CEA gives thumbs up to regulatory reform

By Canadian Electricity Association


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The Canadian Electricity Association CEA is pleased with the federal government’s proposal to modernize the regulatory review process for major economic projects, as announced recently in the government’s seventh annual budget entitled, Economic Action Plan 2012 – A Plan for Jobs, Growth and Long-Term Prosperity.

“The federal government’s proposal for legislation that improves regulatory efficiency is a big step in the right direction,” said Jim Burpee, President and CEO of CEA. “The renewal of our electricity infrastructure is vital to maintaining our prosperity and quality of life. The Canadian Electricity Association is working with the federal government to ensure that Canadians continue to receive reliable, sustainable and cost-effective electricity in the years ahead.”

The Economic Action Plan proposes new legislation that will modernize the federal review process for major economic projects. Focus will be on four major areas: establishing clear timelines, reducing duplication and regulatory burdens, strengthening environmental protection, and enhancing consultation with Aboriginal peoples.

A recent Conference Board of Canada report titled “Shedding Light on the Economic Impact of Investing in Electricity Infrastructure” projects that the renewal of Canada’s electricity infrastructure between now and 2030 will contribute an average addition of $10.9 billion per year to real GDP, create hundreds of thousands of jobs, and provide a boost to government finances. In current dollar terms, collective federal and provincial government balances are projected to increase by roughly $6 billion per year from 2011 to 2015.

Canada is a global leader in clean energy production, with over 80 percent of its electricity generated from non-emitting sources. Hydropower and nuclear, along with renewable energy such as wind and solar, emit few if any greenhouse gasses (GHG). However, much of CanadaÂ’s electricity system was built 30 to 60 years ago, and now needs to be renewed in order to accommodate load growth. Regulatory reform on the federal level is absolutely crucial to ensuring projects are completed in a timely and cost effective manner.

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No deal Brexit could trigger electricity shock for Northern Ireland

Northern Ireland No-Deal Power Contingency outlines Whitehall plans to deploy thousands of generators on barges in the Irish Sea, safeguard the electricity market, and avert blackouts if Brexit disrupts imports from the Republic of Ireland.

 

Key Points

A UK Whitehall plan to prevent NI blackouts by deploying generators and protecting cross-border electricity flows.

✅ Barges in Irish Sea to host temporary power generators

✅ Mitigates loss of EU market access in a no-deal Brexit

✅ Ensures NI supply if Republic cuts electricity exports

 

Such a scenario could see thousands of electricity generators being requisitioned at short notice and positioned on barges in the Irish Sea, even as Great Britain's generation mix shapes wider supply dynamics, to help keep the region going, a Whitehall document quoted by the Financial Times states.

An emergency operation could see equipment being brought back from places like Afghanistan, where the UK still has a military presence, the newspaper said.

The extreme situation could arise because Northern Ireland shares a single energy market with the Irish Republic, where Irish grid price spikes have heightened concern about stability.

The region relies on energy imports from the Republic because it does not have enough generating capacity itself, and the UK is aiming to negotiate a deal to allow that single electricity market on the island of Ireland to continue post-EU withdrawal, while virtual power plant proposals for UK homes are explored to avoid outages, the FT stated.

However, if no Brexit deal is agreed Whitehall fears suppliers in the Irish Republic could cut off power because the UK would no longer be part of the European electricity market, and a recent short supply warning from National Grid underscores the risk.

In a bid to prevent blackouts in Northern Ireland in a worse case situation the Government would need to put thousands of generators into place, even as an emergency energy plan has reportedly not gone ahead nationwide, according to the report.

And officials fear they may need to commandeer some generators from the military in such a scenario, the FT reports.

An official was quoted by the newspaper as saying the preparations were “gob-smacking”.

 

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China's Path to Carbon Neutrality

China Unified Power Market enables carbon neutrality through renewable integration, cross-provincial electricity trading, smart grid upgrades, energy storage, and market reform, reducing coal dependence and improving grid flexibility, efficiency, and emissions mitigation.

 

Key Points

A national power market integrating renewables and grids to cut coal use and accelerate carbon neutrality.

✅ Harmonizes pricing and cross-provincial electricity trading.

✅ Boosts renewable integration with storage and smart grids.

✅ Improves dispatch efficiency, reliability, and emissions cuts.

 

China's ambitious goal to achieve carbon neutrality has become a focal point in global climate discussions around the global energy transition worldwide, with experts emphasizing the pivotal role of a unified power market in realizing this objective. This article explores China's commitment to carbon neutrality, the challenges it faces, and how a unified power market could facilitate the transition to a low-carbon economy.

