the Heating Assistance Rebate Program and creating incentives to install heat pumps.

Elsewhere, some governments have provided a lump-sum credit on electricity bills to ease short-term costs for households.

 

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Court quashes government cancellation of wind farm near Cornwall

Nation Rise Wind Farm Ruling overturns Ontario cancellation, as Superior Court finds the minister's decision unreasonable; EDP Renewables restarts 100-megawatt project near Cornwall, citing jobs, clean energy, and procedural fairness over bat habitat concerns.

 

Key Points

Ontario court quashes cancellation, letting EDP Renewables finish 100 MW Nation Rise project and resume clean energy.

✅ Judges call minister's decision unreasonable, unfair

✅ EDP Renewables to restart construction near Cornwall

✅ 100 MW, 29 turbines; costs awarded, appeal considered

 

Construction of a wind farm in eastern Ontario, as wind power makes gains nationwide, will move ahead after a court quashed a provincial government decision to cancel the project.

In a ruling released Wednesday, a panel of Ontario Superior Court judges said the province's decision to scrap the Nation Rise Wind Farm in December 2019 did not meet the proper requirements.

At the time, Environment Minister Jeff Yurek revoked the approvals of the project near Cornwall, Ont., citing the risk to three bat species.

That decision came despite a ruling from the province's Environmental Review Tribunal that determined the risk the project posed to the bat population was negligible.

The judges said the minister's decision was "unreasonable" and "procedurally unfair."

"The decision does not meet requirements of transparency, justification, and intelligibility, as the Minister has failed to adequately explain his decision," the judges wrote in their decision.

The company behind the project, EDP Renewables, said the 29-turbine wind farm was almost complete when its approval was revoked in December, even as Alberta saw TransAlta scrap a wind farm in a separate development.

The company said Thursday it plans to restart construction on the 100-megawatt wind farm.

"EDPR is eager to recommence construction of the Nation Rise Wind Farm, which will bring much-needed jobs and investment to the community," the company said in a statement. "This delay has resulted in unnecessary expenditures to-date, at a time when governments and businesses should be focused on reducing costs and restarting the economy."

A spokesman for Yurek said the government is disappointed with the outcome of the case but did not comment on a possible appeal.

"At this time, we are reviewing the decision and are carefully considering our next steps," Andrew Buttigieg said in a statement.

NDP climate change critic Peter Tabuns said the court decision is an embarrassment for the minister and the government. He urged the government not to pursue an appeal.

Yurek "was found to have ignored the evidence and the facts," he said. "They didn't just lose, their case collapsed. They had nothing to stand on. Taking this to appeal would be a complete and total waste of money."

Green party Leader Mike Schreiner said the ruling proves the government was acting based on ideology over evidence when it revoked the project's approval.

"As we shift towards a post-COVID recovery, we need the Ford government to give up the irrational crusade against affordable and reliable clean energy," Schreiner said in a statement.

Last year, the NDP revealed the province had spent $231 million to cancel more than 750 renewable energy contracts, a move Ford said he was proud of, shortly after winning the 2018 election.

The Progressive Conservatives have blamed the previous Liberal government, as leadership candidates debate how to fix power, for signing the bad energy deals while the province had an oversupply of electricity.

The Ford government, amid a new stance on wind power, has also said that by cancelling the contracts it would ultimately save ratepayers $790 million -- a figure industry officials have disputed.

At the time of the wind farm cancellation, the government also said it would introduce legislation that would protect consumers from any costs incurred, though a developer warned cancellations could exceed $100M at the time.

It has since acknowledged it will have to pay some companies to cancel the deals and set aside $231 million to reach agreements with those firms, and more recently has moved to reintroduce renewable projects in some cases.

On Wednesday, the judges awarded Nation Rise $126,500 in costs, which the government will have to pay.

 

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Electricity bills on the rise in Calgary after

Calgary Electricity Price Increase signals higher ENMAX bills as grid demand surges; wholesale market volatility, fixed vs floating rates, kWh costs, and transmission charges drive above-average pricing across Alberta this winter.

