Price rises amid plentiful power

By Toronto Star


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Ontario's electricity supply is the healthiest it has been in a decade, says the province's Independent Electricity System Operator IESO.

In fact, at times in the coming months the power system will produce more power than the province can use.

That means it should be safe to carry on with plans to shut down the province's coal-fired generating stations, the IESO says in its latest 18-month forecast.

Shutting down the remaining coal plants, as the province has promised, will take 2,000 megawatts out of the system by 2014. Ontario needs about 20,000 megawatts of power at peak periods on a day with moderate temperatures. On a very hot or cold day, the peak demand can rise to 25,000 megawatts.

Offsetting the coal shutdown, two refurbished units at the Bruce A nuclear station are due to be back in service by the end of 2011, adding 1,500 megawatts of supply.

In addition, 600 megawatts of natural gas-fired generation are expected over the next 18 months, and another 1,200 megawatts from renewable sources, primarily wind.

Meanwhile demand for power, which slumped during the recession, is rebounding slowly. Conservation programs will dampen the demand for power by a meager 100 megawatts over the 18-month period.

Energy Minister Brad Duguid hailed the report.

"We can safely say that we're providing a stable and sustainable supply of energy moving forward," he said in an interview.

The report notes that the system may at times produce more power than it can handle.

That means power has to be exported, or plants that normally run 24 hours a day – such as a nuclear unit or a major hydro station – must shut down.

While the forecast paints a rosy picture of the energy supply, consumers are facing sharp electricity price increases in the months ahead – partly because of the HST, partly because the province is offering much higher prices to new generation projects.

But Duguid said that's no reason to back away from the province's aggressive plans to keep adding new supply and new transmission lines.

"We're going to require sources of supply beyond those 18 months," he said.

"There's no question that the costs of energy supply are on the rise, not only in Ontario but around the world. We need to make sure we're making the investments necessary to make sure Ontarians have the power they need, the transmission reliability they need and at the same time producing energy in a much cleaner way."

Wind developments, in particular, have been running into increasing opposition from residents who say the turbines are noisy and despoil the countryside.

But Duguid said wind is part of a "very healthy mix" of renewable, nuclear and gas-fired generation.

Part of the overall plan is to create 50,000 jobs, in part by attracting manufacturers of generating equipment, including wind turbines, he said.

The province still plans to build two new nuclear reactors at the Darlington nuclear station, he said, but uncertainty over the future of Atomic Energy of Canada Ltd. is clouding the picture.

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Quebec Hit by Widespread Power Outages Following Severe Windstorm

Quebec Windstorm 2025 disrupted Montreal and surrounding regions, triggering power outages, Hydro-Québec repairs, fallen trees, infrastructure damage, and transport delays, while emergency response and community resilience accelerated restoration and recovery efforts across the province.

 

Key Points

A severe April 29 windstorm with 100 km/h gusts caused outages, damage, and emergency recovery across Quebec.

✅ Gusts exceeded 100 km/h across Montreal and nearby regions

✅ Hydro-Québec restored power; crews cleared debris and lines

✅ Communities shared resources, shelters, and volunteer support

 

A powerful windstorm swept across Quebec on April 29, 2025, leaving tens of thousands of residents without electricity and causing significant damage to infrastructure. The storm's intensity disrupted daily life, leading to widespread outages across the province, fallen trees, and transportation delays.

Storm's Impact

The windstorm, characterized by gusts exceeding 100 km/h, struck various regions of Quebec, including Montreal and its surrounding areas. Hydro-Québec reported extensive power outages affecting numerous customers. The storm's ferocity led to the uprooting of trees, downing of power lines, and significant damage to buildings and vehicles.

Response and Recovery Efforts

In the aftermath, emergency services and utility companies mobilized to restore power and clear debris. Hydro-Québec crews worked tirelessly, much like Sudbury Hydro teams did in Ontario, to repair damaged infrastructure, while municipal authorities coordinated efforts to ensure public safety and facilitate the restoration process. Despite these efforts, some areas experienced prolonged outages, highlighting the storm's severity.

Community Resilience

Residents demonstrated remarkable resilience during the crisis. Many communities came together to support one another, as seen when Toronto neighborhoods rallied during lingering outages, sharing resources and providing assistance to those in need. Local shelters were set up to offer warmth and supplies to displaced individuals, and volunteers played a crucial role in the recovery process.