China's Commitment to Carbon Neutrality

China, as the world's largest emitter of greenhouse gases, has committed to achieving carbon neutrality by 2060. This ambitious goal signals a significant shift towards reducing carbon emissions and mitigating climate change impacts. Achieving carbon neutrality requires transitioning away from fossil fuels, including investing in carbon-free electricity pathways and enhancing energy efficiency across sectors such as industry, transportation, and residential energy consumption.

Challenges in China's Energy Landscape

China's energy landscape is characterized by its heavy reliance on coal, which accounts for a substantial portion of electricity generation and contributes significantly to carbon emissions. Transitioning to renewable energy sources such as wind, solar, hydroelectric, and nuclear power is essential to reducing carbon emissions and achieving carbon neutrality. However, integrating these renewable sources into the existing energy grid poses technical, regulatory, and financial challenges that often hinge on adequate clean electricity investment levels and policy coordination.

Role of a Unified Power Market

A unified power market in China could play a crucial role in facilitating the transition to a low-carbon economy. By integrating regional power grids and promoting cross-provincial electricity trading, a unified market can optimize the use of renewable energy resources, incorporate lessons from decarbonizing electricity grids initiatives to enhance grid stability, and reduce reliance on coal-fired power plants. This market mechanism encourages competition among energy producers, incentivizes investment in renewable energy projects, and improves overall efficiency in electricity generation and distribution.

Benefits of a Unified Power Market

Implementing a unified power market in China offers several benefits in advancing its carbon neutrality goals. It promotes renewable energy development by providing a larger market for electricity generated from wind, solar, and other clean sources that underpin the race to net-zero in many economies. It also enhances grid flexibility, enabling better management of fluctuations in renewable energy supply and demand. Moreover, a unified market encourages innovation in energy storage technologies and smart grid infrastructure, essential components for integrating variable renewable energy sources.

Policy and Regulatory Considerations

Achieving a unified power market in China requires coordinated policy efforts and regulatory reforms. This includes harmonizing electricity pricing mechanisms, streamlining administrative procedures for electricity trading across provinces, and ensuring fair competition among energy producers. Clear and consistent policies that support renewable energy deployment and grid modernization, and align with insights on climate policy and grid implications from other jurisdictions, are essential to attracting investment and fostering a sustainable energy transition.

International Collaboration and Leadership

China's commitment to carbon neutrality presents opportunities for international collaboration and leadership in climate action. Engaging with global partners, sharing best practices, and promoting technology transfer, as seen with Canada's 2050 net-zero target commitments, can accelerate progress towards a low-carbon future. By demonstrating leadership in clean energy innovation and climate resilience, China can contribute to global efforts to mitigate climate change and achieve sustainable development goals.

Conclusion

China's pursuit of carbon neutrality by 2060 represents a monumental endeavor that requires transformative changes in its energy sector. A unified power market holds promise as a critical enabler in this transition, facilitating the integration of renewable energy sources, enhancing grid flexibility, and optimizing energy efficiency. By prioritizing policy coherence, regulatory reform, and international cooperation, China can pave the way towards a sustainable energy future while addressing global climate challenges.

 

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SC nuclear plant on the mend after a leak shut down production for weeks

V.C. Summer nuclear plant leak update: Dominion Energy repaired a valve in the reactor cooling system; radioactive water stayed within containment, NRC oversight continues as power output ramps toward full operation.

 

Key Points

A minor valve leak in the reactor cooling system contained onsite; Dominion repaired it as the plant resumes power.

✅ Valve leak in piping to steam generators, not environmental release.

✅ Radioactive water remained in containment, monitored per NRC rules.

✅ Plant ramping from 17% power; full operations may take days.

 

The V.C. Summer nuclear power plant, which has been shut down since early November because of a pipe leak, is expected to begin producing energy in a few days, a milestone comparable to a new U.S. reactor startup reported recently.

Dominion Energy says it has fixed the small leak in a pipe valve that allowed radioactive water to drip out. The company declined to say when the plant would be fully operational, but spokesman Ken Holt said that can take several days, amid broader discussions about the stakes of early nuclear closures across the industry.

The plant was at 17 percent power Wednesday, he said, as several global nuclear project milestones continue to be reported this year.

Holt, who said Dominion is still investigating the cause, said water that leaked was part of the reactor cooling system. While the water came in contact with nuclear fuel in the reactor, the water never escaped the plant's containment building and into the environment, Holt said.

He characterized the valve leak as '"uncommon" but not unexpected. The nuclear leak occurred in piping that links the nuclear reactor with the power plant's steam generators. Hundreds of pipes are in that part of the nuclear plant, a complexity often cited in the energy debate over struggling nuclear plants nationwide.

"There is always some level of leakage when you are operating, but it is contained and monitored, and when it rises to a certain level, you may take action to stop it," Holt said.

A nuclear safety watchdog has criticized Dominion for not issuing a public notice about the leak, but both the company and the U.S. Nuclear Regulatory Commission say the amount was so small it did not require notice.

The V.C. Summer Nuclear plant is about 25 miles northwest of Columbia in Fairfield County. It was licensed in the early 1980s. At one point, Dominion's predecessor, SCE&G, partnered with state owned Santee Cooper to build two more reactors there, even as new reactors in Georgia were taking shape. But the companies walked away from the project in 2017, citing high costs and troubles with its chief contractor, Westinghouse, even as closures such as Three Mile Island's shutdown continued to influence policy.

 

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TVA faces federal scrutiny over climate goals, electricity rates

TVA Rates and Renewable Energy Scrutiny spotlights electricity rates, distributed energy resources, solar and wind deployment, natural gas plans, grid access charges, energy efficiency cuts, and House oversight of lobbying, FERC inquiries, and least-cost planning.

 

Key Points

A congressional probe into TVA pricing and practices affecting renewables, energy efficiency, and climate goals.

✅ House panel probes TVA rates, DER and solar policies.

✅ Efficiency programs cut; least-cost planning questioned.

✅ Inquiry on lobbying, hidden fees; FERC scrutiny.

 

The Tennessee Valley Authority is facing federal scrutiny about its electricity rates and climate action, amid ongoing debates over network profits in other markets.

Members of the House Committee on Energy and Commerce are “requesting information” from TVA about its ratepayer bills and “out of concern” that TVA is interfering with the deployment of renewable and distributed energy resources, even as companies such as Tesla explore electricity retail to expand customer options.

“The Committee is concerned that TVA’s business practices are inconsistent with these statutory requirements to the disadvantage of TVA’s ratepayers and the environment,” the committee said in a letter to TVA CEO Jeffrey Lyash.

The four committee members — U.S. Reps. Frank Pallone, Jr. (D-NJ), Bobby L. Rush (D-IL), Diana DeGette (D-CO), and Paul Tonko (D-NY) — suggested that Tennessee Valley residents pay too much for electricity despite TVA’s relatively low rates, even as regulators have, in other cases, scrutinized mergers like the Hydro One-Avista deal to safeguard ratepayers, underscoring similar concerns. In 2020, Tennessee residents had electric bills higher than the national average, while low-income residents in Memphis have historically faced one of the highest energy burdens in the U.S.

In 2018, TVA reduced its wholesale rate while adding a grid access charge on local power companies—and interfered with the adoption of solar energy. Internal TVA documents obtained through a Freedom of Information Act request by the Energy and Policy Institute revealed that TVA permitted local power companies to impose new fees on distributed solar generation to “lessen the potential decrease in TVA load that may occur through the adoption of [behind the meter] generation.”

Additionally, the committee said TVA is not prioritizing energy conservation and efficiency or “least-cost planning” that includes renewables, as seen in oversight such as the OEB's Hydro One rates decision emphasizing cost allocation. TVA reduced its energy efficiency programs by nearly two-thirds between 2014 and 2018 and cut its energy efficiency customer incentive programs.

At this time, TVA has not aligned its long-term planning with the Biden administration’s goal to achieve a carbon-free electricity sector by 2035. TVA’s generation mix, which is roughly 60% carbon-free, comprises 39% nuclear, 19% coal, 26% natural gas, 11% hydro, 3% wind and solar, and 1% energy efficiency programs, according to TVA.

The committee is “greatly concerned that TVA has invested comparatively little to date in deploying solar and wind energy, while at the same time considering investments in new natural gas generation.”

TVA has announced plans to shutter the Kingston and Cumberland coal plants and is evaluating whether to replace this generation with natural gas, which is a fossil fuel, while debates over grid privatization raise questions about consumer benefits. TVA’s coal and natural gas plants represent most of the largest sources of greenhouses emissions in Tennessee.

TVA responded with a statement without directly addressing the committee’s concerns. TVA said its “developing and implementing emerging technologies to drive toward net-zero emissions by 2050.”

The final question that the House committee posed is whether TVA is funding any political activity. In 2019, the committee questioned TVA about its membership to the now-disbanded Utility Air Regulatory Group, a coalition that was involved in over 200 lawsuits that primarily fought Clear Air Act regulations.