 

Key Points

A market-led rise in Calgary power rates as grid demand and wholesale volatility affect fixed and floating plans.

✅ ENMAX warns of higher winter prices amid record grid demand

✅ Fixed rates hedge wholesale volatility; floating tracks spot market

✅ Transmission and distribution fees rise 5-10 percent annually

 

Calgarians should expect to be charged more for their electricity bills amid significant demand on the grid and a transition to above-average rates across Alberta.

ENMAX, one of the most-used electricity providers in the city, has sent an email to customers notifying them of higher prices for the rest of the winter months.

“Although fluctuations in electricity market prices are normal, we have seen a general trend of increasing rates over time,” the email to customers read.

“The price volatility we are forecasting is due to market factors beyond a single energy provider, including but not limited to expectations for a colder-than-normal winter and changes in electricity supply and demand in Alberta’s wholesale market. ”

Earlier this month, the province set a record for electricity usage during a bitterly cold stretch of weather.

According to energy comparison website energyrates.ca, Alberta’s energy prices have increased by 34 per cent between November 2020 and 2021.

“One of the reasons that this increase seems so significant is we’re actually coming off of a low period in the market,” the site’s founder Joel MacDonald told Global News. “You’re seeing rates well below average transitioning to well above average.”

According to ENMAX’s rate in January, the price of electricity currently sits at 15.9 cents per kilowatt-hour, with an electricity price spike from 7.9 cents per kilowatt-hour last year.

MacDonald said prices for electricity have been relatively low since 2018 but a swing in the price of oil has created more activity in the province’s industrial sector, and in turn more demand on the power grid.

According to MacDonald, the price increase can also be attributed to the removal of a consumer price cap that limited regulated rates to 6.8 cents per kilowatt-hour for households and small businesses with lower demand, which, after the carbon tax was repealed, initially remained in place.

Although the cap was scrapped by the UCP three years ago, he said energy bills now depend on the rate set by the market.

“What’s increased now recently is actually the price per kilowatt, and the (transmission and distribution) charges have only increased, but annually they increase between five and 10 per cent,” MacDonald said. “So the portion of your bill that’s increasing is different than what Albertans are typically used to, or at least in recent memory.”

But Albertans do have options, MacDonald said.

As part of its email to customers, ENMAX sent a list of energy saving tips to reduce energy consumption in people’s homes, including using cold water for laundry and avoiding dryer use, energy-efficient lightbulbs and unplugging electronics when they are not in use.

Retailers also offer contracts with floating or fixed rates for consumers.

“Fixed rates, obviously, you’re going to pick your price. It’s going to be the same each and every single month,” MacDonald said. “Floating rate is based off the wholesale spot market, and that has been exceptionally high the last few months.”

He said consumers looking to save money when electricity prices are high should look into a fixed rate.

 

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Yet another Irish electricity provider is increasing its prices

Electric Ireland Electricity Price Increase stems from rising wholesale costs as energy suppliers adjust tariffs. Customers face higher electricity bills, while gas remains unchanged; switching provider could deliver savings during winter.

 

Key Points

A 4% increase in Electric Ireland electricity prices from 1 Feb 2018, driven by wholesale costs; gas unchanged.

✅ 4% electricity rise effective 1 Feb 2018

✅ Increase attributed to rising wholesale energy costs

✅ Switching supplier may reduce bills and boost savings

 

ELECTRIC IRELAND has announced that it will increase its household electricity prices by 4% from 1 February 2018.

This comes just a week after both Bord Gáis Energy and SSE Airtricity announced increases in their gas and electricity prices, while national efforts to secure electricity supplies continue in parallel.

Electric Ireland has said that the electricity price increase is unavoidable due to the rising wholesale cost of electricity, with EU electricity prices trending higher as well.

The electricity provider said it has no plans to increase residential gas prices at the moment.

Commenting on the latest announcement, Eoin Clarke, managing director of Switcher.ie, said: “This is the third largest energy supplier to announce a price increase in the last week, so the other suppliers are probably not far behind.

“The fact that the rise is not coming into effect until 1 February will be welcomed by Electric Ireland customers who are worried about the rising cost of energy as winter sets in,” he said.

However, any increase is still bad news, especially as a quarter of consumers (27%) say their energy bill already puts them under financial pressure, and EU energy inflation has disproportionately affected lower-income households.

According to Electric Ireland, this will amount to a €2.91 per month increase for an average electricity customer, amounting to €35 per year.

Meanwhile, SSE Airtricity’s change amounts to an increase of 90 cent per week or €46.80 per year for someone with average consumption on their 24hr SmartSaver standard tariff, far below the dramatic Spain electricity price surge seen recently.

Bord Gáis Energy said its announcement will increase a typical gas bill by €2.12 a month and a typical electricity bill by €4.77 a month, reflecting wider trends such as the Germany power price spike reported recently.

In a statement, Bord Gáis Energy said: “The changes, which will take effect from 1st November 2017, are due to significant increases in the wholesale cost of energy as well as higher costs associated with distributing energy on the gas and electricity networks.

“In percentage terms, the increase represents 3.4% in a typical customer’s gas bill and an increase of 5.9% in a typical customer’s electricity bill.”

Clark said that if customers haven’t switched electricity provider in over a year that they should review the deals available at the moment.

“The market is highly competitive so there are huge savings to be made by switching,” he said.

“All suppliers use the same cables to supply electricity to your home, so you don’t need to worry about any loss in service, and you could save up to 324 by switching from typical standard tariffs to the cheapest deals on the market.”

 

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Operating record for Bruce Power as Covid-19 support Council announced

Bruce Power Life-Extension Programme advances Ontario nuclear capacity through CANDU Major Component Replacement, reliable operation milestones, supply chain retooling for COVID-19 recovery, PPE production, ventilator projects, and medical isotope supply security.

 

Key Points

A program to refurbish CANDU reactors, extend asset life, and mobilize Ontario nuclear supply chain and isotopes.

✅ Extends CANDU units via Major Component Replacement

✅ Supports COVID-19 recovery with PPE and ventilator projects

✅ Boosts Ontario energy reliability and medical isotopes

 

Canada’s Bruce Power said on 1 May that unit 1 at the Bruce nuclear power plant had set a record of 624 consecutive days of reliable operation – the longest since it was returned to service in 2012.

It exceeded Bruce 8’s run of 623 consecutive days between May 2016 and February 2018. Bruce 1, a Candu reactor, was put into service in 1977. It was shut down and mothballed by the former Ontario Hydro in 1997, and was refurbished and returned to service in 2012 by Bruce Power.

Bruce units 3 and 4 were restarted in 2003 and 2004. They are part of Bruce Power’s Life-Extension Programme, and future planning such as Bruce C project exploration continues across the fleet, with units 3 and 4 to undergo Major Component Replacement (MCR) Projects from 2023-28, adding about 30 years of life to the reactors.

The refurbishment of Bruce 6 has begun and will be followed by MCR Unit 3 which is scheduled to begin in 2023. Nuclear power accounts for more than 60% of Ontario’s supply, with Bruce Power providing more than 30%   of the province’s electricity.

Set up of Covid recovery council
On 30 April, Bruce Power announced the establishment of the Bruce Power Retooling and Economic Recovery Council to leverage the province’s nuclear supply chain to support Ontario’s fight against Covid-19 and to help aid economic recovery.

Bruce Power’s life extension programme is Canada’s second largest infrastructure project and largest private sector infrastructure programme. It is creating 22,000 direct and indirect jobs, delivering economic benefits that are expected to contribute $4 billion to Ontario’s GDP and $8-$11 billion to Canada’s gross domestic product (GDP), Bruce Power said.

“With 90% of the investment in manufactured goods and services coming from 480 companies in Ontario and other provinces, including recent manufacturing contracts with key suppliers, we can harness these capabilities in the fight against Covid-19, and help drive our economic recovery,” the company said.

“An innovative and dynamic nuclear supply chain is more important than ever in meeting this new challenge while successfully implementing our mission of providing clean, reliable, flexible, low-cost nuclear energy and a global supply of medical isotopes,” said Bruce Power president and CEO Mike Rencheck. “We are mobilising a great team with our extended supply chain, which spans the province, to assist in the fight against Covid-19 and to help drive our economic recovery in the future.”

Greg Rickford, the Minister of Energy, Mines, Northern Development, and Minister of Indigenous Affairs, said the launch of the council is consistent with Ontario’s focus to fight Covid-19 as a top priority and a look ahead to economic recovery, and initiatives like Pickering life extensions supporting long-term system reliability.

The creation of the Council was announced during a live event on Bruce Power's Facebook page, in which Rencheck was joined by Associate Minister of Energy Bill Walker and Rocco Rossi, the president and CEO of the Ontario Chamber of Commerce.

Walker reiterated the Government of Ontario’s commitment to nuclear power over the long term and to the life extension programme, including the Pickering B refurbishment as part of this strategy.

The Council, which will be formed for the duration of the pandemic and will include of all of Bruce Power’s Ontario-based suppliers, will focus on the continued retooling of the supply chain to meet front-line Covid-19 needs to contribute to the province’s economy recovery in the short, medium and long term.

New uses for nuclear medical applications will be explored, including isotopes for the sterilisation of medical equipment and long-term supply security.

The supply chain will be leveraged to support the health care sector through the rapid production of medical Personal Protection Equipment for front line-workers and large-scale PPE donations to communities as well as participation in pilot projects to make ventilators within the Bruce Power supply chain or help identify technology to better utilise existing ventilators;

“Buy Local” tools and approaches will be emphasised to ensure small businesses are utilised fully in communities where nuclear suppliers are located.

The production of hand sanitiser and other cleaning products will be facilitated for distribution to communities.

 

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B.C. government freezes provincial electricity rates

BC Hydro Rate Freeze delivers immediate relief on electricity rates in British Columbia, reversing a planned 3% hike, as BCUC oversight, a utility review, and Site C project debates shape provincial energy policy.

 

Key Points

A one-year provincial policy halting BC Hydro electricity rate hikes while a utility review finds cost savings.

✅ Freeze replaces planned 3% hike approved by BCUC.

✅ Government to conduct comprehensive BC Hydro review.

✅ Critics warn $150M revenue loss impacts capital projects.

 

British Columbia's NDP government has announced it will freeze BC Hydro rates effective immediately, fulfilling a key election promise.

Energy, Mines and Petroleum Resources Minister Michelle Mungall says hydro rates have gone up by more than 24 per cent in the last four years and by more than 70 per cent since 2001, reflecting proposals such as a 3.75% increase over two years announced previously.

"After years of escalating electricity costs, British Columbians deserve a break on their bills," Mungall said in a news release.

BC Hydro had been approved by the B.C. Utilities Commission to increase the rate by three per cent next year, but Mungall said it will pull back its request in order to comply with the freeze.

In the meantime, the government says it will undertake a comprehensive review of the utility meant to identify cost-savings measures for customers often asked to pay an extra $2 a month on electricity bills.

The Liberal critic, Tracy Redies, says the one year rate freeze is going to cost BC Hydro, calling it a distraction from the bigger issue of the future of the Site C project and the oversight of a BC Hydro fund surplus as well.

"A one year rate freeze costs Hydro $150 million," Redies said. "That means there's $150 million less to invest in capital projects and other investments that the utility needs to make."

"This is putting off decisions that should be made today to the future."

Recommendations from the review — including possible new rates — will be implemented starting in April 2019.

 

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