Coal plant closer to 2025 shutdown target

Florida Electricity Deregulation Ruling highlights the Florida Supreme Court decision blocking a ballot measure on retail choice, preserving utility monopolies for NextEra and Duke Energy, while similar deregulation efforts arise in Virginia and Arizona.

Key Points

A high court decision removing a retail choice ballot measure, keeping Florida utility monopolies intact for incumbents.

✅ Petition language deemed misleading for 2020 ballot

✅ Preserves NextEra and Duke Energy market dominance

✅ Similar retail choice pushes in VA and AZ

Florida’s top court ruled against a proposed constitutional amendment that would have allowed customers to pick their electricity provider, even as Florida solar incentives face rejection by state leaders, threatening monopolies held by utilities such as NextEra Energy Inc. and Duke Energy Corp.

In a ruling Thursday, the court said the petition’s language is “misleading” and doesn’t comply with requirements to be included on the 2020 ballot, reflecting debates over electricity pricing changes at the federal level. The measure’s sponsor, Citizens for Energy Choice, said the move ends the initiative, even as electricity future advocacy continues nationwide.

“While we were confident in our plan to gather the remaining signatures required, we cannot overcome this last obstacle,” the group’s chair, Alex Patton, noting ongoing energy freedom in the South efforts, said in a statement.

The proposed measure was one of several efforts underway to deregulate U.S. electricity markets, including New York’s review of retail energy markets this year. Earlier this week, two Virginia state lawmakers unveiled a bill to allow residents and businesses to pick their electricity provider, threatening Dominion Energy Inc.’s longstanding local monopoly. And in Arizona, where Arizona Public Service Co. has long reigned, regulators are considering a similar move, while in New England Hydro-Quebec’s export bid has been energized by a court decision.

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Ontario Pickering Nuclear Closure will shift supply to natural gas, raising emissions as the electricity grid manages nuclear refurbishment, IESO planning, clean power imports, and new wind, solar, and storage to support electrification.

Key Points

Ontario will close Pickering and rely on natural gas, increasing emissions while other nuclear units are refurbished.

✅ 14% of Ontario electricity supplied by Pickering now

✅ Natural gas use rises; grid emissions projected up 375%

✅ IESO warns gas phaseout by 2030 risks blackouts, costs

The Ontario government will not reconsider plans to close the Pickering nuclear station and instead stop-gap the consequent electricity shortfall with natural gas-generated power in a move that will, as an analysis of Ontario's grid shows, hike the province’s greenhouse gas emissions substantially in the coming years.

In a report released this week, a nuclear advocacy group urged Ontario to refurbish the aging facility east of Toronto, which is set to be shuttered in phases in 2024 and 2025, prompting debate over a clean energy plan after Pickering as the closure nears. The closure of Pickering, which provides 14 per cent of the province’s annual electricity supply, comes at the same time as Ontario’s other two nuclear stations are undergoing refurbishment and operating at reduced capacity.

Canadians for Nuclear Energy, which is largely funded by power workers' unions, argued closing the 50-year-old facility will result in job losses, emissions increases, heightened reliance on imported natural gas and an electricity supply gap across Ontario.

But Palmer Lockridge, spokesperson for the provincial energy minister, said further extending Pickering’s lifespan isn’t on the table.

“As previously announced in 2020, our government is supporting Ontario Power Generation’s plan to safely extend the life of the Pickering Nuclear Generating Station through the end of 2025,” said Lockridge in an emailed response to questions.

“Going forward, we are ensuring a reliable, affordable and clean electricity system for decades to come. That’s why we put a plan in place that ensures we are prepared for the emerging energy needs following the closure of Pickering, and as a result of our government’s success in growing and electrifying the province’s economy.”

The Progressive Conservative government under Premier Doug Ford has invested heavily in electrification, sinking billions into electric vehicle and battery manufacturing and industries like steel-making to retool plants to run on electricity rather than coal, and exploring new large-scale nuclear plants to bolster baseload supply.

Natural gas now provides about seven per cent of the province’s energy, a piece of the pie that will rise significantly as nuclear energy dwindles. Emissions from Ontario’s electricity grid, which is currently one of the world’s cleanest with 94 per cent zero-emission power generation, are projected to rise a whopping 375 per cent as the province turns increasingly to natural gas generation. Those increases will effectively undo a third of the hard-won emissions reductions the province achieved by phasing out coal-fired power generation.

The Independent Electricity System Operator (IESO), which manages Ontario’s grid, studied whether the province could phase out natural gas generation by 2030 and concluded that “would result in blackouts and hinder electrification” and increase average residential electricity costs by $100 per month.

The Ontario Clean Air Alliance, however, obtained draft documents from the electricity operator that showed it had studied, but not released publicly, other scenarios that involved phasing out natural gas without energy shortfalls, price hikes or increases in emissions.

The Ontario government will not reconsider plans to close the Pickering nuclear station and instead stop-gap the consequent electricity shortfall facing Ontario with natural gas-generated power in a move that will hike the province’s greenhouse gas emissions.

One model suggested increasing carbon taxes and imports of clean energy from other provinces could keep blackouts, costs and emissions at bay, while another involved increasing energy efficiency, wind generation and storage.

“By banning gas-fired electricity exports to the U.S., importing all the Quebec water power we can with the existing transmission lines and investing in energy efficiency and wind and solar and storage — do all those things and you can phase out gas-fired power and lower our bills,” said Jack Gibbons, chair of the Ontario Clean Air Alliance.

The IESO has argued in response that the study of those scenarios was not complete and did not include many of the challenges associated with phasing out natural gas plants.

Ontario Energy Minister Todd Smith asked the IESO to develop “an achievable pathway to zero-emissions in the electricity sector and evaluate a moratorium on new-build natural gas generation stations,” said his spokesperson. That report, an early look at halting gas power, is expected in November.

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SCE Wildfire Lawsuits allege utility equipment and power lines sparked deadly Los Angeles blazes; investigations, inverse condemnation, and stricter utility regulations focus on liability, vegetation management, and wildfire safety amid Santa Ana winds.

Key Points

Residents sue SCE, alleging power lines ignited LA wildfires; seeking compensation under inverse condemnation.

✅ Videos cited show sparking lines near alleged ignition points.

✅ SCE denies wrongdoing; probes and inspections ongoing.

✅ Inverse condemnation may apply regardless of negligence.

In the aftermath of devastating wildfires in Los Angeles, residents have initiated legal action, similar to other mega-fire lawsuits underway in California, against Southern California Edison (SCE), alleging that the utility's equipment was responsible for sparking one of the most destructive fires. The fires have resulted in significant loss of life and property, prompting investigations into the causes and accountability of the involved parties.

The Fires and Their Impact

In early January 2025, Los Angeles experienced severe wildfires that ravaged neighborhoods, leading to the loss of at least 29 lives and the destruction of approximately 155 square kilometers of land. Areas such as Pacific Palisades and Altadena were among the hardest hit. The fires were exacerbated by arid conditions and strong Santa Ana winds, which contributed to their rapid spread and intensity.

Allegations Against Southern California Edison

Residents have filed lawsuits against SCE, asserting that the utility's equipment, particularly power lines, ignited the fires. Some plaintiffs have presented videos they claim show sparking power lines in the vicinity of the fire's origin. These legal actions seek to hold SCE accountable for the damages incurred, including property loss, personal injury, and emotional distress.

SCE's Response and Legal Context

Southern California Edison has denied any wrongdoing, stating that it has not detected any anomalies in its equipment that could have led to the fires. The utility has pledged to cooperate fully with investigations to determine the causes of the fires. California's legal framework, particularly the doctrine of "inverse condemnation," allows property owners to seek compensation from utilities for damages caused by public services, even without proof of negligence. This legal principle has been central in previous cases involving utility companies and wildfire damages, and similar allegations have arisen in other jurisdictions, such as an alleged faulty transformer case, highlighting shared risks.

Historical Context and Precedents

This situation is not unprecedented. In 2018, Pacific Gas and Electric (PG&E) faced similar allegations when its equipment was implicated in the Camp Fire, the deadliest wildfire in California's history. PG&E's equipment was found to have ignited the fire, and the company later pleaded guilty in the Camp Fire, leading to extensive litigation and financial repercussions for the company, while its bankruptcy plan won support from wildfire victims during restructuring. The case highlighted the significant risks utilities face regarding wildfire safety and the importance of maintaining infrastructure to prevent such disasters.

Implications for California's Utility Regulations

The current lawsuits against SCE underscore the ongoing challenges California faces in balancing utility operations with wildfire prevention, as regulators face calls for action amid rising electricity bills. The state has implemented stricter regulations and oversight, and lawmakers have moved to crack down on utility spending to mitigate wildfire risks associated with utility infrastructure. Utilities are now required to invest in enhanced safety measures, including equipment inspections, vegetation management, and the implementation of advanced technologies to detect and prevent potential fire hazards. These regulatory changes aim to reduce the incidence of utility-related wildfires and protect communities from future disasters.

The legal actions against Southern California Edison reflect the complex interplay between utility operations, public safety, and environmental stewardship. As investigations continue, the outcomes of these lawsuits may influence future policies and practices concerning utility infrastructure and wildfire prevention in California. The state remains committed to enhancing safety measures to protect its residents and natural resources from the devastating effects of wildfires.

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NGCP-SGCC Partnership drives transmission grid modernization in the Philippines, boosting high-voltage capacity, reliability, and resilience, while developing engineering talent via the Trailblazers Program to meet Southeast Asia best practices and utility standards.

Key Points

A partnership to modernize the Philippines' grid, boost high-voltage capacity, and upskill NGCP engineers.

✅ Modernizes transmission assets and grid reliability nationwide

✅ Trailblazers Program develops NGCP's engineering leadership

✅ SGCC knowledge transfer on UHV, high-voltage, and best practices

The National Grid Corp. of the Philippines (NGCP) is building on its partnership with State Grid Corp of China (SGCC) to expand and modernize transmission facilities, as well as enhance the capabilities of its personnel to advance the country's grid network, aligning with smart grid transformation in Egypt seen in other markets. NGCP Internal Affairs Department head Edwin Natividad said the grid operator is implementing various development programs with SGCC to make the country's power grid among the best power utilities in Asia.

"We have to look at policies aligned with best global practices, including smart grid solutions increasingly adopted worldwide, that we can choose in adopting in the Philippines too," he said. One of NGCP's flagship development program is the Trailblazers Program, the company's strategy to further develop engineers "who will not just be technical experts, but also be the change agents and movers in the NGCP organization as well as in the Philippines' power sector," Natividad said.

"Having the support of the largest utility in the world gives us comfort that this program is designed and implemented by the best in the power industry," he said. Under the program, high performing personnel participating will be prepared for bigger roles later on in their careers at NGCP.

Business ( Article MRec ), pagematch: 1, sectionmatch: 1 "The advantage of such a pool is that it provides flexibility and, eventually, organizational self-sufficiency around the current and future talent needs of NGCP," Natividad said. Now on its third edition, the Trailblazers Program has already sent 76 personnel since it started in November 2016. Natividad said more than 16 of those who previously attended similar programs have already assumed higher roles in NGCP.

Apart from technical skills development, NGCP's partnership with SGCC also provides technical development to improve on the physical transmission assets. "If you will compare the facilities being handled by SGCC with other countries, in terms of handling high voltage capability, SGCC is way ahead.

The higher the voltage it's going to be more difficult to handle," Natividad said, adding they can handle more power to distribute to power distributors. As an example, SGCC's transmission facilities can handle high voltage to as much as 1,000 kiloVolts (kV), whereas the Philippines only has one high voltage facility, the interconnection between Luzon and Visayas, which can handle 500 kV, echoing proposals for macrogrids in Canada to improve reliability.

Natividad said NGCP was the first and biggest investment of SGCC outside of China before it made investments in other parts of the world, even as cybersecurity concerns in Britain have influenced supplier choices. A consortium among businessmen Henry Sy Jr., Robert Coyuito Jr., and SGCC as technical partner, NGCP holds a 25-year concession contract to operate and maintain the country's transmission grid.

Earlier, Sy, NGCP president and CEO, said the company is targeting to become the best utility firm in Southeast Asia. Since it took over the operations and maintenance of the country's power transmission network in 2009, the grid operator has introduced major physical and technological upgrades to ageing state-owned lines and facilities, while in Great Britain an independent operator model is being advanced to reshape system operations.

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Ontario Hydro Flat Rate sets a single electricity rate at 12.8 cents per kWh, replacing time-of-use pricing for Ontario ratepayers, affecting hydro bills this summer, alongside COVID-19 Energy Assistance Program support.

Key Points

A fixed 12.8 cents per kWh electricity price replacing time-of-use rates across Ontario from June to November.

✅ Single rate applies 24/7, replacing time-of-use pricing

✅ May slightly raise bills versus pre-pandemic usage patterns

✅ COVID-19 aid offers one-time credits for households, small firms

A new provincial COVID-19 measure, including a fixed COVID-19 hydro rate designed to give Ontario ratepayers "stability" on their hydro bills this summer, could result in slightly higher hydro costs over the next four months.

Ontario Premier Doug Ford's government announced over the weekend that consumers would be charged a single around-the-clock electricity rate between June and November, before a Nov. 1 rate increase takes effect, replacing the much-derided time-of-use model ratepayers have complained about for years.

Instead of being charged between 10 to 20 cents per kilowatt hour, depending on the time of day electricity is used, including ultra-low TOU rates during off-peak hours, hydro users will be charged a blanket rate of 12.8 cents per kWh.

"The new rate will simply show up on your bill," Premier Doug Ford said at a Monday afternoon news conference.

While the government said the new fixed rate would give customers "greater flexibility" to use their home appliances without having to wait for the cheapest rate -- and has tabled legislation to lower rates as part of its broader plan -- the new policy also effectively erases a pandemic-related hydro discount for millions of consumers.

For example, a pre-pandemic bill of $59.90 with time-of-use rates, will now cost $60.28 with the government's new recovery rate, as fixed pricing ends across the province, before delivery charges, rebates and taxes.

That same bill would have been much cheaper -- $47.57 -- if the government continued applying the lowest tier of time-of-use 24/7 under an off-peak price freeze as it had been doing since March 24.

The government also introduced support for electric bills with two new assistance programs to help customers struggling to pay their bills.

The COVID-19 Energy Assistance Program will provide a one-time payment consumers to help pay off electricity debt incurred during the pandemic -- which will cost the government $9 million.

The government will spend another $8 million to provide similar assistance to small businesses hit hard by the pandemic.

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Iran-Iraq Electricity Cooperation advances with power grid synchronization, cross-border energy trade, 400-kV transmission lines, and education partnerships, boosting grid reliability, infrastructure investment, and electricity exports between Tehran and Baghdad for improved supply and stability.

Key Points

A bilateral initiative to synchronize grids, expand networks, and sustain electricity exports, improving reliability.

✅ 400-kV Amarah-Karkheh line enables synchronized operations.

✅ Extends electricity export contracts to meet Iraq demand.

✅ Enhances grid reliability, training, and infrastructure investment.

Aradakanian has focused his one-day visit to Iraq on discussions pertaining to promoting bilateral collaboration between the two neighboring nations in the field of electricity, grid development deals and synchronizing power grid between Tehran and Baghdad, cooperating in education, and expansion of power networks.

He is also scheduled to meet with Iraqi top officials in a bid to boost cooperation in the relevant fields.

Back in December 2019, Ardakanian announced that Iran will continue exports of electricity to Iraq by renewing earlier contract as it is supplying about 40% of Iraq's power today.

"Iran has signed a 3-year-long cooperation agreement with Iraq to help the country's power industry in different aspects. The documents states at its end that we will export electricity to Iraq as far as they need," Ardakanian told FNA on December 9, 2019.

The contract to "export Iran's electricity" to Iraq will be extended, he added.

Ardakanian also said that Iran and Iraq's power grids have become synchronized in a move that supports Iran's regional power hub plans since a month ago.

In 2004 Iran started selling electricity to Iraq. Iran electricity exports to the western neighbor are at its highest level of 1,361 megawatts per day now, as the country weighs summer power sufficiency ahead of peak demand.

The new Amarah-Karkheh 400-KV transmission line stretching over 73 kilometers, is now synchronized to provide electricity to both countries, reflecting regional power export trends as well. It also paves the way for increasing export to power-hungry Iraq in the near future.

With synchronization of the two grids, the quality of electricity in Iraq will improve as the country explores nuclear power options to tackle shortages.

According to official data, 82% of Iraq's electricity is generated by thermal power plants that use gas as feedstock, while Iran is converting thermal plants to combined cycle to save energy. This is expected to reach 84% by 2027.

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