African nations protest low emission targets

German Energy Price Brakes harness price signals in a market-based policy, cutting gas consumption, preserving industrial output, and supporting CO2 reduction, showcasing Germany's resilience and adaptation while protecting households and businesses across Europe.

Key Points

Fixed-amount subsidies preserving price signals to curb gas use, shield consumers, and sustain industrial output.

✅ Maintains incentives via market-based price signals

✅ Cuts gas consumption without distorting EU markets

✅ Protects households and industry while curbing CO2

German industry and society are once again proving much more resilient and adaptable than certain people feared. Horror scenarios of a dangerous energy rationing or a massive slump in our economy have often been bandied about. But we are nowhere near that. With a challenging year just behind us, this is good news — not only for Germany, but also for Europe, where France-Germany energy cooperation has strengthened solidarity.

Companies and households reacted swiftly to the sharp increases in energy prices, in line with momentum in the global energy transition seen across markets. They installed more efficient heating or production facilities, switched to alternatives and imported intermediate products. The results are encouraging: German households and businesses have reduced gas consumption significantly, despite recent cold weather. From the start of the war in Ukraine to mid-December industrial gas consumption in Germany was (temperature-adjusted) around 20 per cent lower than the average level for the preceding three years. Even if some firms have cut back production, especially in energy-intensive sectors, industrial output as a whole has only fallen by about 1 per cent since the start of 2022. Added to this, in a survey released by the Ifo institute in November, over a third of German companies saw the potential to reduce gas consumption further without endangering output.

Instead of imposing excessive laws and regulations, we have relied on price signals and the prudence of market participants to create the right incentives and reduce gas consumption, as falling costs like record-low solar power prices continue to reinforce those signals across sectors.

We will follow this approach in coming months, when energy savings will remain important, even as the EU electricity outlook anticipates sharply higher demand by 2050. Our latest relief measures will not distort price signals. To this end, the Bundestag approved gas and electricity price brakes in its final session in 2022. They are designed to function without any intervention in markets or prices. This system will pay out a fixed amount relative to previous years’ consumption and the current difference to a reference price — regardless of current consumption.

Energy price brakes are the main component of Germany’s “protective shield”, which makes up to €200bn available for measures in 2022 to 2024. Seen in relation to the German economy’s size, its past heavy reliance on Russian energy imports and the fact that the measures will expire in 2024, these are balanced and expedient mechanisms. In contrast to instruments used in other countries, our new arrangements will not affect the price formation process driven by supply and demand, or on incentives to save gas. Companies and households will continue to save the full market price when they reduce consumption by a unit of gas or electricity. In this way, the price brakes also avoid the creation of additional demand for gas at the expense of consumers in other European countries, even as Europe’s Big Oil turning electric signals broader structural shifts in energy markets. No one need fear that competition will be distorted or that gas will be bought up. Indeed, a recent IMF working paper on cushioning the impact of high energy prices on households explicitly praises the German energy price brakes.

Current developments confirm the effectiveness of a market-based approach — and show that we should also rely on price signals when it comes to reducing CO₂ emissions, as suggested by IEA CO2 trends in recent years. Last year, households and companies had only a few weeks to adapt, yet we have already seen a strong response. The effect of CO₂ prices can be even stronger, as adaptation is possible over a much longer time and they additionally affect expectations and long-term decisions. Regulatory interventions and subsidy schemes, even if well targeted, cannot compete with market co-ordination and incentives that support individual decision-making and promote innovation.

Europe and Germany can weather this crisis without a collapse in industrial production. We also have an opportunity to deal efficiently with the move to climate neutrality, aligned with Germany’s hydrogen strategy for imported low-carbon fuels. In both cases, we should have confidence in price signals as well as in the power of people and business to innovate and adapt.

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Ontario Hydro Disconnection Ban ends May 1, prompting utilities and Hydro One to push payment plans, address arrears, and link low-income assistance, as Sudbury officials urge customers to avoid spring electricity disconnections.

Key Points

A seasonal policy halting winter shutoffs in Ontario, ending May 1 as utilities emphasize payment plans and assistance.

✅ Disconnections resume after winter moratorium ends May 1.

✅ Utilities offer payment plans, arrears management, relief funds.