Lessons Learned

The storm underscored the importance of preparedness and infrastructure resilience, including vulnerabilities highlighted by a recent manhole fire affecting Hydro-Québec customers. In response, discussions have been initiated regarding the strengthening of power grids and the implementation of more robust emergency response strategies to mitigate the impact of future natural disasters.

As Quebec continues to recover, the collective efforts of its residents and emergency services serve as a testament to the province's strength and unity, even as similar strong-wind outages affect other regions, in the face of adversity.

 

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U.S. residential electricity bills increased 5% in 2022, after adjusting for inflation

U.S. Residential Electricity Bills rose on stronger demand, inflation, and fuel costs, with higher retail prices, kWh consumption, and extreme weather driving 2022 spikes; forecasts point to stable summer usage and slight price increases.

 

Key Points

They are average household power costs shaped by prices, kWh use, weather, and upstream fuel costs.

✅ 2022 bills up 13% nominal, 5% real vs. 2021

✅ Retail price rose 11%; consumption up 2% to 907 kWh

✅ Fuel costs to plants up 34%, pressuring rates

 

In nominal terms, the average monthly electricity bill for residential customers in the United States increased 13% from 2021 to 2022, rising from $121 a month to $137 a month. After adjusting for inflation—which reached 8% in 2022, a 40-year high—electricity bills increased 5%. Last year had the largest annual increase in average residential electricity spending since we began calculating it in 1984. The increase was driven by a combination of more extreme temperatures, which increased U.S. consumption of electricity for both heating and cooling, and higher fuel costs for power plants, which drove up retail electricity prices nationwide.

Residential electricity customers’ monthly electricity bills are based on the amount of electricity consumed and the retail electricity price. Average U.S. monthly electricity consumption per residential customer increased from 886 kilowatthours (kWh) in 2021 to 907 kWh in 2022, even as U.S. electricity sales have declined over the past seven years. Both a colder winter and a hotter summer contributed to the 2% increase in average monthly electricity consumption per residential customer in 2022 because customers used more space heating during the winter and more air conditioning during the summer, with some states, such as Pennsylvania, facing sharp winter rate increases.

Although we don’t directly collect retail electricity prices, we do collect revenues from electricity providers that allow us to determine prices by dividing by consumption, and industry reports show major utilities spending more on electricity delivery than on power production. In 2022, the average U.S. residential retail electricity price was 15.12 cents/kWh, an 11% increase from 13.66 cents/kWh in 2021. After adjusting for inflation, U.S. residential electricity prices went up by 2.5%.

Higher fuel costs for power plants drove the increase in residential retail electricity prices. The cost of fossil fuels—including natural gas prices, coal, and petroleum—delivered to U.S. power plants increased 34%, from $3.82 per million British thermal units (MMBtu) in 2021 to $5.13/MMBtu in 2022. The higher fuel costs were passed along to residential customers and contributed to higher retail electricity prices, and Germany power prices nearly doubled over a year in a related trend.

In the first three months of 2023, the average U.S. residential monthly electricity bill was $133, or 5% higher than for the same time last year, according to data from our Electric Power Monthly. The increase was driven by a 13% increase in the average U.S. residential retail electricity price, which was partly offset by a 7% decrease in average monthly electricity consumption per residential customer, and industry outlooks also see U.S. power demand sliding 1% on milder weather. This summer, we expect that typical household electricity bills will be similar to last year’s, with customers paying about 2% more on average. The slight increase in electricity costs forecast for this summer stems from higher retail electricity prices but similar consumption levels as last summer.
 

 

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Egypt, Eni ink MoU on hydrogen production projects

Egypt-ENI Hydrogen MoU outlines joint feasibility studies for green and blue hydrogen using renewable energy, carbon capture, and CO2 storage, targeting domestic demand, exports, and net-zero goals within Egypt's energy transition.

 

Key Points

A pact to study green and blue hydrogen in Egypt, leveraging renewables, CO2 storage, and export/demand pathways.

✅ Feasibility study for green and blue hydrogen projects

✅ Uses renewables, SMR, carbon capture, and CO2 storage

✅ Targets local demand, exports, and net-zero alignment

 

The Egyptian Electricity Holding Company (EEHC) and the Egyptian Natural Gas Holding Company (EGAS) signed a memorandum of understanding (MoU) with the Italian energy giant Eni to assess the technical and commercial feasibility of green and blue hydrogen production projects in Egypt, which many see as central to power companies' future strategies worldwide today.

