Brazil revives nuclear power plant

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A government-controlled firm is forging ahead with plans to resume expansion of Brazil's nuclear power program.

The Brazilian government has authorized the company, Electronuclear, to go back to work on the nation's third nuclear power plant.

Work on the Angra 3 reactor, near Rio de Janeiro, has been stalled for 22 years by a lack of money and political issues.

But the administration of President Luiz Ignacio Lula da Silva is turning to nuclear power to meet electricity needs that are growing with the country's booming economy.

"Things have changed a lot, and today it's clearer to everyone that nuclear energy has a role to play in the Brazilian electrical system, just like the other forms of producing electricity, which can't be dismissed," said Leonam Guimaraes, an Electronuclear spokesman.

Brazil is the 10th-largest energy consumer in the world, according to the U.S. Department of Energy. It's the third-largest consumer in the Western Hemisphere, behind the United States and Canada.

The two operational nuclear power plants in Brazil supply about 3 percent of the nation's electricity, according to the International Atomic Energy Agency.

The other countries in the Western Hemisphere that use nuclear power to generate electricity are Mexico (where nuclear power generates 5 percent of electricity), Argentina (7 percent), Canada (16 percent) and the United States (19 percent), according to the atomic agency.

France generates more electrical power with nuclear reactors than any other nation (78 percent), followed by Lithuania (72 percent), Slovakia (57 percent) and Belgium (54 percent), the agency said.

Brazil's two reactors went into use in 1985 and 2000. They supply about half the electrical power used in the state of Rio de Janeiro, according to Electronuclear.

Electronuclear plans to begin construction work on Angra 3 in February and hopes that it will generate electricity by 2014, when Brazil will host the FIFA World Cup soccer tournament.

Environmental activists say authorities have not adequately planned an effective response in the event of an accidental release of radiation from Angra Three.

They also warn that building a third plant could adversely affect the environment, but Electronuclear has pledged to comply with each of 60 conditions the Brazilian government set in granting the country a license to restart work on the third reactor.

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New bill would close loophole that left hundreds of Kentucky miners with cold checks

Kentucky Coal Wage Protection Bill strengthens performance bond enforcement, links Energy and Environment Cabinet and Labor Cabinet notifications, addresses Blackjewel bankruptcy fallout, safeguards unpaid miners, ties mining permits to payroll bonds, penalizes violators via revocations.

 

Key Points

A Kentucky plan to enforce wage bonds and revoke mining permits to protect miners after bankruptcies.

✅ Requires wage bonds for firms under 5 years

✅ Links Energy and Environment Cabinet and Labor Cabinet

✅ Violators face permit revocation in 90 days

 

Following the high-profile bankruptcy of a coal company that left hundreds of Kentucky miners with bad checks last month, Sen. Johnny Ray Turner (D-Prestonsburg) said he will pre-file a bill Thursday aimed at closing a loophole that allowed the company to operate in violation of state law.

The bill would also compel state agencies to determine whether other companies are currently in violation of the law, and could revoke mining permits if the companies don't comply.

Turner's bill would amend an already-existing law that requires coal and construction companies that have been operating in Kentucky for less than five years to post a performance bond to protect wages if the companies cease their operations.

Blackjewel LLC., which employed hundreds of miners in Eastern Kentucky, failed to post that bond. When it shut its mines down and filed for bankruptcy last month, it left hundreds of miners without payment for 3 weeks and one day of work.

The bond issue has sparked criticism from various state officials, including Attorney General Andy Beshear, who said Tuesday that he would investigate whether other companies are currently in violation, similar to an external investigation of utility workers in another jurisdiction.

Blackjewel issued cold checks to its employees June 28, and when the checks bounced days later, many employees were left with bank accounts overdrawn by more than $1,000. The bankruptcy left many miners and their families with concerns over upcoming bill and mortgage payments, and, as unpaid days off at utilities elsewhere show, the strain on workers can be severe, and fostered a ongoing protest that blocked a train hauling coal from one of the company's Harlan County mines.

Blackjewel had been operating in Kentucky for about two years before it filed for bankruptcy, so it should have paid the performance bond, according to state law.