✅ Hydro One delays shutoffs until June 1; arrears down 60%.

The first of May has taken on new meaning this year in Ontario.

It's when the province's ban on hydro disconnections during the winter months comes to an end, even as Ontario considers extending moratoriums in some cases.

Wendy Watson, the director of communications at Greater Sudbury Utilities, says signs of the approaching deadline could be seen in their office of the past few weeks.

"We've had quite an active stream of people into our front office to catch up on their accounts and also we've had a lot of people calling us to make payment arrangements or pay their bill or deal with their arrears," she says.

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Watson says there are 590 customers in Sudbury who could face possible disconnection this spring, compared with just 60 when the ban started in November.

"They will put off until tomorrow what they can avoid today," she says.

Watson says they are hoping to work with customers to figure payment plans with more choice and flexibility and avoid the need to cut power to certain homes and businesses. 

"As we like to say we're in the distribution of energy business, not the disconnection of energy business. We want you to be able to turn the lights on," she says.

Joseph Leblanc from the Social Planning Council of Sudbury says the winter hydro disconnection ban is one of several government measures that keep low income families on the brink of disaster. (CBC)

Hydro One executive vice-president of customer care Ferio Pugilese, whose utility later extended disconnection bans across its service area, tells a different story.

He says the company has worked hard to configure payment plans for customers over the last three years amid unchanged peak-rate policies and find ways for them to pay "that fit their lifestyle."

"The threat of a disconnection is not on its own something that's going to motivate someone to pay their bills," says Pugilese.

He says Hydro One is also sending out notices this spring, but won't begin cutting anyone off until June 1st.

He says that disconnections and the amount owing from outstanding bills to Hydro One are down 60 per cent in the last year. 

Ontario Energy Minister Glenn Thibeault says there is plenty of help from government programs and utility financing options like Hydro One's relief fund for those having trouble paying their power bills. (CBC)

Sudbury MPP and Energy Minister Glenn Thibeault says his hope is that people having trouble paying their power bills will talk to their hydro utility and look at the numerous programs the government offers to help low-income citizens.

"You know, I really want every customer to have a conversation with their local utility about getting back on track and we do have those programs in place," he says.

However, Joseph Leblanc, the executive director of the Social Planning Council of Sudbury, says the winter disconnection ban is just another government policy that keeps the poor on the brink of disaster.

"It's a feel good story for the government to say that, but it's a band-aid solution. We can stop the bleeding for a little while, make sure people aren't freezing to death in Ontario," he says. 

"People choose between rent, hydro, medicine, food, and there's an option for one of those to take some pressure off for a little while."

Instead, Leblanc would like to see the government fast track the province-wide implementation of the basic income program it's testing out in a few cities. 

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Vogtle Units 3 and 4 are Westinghouse AP1000 nuclear reactors under construction in Waynesboro, Georgia, led by Southern Nuclear, Georgia Power, and Bechtel, adding 2,234 MWe of carbon-free baseload power with DOE loan guarantees.

Key Points

Vogtle Units 3 and 4 are AP1000 reactors in Georgia delivering 2,234 MWe of low-carbon baseload electricity.

✅ Each unit: Westinghouse AP1000, 1,117 MWe capacity.

✅ Managed by Southern Nuclear, built by Bechtel.

✅ DOE loan guarantees support financing and risk.

Construction is ongoing for two new nuclear reactors, Units 3 and 4, at Georgia Power's Alvin W. Vogtle Electric Generating Plant in Waynesboro, Ga. the first new nuclear reactors to be constructed in the United Stated in 30 years, mirroring a new U.S. reactor startup that will provide electricity to more than 500,000 homes and businesses once operational.

Construction on Unit 3 started in March 2013 with an expected completion date of November 2021. For Unit 4, work began in November 2013 with a targeted delivery date of November 2022. Each unit houses a Westinghouse AP1000 (Advanced Passive) nuclear reactor that can generate about 1,117 megawatts (MWe). The reactor pressure vessels and steam generators are from Doosan, a South Korean firm.

The pouring of concrete was delayed to 2013 due to the United States Nuclear Regulatory Commission issuing a license amendment which permitted the use of higher-strength concrete for the foundations of the reactors, eliminating the need to make additional modifications to reinforcing steel bar.