Under the MoU, a study will be conducted to assess joint projects for the production of green hydrogen using electricity generated from renewable energy and supported by regional electricity interconnections where relevant, and blue hydrogen using the storage of CO2 in depleted natural gas fields, according to a statement by the Ministry of Petroleum on Thursday.

The study will also estimate the potential local market consumption of hydrogen and export opportunities, taking cues from Ontario's hydrogen economy proposal to align electricity rates for growth.

This agreement is part of Eni's objective to achieve zero net emissions by 2050 and Egypt's strategy towards diversifying the energy mix and developing hydrogen projects in collaboration with major international companies, taking note of Italy's green hydrogen initiatives in Sicily as a comparable effort.

It signed the deal with Egyptian Natural Gas Holding (EGAS) and Egyptian Electricity Holding Co. (EEHC).

The companies will carry out a joint study on producing renewable energy powered green hydrogen, informed by electrolyzer investments in similar projects, where applicable. They will also work on blue hydrogen. This involves reforming natural gas and capturing the resulting CO2, in this instance in depleted natural gas fields.

The study will also consider domestic hydrogen use and export options, including funding models like the Hydrogen Innovation Fund now in Ontario.

Eni said the MoU was in line with its plans to eliminate net emissions and emissions cancel emission intensity by 2050. The company noted the agreement was in line with Egypt’s plan for the energy transition, in which it pursues hydrogen plans with major international companies, alongside broader clean-tech collaboration such as Tesla cooperation discussions in Dubai, to accelerate progress.

 

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Learn how fees and usage impacts your electricity bill in new online CER tool

CER Interactive Electricity Bill Tool compares provincial electricity prices, fees, taxes, and usage. Explore household appliance costs, hydroelectric generation, and consumption trends across Canada with interactive calculators and a province-by-province breakdown.

 

Key Points

An online CER report with calculators comparing electricity prices, fees, and usage to explain household energy costs.

✅ Province-by-province bill, price, and consumption comparison

✅ Calculator for appliance and electronics energy costs

✅ Explains fees, taxes, regulation, and generation sources

 

Canadians have a new way to assess their electricity bill in a new, interactive online report released by the Canada Energy Regulator (CER).

The report titled What is in a residential electricity bill? features a province-to-province comparison of electricity bills, generation and consumption. It also explains electricity prices across the country, including how Calgary electricity prices have changed, allowing people to understand why costs vary depending on location, fees, regulation and taxes.  

Learn how fees and usage impacts your electricity bill in new online CER tool
Interactive tools allow people to calculate the cost of household appliances and electronic use for each province and territory, and to understand how Ontario rate increases may affect monthly bills. For example, an individual can use the tools to find out that leaving a TV on for 24-hours in Quebec costs $5.25 per month, while that same TV on for a whole day would cost $12.29 per month in Saskatchewan, $20.49 per month in the Northwest Territories, and $15.30 per month in Nova Scotia.

How Canadians use energy varies as much as how provinces and territories produce it, especially in regions like Nunavut where unique conditions influence costs. Millions of Canadians rely on electricity to power their household appliances, charge their electronics, and heat their homes. Provinces with abundant hydro-electric resources like Quebec, B.C., Manitoba, and Newfoundland and Labrador use electricity for home heating and tend to consume the most electricity.

By gathering data from various sources, this report is the first Canadian publication that features interactive tools to allow for a province-by-province comparison of electricity bills while highlighting different elements within an electricity bill, a helpful context as Canada faces a critical supply crunch in the years ahead.

The CER monitors energy markets and assesses Canadian energy requirements and trends, including clean electricity regulations developments that shape pricing. This report is part of a portfolio of publications on energy supply, demand and infrastructure that the CER publishes regularly as part of its ongoing market monitoring.

"No matter where you go in the country, Canadians want to know how much they pay for power and why, especially amid price spikes in Alberta this year," says lead author Colette Craig. "This innovative, interactive report really explains electricity bills to help everyone understand electricity pricing and consumption across Canada."