TVA revealed that it had contributed $7.3 million to the industry lobbying group since 2001. Since TVA doesn’t have shareholders, customers paid for UARG membership fees, echoing findings that deferred utility costs burden customers in other jurisdictions. An Office of the Inspector General investigation couldn’t prove whether TVA’s contributions directly funded litigation because UARG didn’t have a line-by-line accounting of what they did with TVA’s dollars.

The congressional committee questioned whether TVA is still paying for lobbying or litigation that opposes “public health and welfare regulations.”

This last question follows a recent trend of questioning utilities about “hidden fees.” In December, the Federal Energy Regulatory Commission issued a Notice of Inquiry to examine how bills from investor-owned utilities might contain fees that fund political activity, and regulators have penalized firms like NT Power over customer notice practices, highlighting consumer protection. The Center for Biological Diversity filed a petition to protect electric and gas customers of investor-owned utilities from paying these fees, which may be used for lobbying, campaign-related donations and litigation.

 

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Electric vehicle sales triple in Australia despite lack of government support

Australian Electric Vehicle Sales tripled in 2019 amid expanding charging infrastructure and more models, but market share remains low, constrained by limited government policy, weak incentives, and absent emissions standards despite growing ultra-fast chargers.

 

Key Points

EV units sold in Australia; in 2019 they tripled to 6,718, but market share was just 0.6%.

✅ Sales rose from 2,216 (2018) to 6,718 (2019); ~80% were BEVs.

✅ Public charging sites reached 2,307; fast chargers up 40% year-on-year.

✅ Policy gaps and absent standards limit model supply and EV uptake.

 

Sales of electric vehicles in Australia tripled in 2019 despite a lack of government support, according to the industry’s peak body.

The country’s network of EV charging stations was also growing, the Electric Vehicle Council’s annual report found, including a rise in the number of faster charging stations that let drivers recharge a car in about 15 minutes.

But the report, released on Wednesday, found the market share for electric vehicles was still only 0.6% of new vehicle sales – well behind the 2.5% to 5% in other developed countries.

The chief executive of the council, Behyad Jafari, said the rise in sales was down to more models becoming available. There are now 28 electric models on sale, with eight priced below $65,000.

Six more were due to arrive before the end of 2021, including two priced below $50,000, the council’s report said.

“We have repeatedly heard from car companies that they were planning to bring vehicles here, but Australia doesn’t have that policy support.”

The Morrison government promised a national electric vehicle strategy would be finalised by the middle of this year, but the policy has been delayed. The prime minister, Scott Morrison, last year accused Labor of wanting to “end the weekend” and force people out of four-wheel drives after the opposition set a target of 50% of new car sales being electric by 2030.

Jafari cited the Kia e-Niro – an award-winning electric SUV that was being prepared for an Australian launch, but is now reportedly on hold because the manufacturer favoured shipping to countries with emissions standards.

The council’s members include BMW, Nissan, Hyundai and Harley Davidson, as well as energy, technology and charging infrastructure companies.

Sales of electric vehicles – which include plug-in hybrids – went from 2,216 in 2018 to 6,718 in 2019, the report said. Jafari said about 80% of those sales were all-electric vehicles.

There have been 3,226 electric vehicles sold in 2020, the report said, despite an overall drop of 20% in vehicle sales due to the Covid-19 pandemic, while U.S. EV sales have surged into 2024.

Jafari said: “Our report is showing that Australian consumers want these cars.

“There is no controversy that the future of the industry is electric, but at the moment the industry is looking at different markets. We want policies that show [Australia] is going on this journey.”

Government agency data has forecast that half the new cars sold will be electric by 2035, underscoring that the age of electric cars is arriving even if there is no policy to support their uptake.

Manufacturers currently selling electric cars in Australia are Nissan, Hyundai, Mitsubishi, Tesla, Volvo, Porsche, Audi, BMW, Mercedes, Jaguar and Renault, the report said.

Jafari said most G20 countries had emissions standards in place for vehicles sold and incentives in place to support electric vehicles, such as rebates or exemptions from charges. This hadn’t happened in Australia, he said.

The report said: “Globally, carmakers are rolling out more electric vehicle models as the electric car market expands, but so far production cannot keep up with demand. This means that without policy signals, Australians will continue to be denied access to the full global range of electric vehicles.”

On Tuesday, one Australian charging provider, Evie Networks, opened an ultra-fast station at a rest stop at Campbell Town in Tasmania – between Launceston and Hobart.

The company said the station would connect EV owners in the state’s north and south and the two 350kW chargers could recharge a vehicle in 15 minutes, highlighting whether grids have the power to charge EVs at scale. Two more sites were planned for Tasmania, the company said.

A Tasmanian government grant to support electric vehicle charging had helped finance the site. Evie was also supported with a $15m grant from the federal government’s Australian Renewable Energy Agency.

According to the council report, Australia now has 2,307 public charging stations, including 357 fast chargers – a rise of 40% in the past year.

A survey of 2,900 people in New South Wales, the ACT, Victoria and South Australia, carried out by NRMA, RACV and RAA on behalf of the council, found the main barriers to buying an electric vehicle were concerns over access to charging points, higher prices and uncertainty over driving range.

Consumers favoured electric vehicles because of their environmental footprint, lower maintenance costs and vehicle performance.

The report said the average battery range of electric vehicles available in Australia was 400km, but almost 80% of people thought the average was less.

According to the survey, 56% of Australians would consider an electric car when they next bought a vehicle, and in the UK, EV inquiries soared during a fuel supply crisis.

“We are far behind, but it is surmountable,” Jafari said.

The council report also rated state and territories on the policies that supported its industry and found the ACT was leading, followed by NSW and Queensland.

A review of commercial electric vehicle use found public electric bus trials were planned or under way in Queensland, NSW, WA, Victoria and ACT. There are now more than 400,000 electric buses in use around the globe.

 

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Manitoba Hydro's burgeoning debt surpasses $19 billion

Manitoba Hydro Debt Load surges past $19.2B as the Crown corporation faces shrinking net income, restructuring costs, and PUB rate decisions, driven by Bipole III, Keeyask construction, aging infrastructure, and rising interest rate risks.

 

Key Points

Manitoba Hydro Debt Load refers to the utility's escalating borrowings exceeding $19B, pressuring rates and finances.

✅ Debt rose to $19.2B; projected near $25B within five years.

✅ Major drivers: Bipole III, Keeyask, aging assets, restructuring.

✅ Rate hikes sought; PUB approved 3.6% vs 7.9% request.

 

Manitoba Hydro's debt load now exceeds $19 billion as the provincial Crown corporation grapples with a shrinking net income amid ongoing efforts to slay costs.

The utility's annual report, to be released publicly on Tuesday, also shows its total consolidated net income slumped from $71 million in 2016-2017 to $37 million in the last fiscal year, mirroring a Hydro One profit drop as electricity revenue fell.

It said efforts to restructure the utility and reduce costs are partly to blame for the $34 million drop in year-over-year income.

These earnings come nowhere close, however, to alleviating Hydro's long-term debt problem, a dynamic also seen in a BC Hydro deferred costs report about customer exposure. The figure is pegged at $19.2 billion this fiscal year, up from $16.1 billion the previous year and $14.2 billion in 2016.

The utility projects its debt will grow to about $25 billion in the next five years. Its largest expenses include finishing the Bipole III line, working on the Keeyask Generating System that is halfway done and rebuilding aging wood poles and substations, the report said.

"This level of debt increases the potential financial exposure from risks facing the corporation and is a concern for both

the corporation and our customers who may be exposed to higher rate increases in the event of rising interest rates, a prolonged drought or a major system failure," outgoing president and CEO Kelvin Shepherd wrote.

The income drop is primarily a result of the $50 million spent in the form of restructuring charges associated with the utility's efforts to streamline the organization and drive down costs, amid NDP criticism of Hydro changes related to government policy.

Those efforts included the implementation of buyouts for employees through what the utility dubbed its "voluntary departure program."

Among the changes, Manitoba Hydro reduced its workforce by 800 employees, which is expected to save the utility over $90 million per year. It also reduced its management positions by 26 per cent, a Monday news release said, while Hydro One leadership upheaval in Ontario drove its shares down during comparable governance turmoil.

To improve its financial situation, Hydro has applied for rate increases, even as the Consumers Coalition pushes to have the proposal rejected. The Public Utilities Board offered a 3.6 per cent average rate hike, instead of the 7.9 per cent jump the utility asked for.

In May, when the PUB rendered its decision, it made several recommendations as an alternative to raising rates, including receiving a share of carbon tax revenue and asking the government to help pay for Bipole III.

Hydro is projecting a net income of $70 million for 2018-2019, which includes the impact of the recent rate increase. That total reflects an approximately 20 per cent reduction in net income from 2017-18 after restructuring costs are calculated.

 

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