The work is occurring in the middle of an operational nuclear facility, and the construction area contains many cranes and storage areas for the prefabricated parts being installed. Space also is needed for various trucks making deliveries, especially concrete.

The reactor buildings, circular in shape, are several hundred feet apart from one another and each one has an annex building and a turbine island structure. The estimated total price for the project is expected in the $18.7 billion range. Bechtel Corporation, which built Units 1 and 2, was brought in January 2017 to take over the construction that is being overseen by Southern Nuclear Operating Company (SNOC), which operates the plant.

The project will require the equivalent of 3,375 miles of sidewalk; the towers for Units 3 and 4 are 60 stories high and have two million pound CA modules; the office space for both units is 300,000 sq. ft.; and there are more than 8,000 construction workers over 30 percent being military veterans. The new reactors will create 800 permanent jobs.

Southern Nuclear and Georgia Power took over management of the construction project in 2017 after Westinghouse's Chapter 11 bankruptcy. The plant, built in the late 1980s with Unit 1 becoming operational in 1987 and Unit 2 in 1989, is jointly owned by Georgia Power (45.7 percent), Oglethorpe Power Corporation (30 percent), Municipal Electric Authority of Georgia (22.7 percent) and Dalton Utilities (1.6 percent).

"Significant progress has been made on the construction of Vogtle 3 and 4 since the transition to Southern Nuclear following the Westinghouse bankruptcy," said Paul Bowers, Chairman, President and CEO of Georgia Power. "While there will always be challenges in building the first new nuclear units in this country in more than 30 years, we remain focused on reducing project risk and maintaining the current project momentum in order to provide our customers with a new carbon-free energy source that will put downward pressure on rates for 60 to 80 years."

The Vogtle and Hatch nuclear plants currently provide more than 20 percent of Georgia's annual electricity needs. Vogtle will be the only four-unit nuclear facility in the country. The energy is needed to meet the rising demand for electricity as the state expects to have more than four million new residents by 2030.

The plant's expansion is the largest ongoing construction project in Georgia and one of the largest in the state's history, while comparable refurbishments such as the Bruce reactor overhaul progress in Canada. Last March an agreement was signed to secure approximately $1.67 billion in additional Department of Energy loan guarantees. Georgia Power previously secured loan guarantees of $3.46 billion.

The signing highlighted the placement of the top of the containment vessel for Unit 3, echoing the Hinkley Point C roof lift seen in the U.K., which signified that all modules and large components had been placed inside it. The containment vessel is a high-integrity steel structure that houses critical plant components. The top head is 130 ft. in diameter, 37 ft. tall, and weighs nearly 1.5 million lbs. It is comprised of 58 large plates, welded together with each more than 1.5 in. thick.

"From the very beginning, public and private partners have stood with us," said Southern Company Chairman, President and CEO Tom Fanning. "Everyone involved in the project remains focused on sustaining our momentum."

Bechtel has completed more than 80 percent of the project, and the major milestones for 2019 have been met, aligning with global nuclear milestones reported across the industry, including setting the Unit 4 pressurizer inside the containment vessel last February, which will provide pressure control inside the reactor coolant system. More specialized construction workers, including craft labor, have been hired via the addition of approximately 300 pipefitters and 350 electricians since November 2018. Another 500 to 1,000 craft workers have been more recently brought in.

A key accomplishment occurred last December when 1,300 cu. yds. of concrete were poured inside the Unit 4 containment vessel during a 21-hour operation that involved more than 100 workers and more than 120 truckloads of concrete. In 2018 alone, more than 23,000 cu. yds. of concrete were poured part of the nearly 600,000 cu. yds. placed since construction started, and the installation of more than 16,200 yds. of piping.

Progress also has been solid for Unit 3. Last January the integrated head package (IHP) was set inside the containment vessel. The IHP, weighing 475,000 lbs. and standing 48 ft. tall, combines several separate components in one assembly and allows the rapid removal of the reactor vessel head during a refueling outage. One month earlier, the placement of the third and final ring for containment vessel, and the placement of the fourth and final reactor coolant pump (RCP, 375,000 lbs.), were executed.