Quick Facts

  • Quebec ranks first in electricity consumption per capita at 21.0 MW.h, followed by Saskatchewan at 20.0 MW.h, Newfoundland and Labrador at 19.3 MW.h.
  • About 95% of Quebec's electricity is produced from hydroelectricity.
  • Provinces that use electricity for home heating tend to consume the most electricity.
  • Canada's largest consuming sector for electricity was industrial at 238 TW.h. The residential and commercial sectors consumed 168 TW.h and 126 TW.h, respectively.
  • In 2018, Canada produced 647.7 terawatt hours (TW.h) of electricity. More than half of the electricity in Canada (61%) is generated from hydro sources. The remainder is produced from a variety of sources, such as fossil fuels (natural gas and petroleum), nuclear, wind, coal, biomass, solar.
  • Canada is a net exporter of electricity. In 2019, net exports to the U.S. electricity market totaled 47.0 TW.h.
  • The total value of Canada's electricity exports was $2.5 billion Canadian dollars and the value of imports was $0.6 billion Canadian dollars, resulting in 2019 net exports of $1.9 billion.
  • All regions in Canada are reflected in this report but it does not include data that reflects the COVID-19 lockdown and its effects on residential electricity bills.
     

 

 

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Economic Crossroads: Bank Earnings, EV Tariffs, and Algoma Steel

Canada Economic Crossroads highlights bank earnings trends, interest rates, loan delinquencies, EV tariffs on Chinese imports, domestic manufacturing, Algoma Steel decarbonization, sustainability, and housing market risks shaping growth, investment, consumer prices, and climate policy.

 

Key Points

An overview of how bank earnings, EV tariffs, and Algoma Steel's transition shape Canada's economy.

✅ Higher rates lift margins but raise delinquencies and housing risks

✅ EV tariffs aid domestic makers but pressure consumer prices

✅ Algoma invests to decarbonize, boosting efficiency and compliance

 

In a complex economic landscape, recent developments have brought attention to several pivotal issues affecting Canada's business sector. The Globe and Mail’s latest report delves into three major topics: the latest bank earnings, the implications of new tariffs on Chinese electric vehicles (EVs), and Algoma Steel’s strategic maneuvers. These factors collectively paint a picture of the challenges and opportunities facing Canada's economy.

Bank Earnings Reflect Economic Uncertainty

The recent financial reports from major Canadian banks have revealed a mixed picture of the nation’s economic health. As the Globe and Mail reports, earnings results show robust performances in some areas while highlighting growing concerns in others. Banks have generally posted strong quarterly results, buoyed by higher interest rates which have improved their net interest margins. This uptick is largely attributed to the central bank's monetary policies aimed at combating inflation and stabilizing the economy.

However, the positive earnings are tempered by underlying economic uncertainties. Rising loan delinquencies and a slowing housing market are areas of concern. Increased interest rates, while beneficial for banks’ margins, have also led to higher borrowing costs for consumers and businesses. This dynamic has the potential to impact overall economic growth and consumer confidence.

Tariffs on Chinese EVs: A Strategic Shift

Another significant development is the imposition of new tariffs on Chinese electric vehicles. This move is part of a broader strategy to protect domestic automotive industries and address trade imbalances, aligning with public support for tariffs in key sectors. The tariffs are expected to increase the cost of Chinese EVs in Canada, which could have several implications for the market.

On one hand, the tariffs might provide a temporary boost to Canadian and North American manufacturers by reducing competition from lower-priced Chinese imports. This protectionist measure could encourage investments in local production and innovation, mirroring tariff threats boosting support for energy projects in other sectors. However, the increased cost of Chinese EVs may also lead to higher prices for consumers, potentially slowing the adoption of electric vehicles—a critical goal in Canada’s climate strategy.

The tariffs come at a time when the Canadian government is keen on accelerating the transition to electric mobility to meet its environmental targets, even as a critical crunch in electrical supply raises questions about grid readiness. Balancing the protection of domestic industries with the broader goal of reducing emissions will be a significant challenge moving forward.

Algoma Steel’s Strategic Evolution

In the steel industry, Algoma Steel has been making headlines with its strategic initiatives aimed at transforming its operations, in a broader shift toward clean grids and industrial decarbonization. The Globe and Mail highlights Algoma Steel's efforts to modernize its production processes and shift towards more sustainable practices. This includes significant investments in technology and infrastructure to enhance production efficiency and reduce environmental impact.

Algoma's focus on reducing carbon emissions aligns with broader industry trends towards sustainability. The company’s efforts are part of a larger push within the steel sector to address climate change and meet regulatory requirements. As one of Canada’s leading steel producers, Algoma’s actions could set a precedent for the industry, showcasing how traditional manufacturing sectors can adapt to evolving environmental standards.

Implications and Future Outlook

The interplay of these developments reflects a period of significant transition for Canada's economy, shaped in part by U.S. policy where Biden is seen as better for Canada's energy sector by some analysts. For banks, the challenge will be to navigate the balance between profitability and potential risks from a changing economic environment. The new tariffs on Chinese EVs represent a strategic shift with mixed implications for the automotive market, potentially influencing both domestic production and consumer prices. Meanwhile, Algoma Steel’s push towards sustainability could serve as a model for other industries seeking to align with environmental goals.

As these issues unfold, stakeholders across sectors will need to stay informed and adaptable. For policymakers, the challenge will be to support domestic industries while fostering innovation and sustainability, including the dilemma over electricity rates and innovation they must weigh. For businesses, the focus will be on navigating financial pressures and leveraging opportunities for growth. Consumers, in turn, will face the impact of these developments in their daily lives, from the cost of borrowing to the price of electric vehicles.

In summary, Canada’s current economic landscape is characterized by a blend of financial resilience, strategic adjustments, and evolving industry practices, amid policy volatility such as a tariff threat delaying Quebec's green energy bill earlier this year. As the country navigates these crossroads, the outcomes of these developments will play a crucial role in shaping the future economic environment.

 

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B.C. ordered to pay $10M for denying Squamish power project

Greengen Misfeasance Ruling details a B.C. Supreme Court decision awarding $10.125 million over wrongfully denied Crown land and water licence permits for a Fries Creek run-of-river hydro project under a BC Hydro contract.

 

Key Points

A B.C. Supreme Court ruling awarding $10.125M for wrongful denial of Crown land and water licences on Greengen's project.

✅ $10.125M damages for misfeasance in public office

✅ Denial of Crown land tenure and water licence permits

✅ Tied to Fries Creek run-of-river and BC Hydro EPA

 

A B.C. Supreme Court judge has ordered the provincial government to pay $10.125 million after it denied permits to a company that wanted to build a run-of-the river independent power project near Squamish.

In his Oct. 10 decision, Justice Kevin Loo said the plaintiff, Greengen Holdings Ltd., “lost an opportunity to achieve a completed and profitable hydro-electric project” after government representatives wrongfully exercised their legal authority, a transgression described in the ruling as “misfeasance,” with separate concerns reflected in an Ontario market gaming investigation reported elsewhere.

Between 2003 and 2009, the company sought to develop a hydro-electric project on and around Fries Creek, which sits opposite the Brackendale neighbourhood on the other side of the Squamish River. To do so, Greengen Holdings Ltd. required a water licence from the Minister of the Environment and tenure over Crown land from the Minister of Agriculture.

After a lengthy process involving extensive communications between Greengen and various provincial and other ministries and regulatory agencies, the permits were denied, according to Loo. Both decisions cited impacts on Squamish Nation cultural sites that could not be mitigated.

Elsewhere, an Indigenous-owned project in James Bay proceeded despite repeated denials, underscoring varied approaches to community participation.

40-year electricity plan relied on Crown land
The case dates back to December 2005, when BC Hydro issued an open call for power with Greengen. The company submitted a tender several months later.

On July 26, 2006, BC Hydro awarded Greengen an energy purchase agreement, amid evolving LNG electricity demand across the province, under which Greengen would be entitled to supply electricity at a fixed price for 40 years.

Unlike conventional hydroelectric projects, such as new BC generating stations recently commissioned, which store large volumes of water in reservoirs, and in so doing flood large tracts of land, a run of the river project often requires little or no water storage. Instead, from a high elevation, they divert water from a stream or river channel.

Water is then sent into a pressured pipeline known as a penstock, and later passed through turbines to generate electricity, Loo explained, as utilities pursue long-term plans like the Hydro-Québec strategy to reduce fossil fuel reliance. The system returns water to the original stream or river, or into another body of water. 

The project called for most of that infrastructure to be built on Crown land, according to the ruling.

All sides seemed to support the project
In early 2005, company principle Terry Sonderhoff discussed the Fries Creek project in a preliminary meeting with Squamish Nation Chief Ian Campbell.

“Mr. