Mississippi Power gets initial nod for coal plant

Ontario Off-Peak Electricity Rate offers 8.2 cents per kWh for 24 hours, supporting Time-of-Use and Tiered Regulated Price Plan customers, including residential, small business, and farms, under Ontario Energy Board guidelines during temporary relief.

Key Points

A temporary 8.2 cents per kWh all-day price for RPP customers, covering TOU and Tiered users across Ontario.

✅ Applies 24 hours daily at 8.2 cents per kWh for 21 days

✅ Covers residential, small business, and farm RPP customers

✅ Valid for TOU and Tiered plans set by the Ontario Energy Board

 The Ontario government has announced electricity relief with electricity prices set at the off-peak price of 8.2 cents per kilowatt-hour, 24 hours per day for 21 days starting January 18, 2022, until the end of day February 7, 2022, for all Regulated Price Plan customers. The off-peak rate will apply automatically to residential, small businesses and farms who pay Time-of-Use or Tiered prices set by the Ontario Energy Board.

This rate relief includes extended off-peak rates to support small businesses, as well as workers and families spending more time at home while the province is in Modified Step Two of the Roadmap to Reopen.

As part of our mandate, we set the rates that your utility charges for the electricity you use in your home or small business. These rates appear on the Electricity line of your bill, and we administer protections such as disconnection moratoriums for residential customers. We also set the Delivery rates that cover the cost to deliver electricity to most residential and small business customers.

Types of electricity rates

For residential and small business customers that buy electricity from their utility, there are two different types of rates (also called prices here), and Ontario also provides stable electricity pricing for larger users. The Ontario Energy Board sets both once a year on November 1:

Time-of-Use (TOU)

With TOU prices, the price depends on when you use electricity, including options like ultra-low overnight pricing that encourage off-peak use.

There are three TOU price periods:

• Off-peak, when demand for electricity is lowest and new offerings like the Ultra-Low Overnight plan can encourage shifting usage. Ontario households use most of their electricity – nearly two thirds of it – during off-peak hours.
• Mid-peak, when demand for electricity is moderate. These periods are during the daytime, but not the busiest times of day, and utilities like BC Hydro are exploring similar TOU structures as well.
• On-peak, when demand for electricity is generally higher. These are the busier times of day – generally when people are cooking, starting up their computers and running heaters or air conditioners.

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BC Hydro LNG Load Forecast signals rising electricity demand from LNG Canada, Woodfibre, and Tilbury, aligning Site C dam capacity with BCUC review, hydroelectric supply, and a potential fourth project in feasibility study British Columbia.

Key Points

BC Hydro's projection of LNG-driven power demand, guiding Site C capacity, BCUC review, and grid planning.

✅ Includes LNG Canada, Woodfibre, and Tilbury load requests

✅ Aligns Site C hydroelectric output with industrial electrification

✅ Notes feasibility study for a fourth LNG project

Despite recent project cancellations, such as the Siwash Creek independent power project now in limbo, BC Hydro still expects three LNG projects — and possibly a fourth, which is undergoing a feasibility study — will need power from its controversial and expensive Site C hydroelectric dam.

In a letter sent to the British Columbia Utilities Commission (BCUC) on Oct. 3, BC Hydro’s chief regulatory officer Fred James said the provincially owned utility’s load forecast includes power demand for three proposed liquefied natural gas projects because they continue to ask the company for power.

The letter and attached report provide some detail on which of the LNG projects proposed in B.C. are more likely to be built, given recent project cancellations.

The documents are also an attempt to explain why BC Hydro continues to forecast a surge in electricity demand in the province, as seen in its first call for power in 15 years driven by electrification, even though massive LNG projects proposed by Malaysia’s state owned oil company Petronas and China’s CNOOC Nexen have been cancelled.

An explanation is needed because B.C.’s new NDP government had promised the BCUC would review the need for the $9-billion Site C dam, which was commissioned to provide power for the province’s nascent LNG industry, amid debates over alternatives like going nuclear among residents. The commission had specifically asked for an explanation of BC Hydro’s electric load forecast as it relates to LNG projects by Wednesday.

The three projects that continue to ask BC Hydro for electricity are Shell Canada Ltd.’s LNG Canada project, the Woodfibre LNG project and a future expansion of FortisBC’s Tilbury LNG storage facility.

None of those projects have officially been sanctioned but “service requests from industrial sector customers, including LNG, are generally included in our industrial load forecast,” the report noted, even as Manitoba Hydro warned about energy-intensive customers in a separate notice.

In a redacted section of the report, BC Hydro also raises the possibility of a fourth LNG project, which is exploring the need for power in B.C.

“BC Hydro is currently undertaking feasibility studies for another large LNG project, which is not currently included in its Current Load Forecast,” one section of the report notes, though the remainder of the section is redacted.

The Site C dam, which has become a source of controversy in B.C. and was an important election issue, is currently under construction and, following two new generating stations recently commissioned, is expected to be in service by 2024, a timeline which had been considered to provide LNG projects with power by the time they are operational.

BC Hydro’s letter to the BCUC refers to media and financial industry reports that indicate global LNG markets will require more supply by 2023.

“While there remains significant uncertainty, global LNG demand will continue to grow and there is opportunity for B.C. LNG,” the report notes.

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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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Ontario Electricity Demand Drop During COVID-19 reflects a 1,000-2,000 MW decline as IESO balances the grid, shifts peak demand later, throttles generators and baseload nuclear, and manages exports amid changing load curves.

Key Points

An about 10% reduction in Ontario's load, shifting peaks and requiring IESO grid balancing measures.

✅ Demand down 1,000-2,000 MW; roughly 10% below normal.

✅ Peak shifts later in morning as home use rises.

✅ IESO throttles generators; baseload nuclear stays online.

It’s as if the COVID-19 epidemic had tripped a circuit breaker, shutting off all power to a city the size of Ottawa.

Virus-induced restrictions that have shut down large swaths of normal commercial life across Canada has led to a noticeable drop in demand for power in Ontario and reflect a global demand dip according to reports, insiders said on Friday.

Terry Young, vice-president with the Independent Electricity System Operator, said planning was underway for further declines in usage and for whether Ontario will embrace more clean power in the long term, given the delicate balance that needs to be maintained between supply and demand.

“We’re now seeing demand that is running about 1,000 to 2,000 megawatts less than we would normally see,” Young said. “You’re essentially seeing a city the size of Ottawa drop off demand during the day.”

At the high end, a 2,000 megawatt reduction would be close to the equivalent peak demand of Ottawa and London, Ont., combined.

The decline, in the order of 10 per cent from the 17,000 to 18,000 megawatts of usage that might normally be expected and similar to the UK’s 10% drop reported during lockdowns, began last week, Young said. The downward trend became more noticeable as governments and health authorities ordered non-essential businesses to close and people to stay home. However, residential and hospital usage has climbed.

Experts say frequent hand-washing and staying away from others is the most effective way to curb the spread of the highly contagious coronavirus, which poses a special risk to older people and those with underlying health conditions. As a result, factories and other big users have reduced production or closed entirely.

Because electricity cannot be stored, generators need to throttle back their output as domestic demand shrinks and exports to places such as the United States, including New York City, which is also being hit hard by the coronavirus, fall.

“We’re watching this carefully,” Young said. “We’re able to manage this drop, but it’s something we obviously have to keep watching…and making sure we’re not over-generating electricity.”

Turning off generation, especially for nuclear plants, is an intensive process, as are restarts and would likely happen only if the downward demand trend intensifies significantly, amid concerns over Ontario’s electricity getting dirtier if baseload is displaced. However, one of North America’s largest generators, Bruce Power near Kincardine, Ont., said it had a large degree of flexibility to scale down or up.

“We have the ability to provide one-third of our output as a dynamic response, which is unique to our facility,” said James Scongack, an executive vice-president with Bruce Power. “We developed this coming out of the 2008 downturn and it’s been a critical system asset for the last decade.”

“We don’t see there being a scenario where our baseload will not be needed,” he said, even as some warn Ontario may be short of electricity in the coming years.

The province’s publicly owned Ontario Power Generation said it was also in conversations with the system operator, which provides direction to generators, and is often cited in the Ontario election discussion.

One clear shift in normal work-day usage with so many people staying at home has been the change in demand patterns. Typically, Young said, there’s a peak from about 7 a.m. to 8 a.m. as people wake and get ready to go to work or school. The peak is now occurring later in the morning, Young said.

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

Key Points

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

✅ 4% electricity rise effective 1 Feb 2018

✅ Increase attributed to rising wholesale energy costs

✅ Switching supplier may reduce bills and boost savings

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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ComEd Smart Grid Reliability drives outage reduction across Illinois, leveraging smart switches, grid modernization, and peak demand programs to keep customers powered, improve power quality, and enhance energy savings during extreme weather and severe storms.

Key Points

ComEd's smart grid performance, cutting outages and improving power quality to enhance reliability and customer savings.

✅ Smart switches reroute power to avoid customer interruptions

✅ Fewer outages during extreme weather across northern Illinois

✅ Peak Time Savings rewards for reduced peak demand usage

While the summer of 2019 set records for heat and brought severe storms, ComEd customers stayed cool thanks to record-setting reliability during the season. These smart grid investments over the last seven years helped to set records in key reliability measurements, including frequency of outages metrics, and through smart switches that reroute power around potential problem areas, avoided more than 538,000 customer interruptions from June to August.

"In a summer where we were challenged by extreme weather, we saw our smart grid investments and our people continue to deliver the highest levels of reliability, backed by extensive disaster planning across utilities, for the families and businesses we serve," said Joe Dominguez, CEO of ComEd. "We're proud to deliver the most affordable, cleanest and, as we demonstrated this summer, most reliable energy to our customers. I want to thank our 6,000 employees who work around the clock in often challenging conditions to power our communities."

ComEd has avoided more than 13 million customer interruptions since 2012, due in part to smart grid and system improvements. The avoided outages have resulted in $2.4 billion in estimated savings to society. In addition to keeping energy flowing for residents, strong power reliability continues to help persuade industrial and commercial companies to expand in northern Illinois and Chicago. The GridWise Alliance recently recognized Illinois as the No. 2 state in the nation for its smart grid implementation.

"Our smart grid investments has vastly improved the infrastructure of our system," said Terry Donnelly, ComEd president and chief operating officer. "We review the system and our operations continually to make sure we're investing in areas that benefit the greatest number of customers, and to prepare for public-health emergencies as well. On a daily basis and during storms or to reduce wildfire risk when necessary, our customers are seeing fewer and fewer interruptions to their lives and businesses."

ComEd customers also set records for energy savings this summer. Through its Peak Time Savings program and other energy-efficiency programs offered by utilities, ComEd empowered nearly 300,000 families and individuals to lower their bills by a total of more than $4 million this summer for voluntarily reducing their energy use during times of peak demand. Since the Peak Time Savings program launched in 2015, participating customers have earned a total of more than $10 million in bill credits.

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