David A. Dickerson, the Kentucky Labor Cabinet Secretary, said the law as it's currently written does not set up any mechanism that notifies the cabinet, or provides comparable public reporting at large utility projects elsewhere, when a company opens in Kentucky that is supposed to pay the bond.

That allowed Blackjewel to operate for two years without any protection for workers before it closed its mines. Had the company posted the bond according to state law, miners likely would have been paid for the work they had already completed, officials said.

The law requires companies to set aside enough money to cover payroll for four weeks.

Turner's bill would compel the state Energy and Environment Cabinet to notify the Labor Cabinet's Department of Workplace Standards of any application for a mining permit from a company that has been doing business in Kentucky for less than five years.

It also compels the EEC to notify the Labor Cabinet of any companies that already have permits that are subject to the bond.

"It should have already been that way, but I'm happy so our children don't have to go through this," said Jeff Willig, a former Blackjewel miner who helped launch the protest at the railroad.

Willig said he and other miners will continue to block the tracks until they receive payment for their past work.

Any company currently operating in violation of the law would have 90 days to become compliant before its mining permits are revoked. New companies that are applying for permits will be required post the bond before permits are issued.

"Hopefully it will take care of the loopholes that had been exploited by Blackjewel," Turner said.

The bill will be taken up by the legislature when it returns to session in January. It would also cover attorneys' fees if workers are forced to sue their employer to cover wages, underscoring broader worker safety concerns during health emergencies.

Turner said he has reached out to Republican leadership in the Senate, and expects the bill to have bipartisan support come January.

Turner announced the legislation at a press conference in Harlan, the county with the highest population of Blackjewel employees affected by the bankruptcy, and as prolonged utility outages after tornadoes have strained other Kentucky communities.

State rep. Angie Hatton (D-Whitesburg) was also in attendance, along with rep. Chris Fugate (R-Chavies) and state Sen. Morgan McGarvey (D-Louisville).

Hatton said the bankruptcy has had serious economic impact throughout Eastern Kentucky, including in Letcher County, which is home to more than 130 former Blackjewel workers.

"This is something that has done a lot of damage to Eastern Kentucky," Hatton said.

Hatton plans to file the same bill in the state House of Representatives.

Fugate commended community members in Harlan County and elsewhere who have banded together in support of the miners by donating children's clothing, school supplies, food and other goods, while other regions have created a coal transition fund to help displaced workers.

Mosley called the bankruptcy "totally unprecedented" and said the current performance bond law, which has been on-the-books since 1986, lacked the enforcement necessary to protect miners in bankruptcies like Blackjewel's, even as a workplace safety fine in another case shows regulatory consequences in other industries.

"There was a law, there wasn't good enough process," Mosley said.

Blackjewel received court approval to sell many of its mines last month, including many in Kentucky, to Kopper Glo Mining, LLC.

As part of the sale agreement, Kopper Glo said it would pay $450,000 to cover the past wages of Blackjewel miners, and collect a per ton fee accumulating up to $550,000 that it will also contribute to pay back wages.

That total $1 million is less than half of all back wages owed to Blackjewel miners, but attorneys who filed a class action suit against the company said miners have a priority lien on the purchase price. That could allow former Blackjewel employees to make good on their back wages as bankruptcy proceedings continue.

Mosley said he spoke with a Kopper Glo official Thursday, who said the company is working to re-open the mines as quickly as possible. The official did not give an exact timeline.

 

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Financial update from N.L energy corp. reflects pandemic's impact

Nalcor Energy Pandemic Loss underscores Muskrat Falls delays, hydroelectric risks, oil price shocks, and COVID-19 impacts, affecting ratepayers, provincial debt, timelines, and software commissioning for the Churchill River project and Atlantic Canada subsea transmission.

 

Key Points

A $171M Q1 2020 downturn linked to COVID-19, oil price collapse, and Muskrat Falls delays impacting schedules and costs.

✅ Q1 2020 profit swing: +$92M to -$171M amid oil price crash

✅ Muskrat Falls timeline slips; cost may reach $13.1B

✅ Software, workforce, COVID-19 constraints slow commissioning

 

Newfoundland and Labrador's Crown energy corporation reported a pandemic-related profit loss from the first quarter of 2020 on Tuesday, along with further complications to the beleaguered Muskrat Falls hydroelectric project.

Nalcor Energy recorded a profit loss of $171 million in the first quarter of 2020, down from a $92 million profit in the same period last year, due in part to falling oil prices during the COVID-19 pandemic.

The company released its financial statements for 2019 and the first quarter of 2020 on Tuesday, and officials discussed the numbers in a livestreamed presentation that detailed the impact of the global health crisis on the company's operations.

The loss in the first quarter was caused by lower profits from electricity sales and a drop in oil prices due to the pandemic and other global events, company officials said.

The novel coronavirus also added to the troubles plaguing the Muskrat Falls hydroelectric dam on Labrador's Churchill River, amid Quebec-N.L. energy tensions that long predate the pandemic.

Work at the remote site stopped in March over concerns about spreading the virus. Operations have been resuming slowly, with a reduced workforce tackling the remaining jobs.

Officials with Nalcor said it will likely be another year before the megaproject is complete.

CEO Stan Marshall estimates the months of delays could bring the total cost to $13.1 billion including financing, up from the previous estimate of $12.7 billion -- though the total impact of the coronavirus on the project's price tag has yet to be determined.

"If we're going to shut down again, all of that's wrong," Marshall said. "But otherwise, we can just carry on and we'll have a good idea of the productivity level. I'm hoping that by September we'll have a more definitive number here."

The 824 megawatt hydroelectric dam will eventually send power to Newfoundland, and later Nova Scotia, through subsea cables, even as Nova Scotia boosts wind and solar in its energy mix.

It has seen costs essentially double since it was approved in 2012, and faced significant delays even before pandemic-forced shutdowns in North America and around the world this spring.

Cost and schedule overruns were the subject of a sweeping inquiry that held hearings last year, while broader generation choices like biomass use have drawn scrutiny as well.

The commissioner's report faulted previous governments for failing to protect residents by proceeding with the project no matter what, and for placing trust in Nalcor executives who "frequently" concealed information about schedule, cost and related risks.

Some of the latest delays have come from challenges with the development of software required to run the transmission link between Labrador and Newfoundland, where winter reliability issues have been flagged in reports.

The software is still being worked out, Marshall said Tuesday, and the four units at the dam will come online gradually over the next year.

"It's not an all or nothing thing," Marshall said of the final work stages.
Nalcor's financial snapshot follows a bleak fiscal update from the province this month. The Liberal government reported a net debt of $14.2 billion and a deficit of more than $1.1 billion, even as a recent Churchill Falls deal promised new revenues for the province, citing challenges from pandemic-related closures and oil production shutdowns.

Finance Minister Tom Osborne said at the time that help from Ottawa will be necessary to get the province's finances back on track.

Muskrat Falls represents about one-third of the province's debt, and is set to produce more power than the province of about half a million people requires. Anticipated rate increases due to the ballooning costs and questions about Muskrat Falls benefits have posed a significant political challenge for the provincial government.

Ottawa has agreed to work with Newfoundland and Labrador on a rewrite of the project's financial structure, scrapping the format agreed upon in past federal-provincial loan agreements in order to ease the burden on ratepayers, while some argue independent planning would better safeguard ratepayers.

Marshall, a former Fortis CEO who was brought in to lead Nalcor in 2016, has called the project a "boondoggle" and committed to seeing it completed within four years. Though that plan has been disrupted by the pandemic, Marshall said the end is in sight.

"I'm looking forward to a year from now. And I hope to be gone," Marshall said.

 

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Prevent Summer Power Outages

Summer Heatwave Electricity Shutoffs strain utilities and vulnerable communities, highlighting energy assistance, utility moratoriums, cooling centers, demand response, and grid resilience amid extreme heat, climate change, and rising air conditioning loads.

 

Key Points

Service disconnections for unpaid bills during extreme heat, risking vulnerable households and straining power grids.

✅ Moratoriums and flexible payment plans reduce shutoff risk.

✅ Cooling centers and assistance programs protect at-risk residents.

✅ Demand response, smart grids, and efficiency ease peak loads.

 

As summer temperatures soar, millions of people across the United States face the grim prospect of electricity shutoffs due to unpaid bills, as heat exacerbates electricity struggles for many families nationwide. This predicament highlights a critical issue exacerbated by extreme weather conditions and economic disparities.

The Challenge of Summer Heatwaves

Summer heatwaves not only strain power grids, as unprecedented electricity demand has shown, but also intensify energy consumption as households and businesses crank up their air conditioning units. This surge in demand places considerable stress on utilities, particularly in regions unaccustomed to prolonged heatwaves or lacking adequate infrastructure to cope with increased loads.

Vulnerable Populations

The threat of electricity shutoffs disproportionately affects vulnerable populations, including low-income households who face sky-high energy bills during extreme heat, elderly individuals, and those with underlying health conditions. Lack of access to air conditioning during extreme heat can lead to heat-related illnesses such as heat exhaustion and heatstroke, posing serious health risks.

Economic and Social Implications

The economic impact of electricity shutoffs extends beyond immediate discomfort, affecting productivity, food storage, and the ability to work remotely for those reliant on electronic devices, while rising electricity prices further strain household budgets. Socially, the inability to cool homes and maintain basic comforts strains community resilience and exacerbates inequalities.

Policy and Community Responses

In response to these challenges, policymakers and community organizations advocate for measures to prevent electricity shutoffs during heatwaves. Proposed solutions include extending moratoriums on shutoffs, informed by lessons from COVID-19 energy insecurity measures, implementing flexible payment plans, providing financial assistance to at-risk households, and enhancing communication about available resources.

Public Awareness and Preparedness

Raising public awareness about energy conservation during peak hours and promoting strategies to stay cool without overreliance on air conditioning are crucial steps towards mitigating electricity demand. Encouraging energy-efficient practices and investing in renewable energy sources also contribute to long-term resilience against climate-driven energy challenges.

Collaborative Efforts

Collaboration between government agencies, utilities, nonprofits, and community groups is essential in developing comprehensive strategies to safeguard vulnerable populations during heatwaves, especially when systems like the Texas power grid face renewed stress during prolonged heatwaves. By pooling resources and expertise, stakeholders can better coordinate emergency response efforts, distribute cooling centers, and ensure timely assistance to those in need.

Technology and Innovation

Advancements in smart grid technology and decentralized energy solutions offer promising avenues for enhancing grid resilience and minimizing disruptions during extreme weather events. These innovations enable more efficient energy management, demand response programs, and proactive monitoring of grid stability, though some utilities face summer supply-chain constraints that delay deployments.

Conclusion

As summer heatwaves become more frequent and severe, the risk of electricity shutoffs underscores the urgent need for proactive measures to protect vulnerable communities. By prioritizing equity, sustainability, and resilience in energy policy and practice, stakeholders can work towards ensuring reliable access to electricity, particularly during times of heightened climate vulnerability. Addressing these challenges requires collective action and a commitment to fostering inclusive and sustainable solutions that prioritize human well-being amid changing climate realities.

 

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Hydro One CEO's $4.5M salary won't be reduced to help cut electricity costs

Hydro One CEO Salary shapes debate on Ontario electricity costs, executive compensation, sunshine list transparency, and public disclosure rules, as officials argue pay is not driving planned hydro rate cuts for consumers.

 

Key Points

Hydro One CEO pay disclosed in public filings, central to debates on Ontario electricity rates and transparency.

✅ 2016 compensation: $4.5M (salary + bonuses)

✅ Excluded from Ontario's sunshine list after privatization

✅ Government says pay won't affect planned hydro rate cuts

 

The $4.5 million in pay received by Hydro One's CEO is not a factor in the government's plan to cut electricity costs for consumers, an Ontario cabinet minister said Thursday amid opposition concerns about the executive's compensation and wider sector pressures such as Manitoba Hydro's rising debt in other provinces.

Treasury Board President Liz Sandals made her comments on the eve of the release of the province's so-called sunshine list.

The annual disclosure of public-sector salaries over $100,000 will be released Friday, but Hydro One salaries such as that of company boss Mayo Schmidt won't be on it.Though the government still owns most of Hydro One — 30 per cent has been sold — the company is required to follow the financial disclosure rules of publicly traded companies, which means disclosing the salaries of its CEO, CFO and next three highest-paid executives, and financial results such as a Q2 profit decline in filings.

New filings show that Schmidt was paid $4.5 million in 2016 — an $850,000 salary plus bonuses — and those top five executives were paid a total of about $11.7 million. 

"Clearly that's a very large amount," said Sandals. Sandals wouldn't say whether or not she thought the pay was appropriate at a time when the government is trying to reduce system costs and cut people's hydro bills.

Mayo Schmidt, President & CEO of Hydro One Limited and Hydro One Inc. (Hydro One )

But she suggested the CEO's salary was not a factor in efforts to bring down hydro prices, even as Hydro One shares fell after a leadership shakeup in a later period. "The CEO salary is not part of the equation of will 'we be able to make the cut,"' she said. "Regardless of what those salaries are, we will make a 25-per-cent-off cut." The cut coming this summer is actually an average of 17 per cent -- the 25-per-cent figure factors in an earlier eight-per-cent rebate.

NDP Leader Andrea Horwath, who has proposed to make hydro public again in Ontario, said the executive salaries are relevant to cutting hydro costs.

"All of this is cost of operating the electricity system, it's part of the operating of Hydro One and so of course those increased salaries are going to impact the cost of our electricity," she said.

Schmidt was appointed Aug. 31, 2015, and in the last four months of that year earned $1.3 million, but the former CEO was paid $745,000 in 2014. About 3,800 workers were paid over $100,000 that year, none of whom will be on the sunshine list this year.

Progressive Conservative energy critic Todd Smith has a private member's bill that would put Hydro One salaries back on the list, amid investor concerns about Hydro One that cite too many unknowns.

"The Wynne Liberals don't want the people of Ontario to know that their rates have helped create a new millionaire's club at Hydro One," Smith said. "Hydro One is still under the majority ownership of the public, but Premier Kathleen Wynne has removed these salaries from the public's watchful eye."

The previous sunshine list showed 115,431 people were earning more than $100,000 — an increase of nearly 4,000 people despite the fact 3,774 Hydro One workers were not on the list for the first time.

Tom Mitchell, the former CEO at Ontario Power Generation who resigned last summer, topped the 2015 list at $1.59 million.

 

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Alberta set to retire coal power by 2023, ahead of 2030 provincial deadline

Alberta coal phaseout accelerates as utilities convert to natural gas, cutting emissions under TIER regulations and deploying hydrogen-ready, carbon capture capable plants, alongside new solar projects in a competitive, deregulated electricity market.

 

Key Points

A provincewide shift from coal to natural gas and renewables, cutting power emissions years ahead of the 2030 target.

✅ Capital Power, TransAlta converting coal units to gas

✅ TIER pricing drives efficiency, carbon capture readiness

✅ Hydrogen-ready turbines, solar projects boost renewables

 

Alberta is set to meet its goal to eliminate coal-fired electricity production years earlier than its 2030 target, amid a broader shift to cleaner energy in the province, thanks to recently announced utility conversion projects.

Capital Power Corp.’s plan to spend nearly $1 billion to switch two coal-fired power units west of Edmonton to natural gas, and stop using coal entirely by 2023, was welcomed by both the province and the Pembina Institute environmental think-tank.

In 2014, 55 per cent of Alberta’s electricity was produced from 18 coal-fired generators. The Alberta government announced in 2015 it would eliminate emissions from coal-fired electricity generation by 2030.

Dale Nally, associate minister of Natural Gas and Electricity, said Friday that decisions by Capital Power and other utilities to abandon coal will be good for the environment and demonstrates investor confidence in Alberta’s deregulated electricity market, where the power price cap has come under scrutiny.

He credited the government’s Technology Innovation and Emissions Reduction (TIER) regulations, which put a price on industrial greenhouse gas emissions, as a key factor in motivating the conversions.

“Capital Power’s transition to gas is a great example of how private industry is responding effectively to TIER, as it transitions these facilities to become carbon capture and hydrogen ready, which will drive future emissions reductions,” Nally said in an email.

Capital Power said direct carbon dioxide emissions at its Genesee power facility near Edmonton will be about 3.4 million tonnes per year lower than 2019 emission levels when the project is complete.

It says the natural gas combined cycle units it’s installing will be the most efficient in Canada, adding they will be capable of running on 30 per cent hydrogen initially, with the option to run on 95 per cent hydrogen in future with minor investments.

In November, Calgary-based TransAlta Corp. said it will end operations at its Highvale thermal coal mine west of Edmonton by the end of 2021 as it switches to natural gas at all of its operated coal-fired plants in Canada four years earlier than previously planned.

The Highvale surface coal mine is the largest in Canada, and has been in operation on the south shore of Wabamun Lake in Parkland County since 1970.

The moves by the two utilities and rival Atco Ltd., which announced three years ago it would convert to gas at all of its plants by this year, mean significant emissions reduction and better health for Albertans, said Binnu Jeyakumar, director of clean energy for Pembina.

“Alberta’s early coal phaseout is also a great lesson in good policy-making done in collaboration with industry and civil society,” she said.

“As we continue with this transformation of our electricity sector, it is paramount that efforts to support impacted workers and communities are undertaken.”

She added the growing cost-competitiveness of renewable energy, such as wind power, makes coal plant retirements possible, applauding Capital Power’s plans to increase its investments in solar power.

In Ontario, clean power policy remains a focus as the province evaluates its energy mix.

The company announced it would go ahead with its 75-megawatt Enchant Solar power project in southern Alberta, investing between $90 million and $100 million, and that it has signed a 25-year power purchase agreement with a Canadian company for its 40.5-MW Strathmore Solar project now under construction east of Calgary.
 

 

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Gaza’s sole electricity plant shuts down after running out of fuel

Gaza Power Plant Shutdown underscores the Gaza Strip's fuel ban, Israeli blockade, and electricity crisis, cutting megawatts, disrupting hospitals and quarantine centers, and exposing fragile energy supply, GEDCO warnings, and public health risks.

 

Key Points

An abrupt halt of Gaza's sole power plant due to a fuel ban, deepening the electricity crisis and straining hospitals.

✅ Israeli fuel ban halts Gaza's only power plant

✅ Available supply drops far below 500 MW demand

✅ Hospitals and COVID-19 quarantine centers at risk

 

The only electricity plant in the Gaza Strip shut down yesterday after running out of fuel banned from entering the besieged enclave by the Israeli occupation, Gaza Electricity Distribution Company announced.

“The power plant has shut down completely,” the company said in a brief statement, as disruptions like China power cuts reveal broader grid vulnerabilities.

Israel banned fuel imports into Gaza as part of punitive measures over the launching incendiary balloons from the Strip.

On Sunday, GEDCO warned that the industrial fuel for the electricity plant would run out, mirroring Lebanon's fuel shortage challenges, on Tuesday morning.

Since 2007, the Gaza Strip suffered under a crippling Israeli blockade that has deprived its roughly two million inhabitants of many vital commodities, including food, fuel and medicine, and regional strains such as Iraq's summer electricity needs highlight broader power insecurity.

As a result, the coastal enclave has been reeling from an electricity crisis, similar to when the National Grid warned of short supply in other contexts.

The Gaza Strip needs some 500 megawatts of electricity – of which only 180 megawatts are currently available – to meet the needs of its population, while Iran supplies about 40% of Iraq's electricity in the region.

Spokesman of the Ministry of Health in Gaza, Ashraf Al Qidra, said the lack of electricity undermines offering health services across Gaza’s hospitals.

He also warned that the lack of electricity would affect the quarantine centres used for coronavirus patients, reinforcing the need to keep electricity options open during the pandemic.

Gaza currently has three sources of electricity: Israel, which provides 120 megawatts and is advancing coal use reduction measures; Egypt, which supplies 32 megawatts; and the Strip’s sole power plant, which generates between 40 and 60 megawatts.

 

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