"Weighing just under 2 million pounds, approximately 38 feet high and with a diameter of 130 feet, the ring is the fourth of five sections that make up the containment vessel," stated a Georgia Power press release. "The RCPs are mounted to the steam generator and serve a critical part of the reactor coolant system, circulating water from the steam generator to the reactor vessel, allowing sufficient heat transfer for safe plant operation. In the same month, the Unit 3 shield building with additional double-decker panels, was placed.

According to a construction update from Georgia Power, a total of eight six-panel sections have been placed, with each one measuring 20 ft. tall and 114 ft. wide, weighing up to 300,000 lbs. To date, more than half of the shield building panels have been placed for Unit 3. The shield building panels, fabricated in Newport News, Va., provide structural support to the containment cooling water supply and protect the containment vessel, which houses the reactor vessel.

Building the reactors is challenging due to the design, reflecting lessons from advanced reactors now being deployed. Unit 3 will have 157 fuel assemblies, with each being a little over 14 ft. long. They are crucial to fuelling the reactor, and once the initial fueling is completed, nearly one-third of the fuel assemblies will be replaced for each re-fuelling operation. In addition to the Unit 3 containment top, placement crews installed three low-pressure turbine rotors and the generator rotor inside the unit's turbine building.

Last November, major systems testing got underway at Unit 3 as the site continues to transition from construction toward system operations. The Open Vessel Testing will demonstrate how water flows from the key safety systems into the reactor vessel ensuring the paths are not blocked or constricted.

"This is a significant step on our path towards operations," said Glen Chick, Vogtle 3 & 4 construction executive vice president. "[This] will prepare the unit for cold hydro testing and hot functional testing next year both critical tests required ahead of initial fuel load."

It also confirms that the pumps, motors, valves, pipes and other components function as designed, a reminder of how issues like the South Carolina plant leak can disrupt operations when systems falter.

"It follows the Integrated Flush process, which began in August, to push water through system piping and mechanical components that feed into the Unit 3 reactor vessel and reactor coolant loops for the first time," stated a press release. "Significant progress continues ... including the placement of the final reinforced concrete portion of the Unit 4 shield building. The 148-cubic yard placement took eight hours to complete and, once cured, allows for the placement of the first course of double-decker panels. Also, the upper inner casing for the Unit 3 high-pressure turbine has been placed, signifying the completion of the centerline alignment, which will mean minimal vibration and less stress on the rotors during operations, resulting in more efficient power generation."

The turbine rotors, each weighing approximately 200 tons and rotating at 1,800 revolutions per-minute, pass steam through the turbine blades to power the generator.

The placement of the middle containment vessel ring for Unit 4 was completed in early July. This required several cranes to work in tandem as the 51-ft. tall ring weighed 2.4 million lbs. and had dozens of individual steel plates that were fabricated on site.

A key part of the construction progress was made in late July with the order of the first nuclear fuel load for Unit 3, which consists of 157 fuel assemblies with each measuring 14 ft. tall.

On May 7, Unit 3 was energized (permanently powered), which was essential to perform the testing for the unit. Prior to this, the plant equipment had been running on temporary construction power.

"[This] is a major first step in transitioning the project from construction toward system operations," Chick said.

Construction of the north side of the Unit 3 Auxiliary Building (AB) has progressed with both the floor and roof modules being set. Substantial work also occurred on the steel and concrete that forms the remaining walls and the north AB roof at elevation.

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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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Ford Oakville EV investment secures government funding, Unifor deal, and plant retooling, channeling $500 million plus $1.98 billion for Canadian electric vehicle manufacturing, Windsor engine contracts, and 2025 production, strengthening Ontario's auto industry.

Key Points

Government and Ford will retool Oakville for EVs, creating jobs under a Unifor deal and Windsor engine work.

✅ $500M government funding for plant retooling

✅ Ford commits $1.98B; five new EVs by 2025

✅ Unifor deal adds Windsor engine work, jobs

The federal government and Ontario have pledged to spend up to $500 million to make the Ford plant in Oakville, Ont., able to build electric vehicles, aligning with efforts to capitalize on the U.S. EV pivot underway.

The future of the plant has been a key question for Canada's automotive industry, as moves like GM's Ontario EV deal point to broader changes, ever since the Unifor union started negotiating with the automaker for a new three-year pact to cover the company's Canadian workforce.

The two sides struck a deal a few hours after a midnight strike deadline on Tuesday morning, one that will see the company commit $1.98 billion to build five new electric vehicles and an engine contract that could yield new EV jobs in Windsor, Ont.

Ford has previously committed to spending $11 billion US to develop and manufacture electric vehicles, but so far all of that money was earmarked for Ford plants in Mexico and the company's home state of Michigan.

"With Oakville gaining such a substantial portion of Ford's planned investment, the assembly plant and its workers are better set for employment going forward," said Sam Fiorani, vice-president of global forecasting at AutoForecast Solutions.

Unifor's 'unique' Ford deal includes 5 new electric vehicles in Oakville, engine for Windsor plants
Currently, the plant builds the Ford Edge and Lincoln Nautilus, but concerns over the plant's future emerged earlier this year when a report suggested Ford was contemplating scrapping the Edge altogether. The new vehicles will come as welcome news for the plant, even as Fiorani says he worries that demand for the electric vehicles (EV) has so far not lived up to the hype.

"The EV market is coming, and Ford looks to be preparing for it. However, the demand is just not growing in line with the proposed investment from all vehicle manufacturers," he said.

Plant needs upgrade first
And the plant can't simply flip a switch and start building an entirely new type of vehicle. It will require a major retooling, and that will require time — and cash — to happen, which is where government cash comes in, as seen with a Niagara Region battery plant supporting the EV supply chain.

As first reported by the Toronto Star, the two branches of government have committed to spent up to $500 million combined to upgrade the plant so that it can build electric vehicles.

"The retooling will begin in 2024 with vehicles rolling off the line in 2025," Unifor president Jerry Dias said. "So we know this is a decades-long commitment."

It's not clear what portion of the cash will come from what branch of government, but CBC News has previously reported that Wednesday's throne speech is expected to contain a number of policies aimed at beefing up Canada's electric vehicle industry, as EV assembly deals are putting Canada in the race, both on the consumer side and for businesses that build them.

Ontario's minister of economic development and trade welcomed the news of a tentative deal on Tuesday and confirmed that Queen's Park legislators stand ready to do their part, as shown by Honda's Ontario battery investment moves in the province.

"Our government will always work with our federal colleagues, workers and the auto sector to ensure the right conditions are in place for the industry to remain stable today and seize the new opportunities of tomorrow," a spokesperson for Vic Fedeli told CBC News in an emailed statement Tuesday.

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FERC Capacity Markets face scrutiny as GAO flags inconsistent data on resource adequacy and costs, urging performance goals, risk assessment, and better metrics across PJM, ISO-NE, NYISO, and MISO amid cost-recovery proposals.

Key Points

FERC capacity markets aim for resource adequacy, but GAO finds weak data and urges goals and performance reviews.

✅ GAO cites inconsistent data on resource adequacy and costs

✅ Calls for performance goals, metrics, and risk assessment

✅ Applies to PJM, ISO-NE, NYISO; MISO market is voluntary

Capacity markets may or may not be functioning properly, but FERC can't adequately make that determination, according to the GAO report.

"Available information on the level of resource adequacy ... and related costs in regions with and without capacity markets is not comprehensive or consistent," the report found. "Moreover, consistent data on historical trends in resource adequacy and related costs are not available for regions without capacity markets."

The review concluded that FERC collects some useful information in regions with and without capacity markets, but GAO said it "identified problems with data quality, such as inconsistent data."

GAO included three recommendations, including calling for FERC to take steps to improve the quality of data collected, and regularly assess the overall performance of capacity markets by developing goals for those assessments.

"FERC should develop and document an approach to regularly identify, assess, and respond to risks that capacity markets face," the report also recommended. The commission "has not established performance goals for capacity markets, measured progress against those goals, or used performance information to make changes to capacity markets as needed."

The recommendation comes as the agency is grappling with a controversial proposal to assure cost-recovery for struggling coal and nuclear plants in the power markets. So far, the proposal would only apply to power markets with capacity markets, including PJM Interconnection, the New England ISO, the New York ISO and possibly MISO. However MISO only has a voluntary capacity market, making it unclear how the proposed rule would be applied there. 

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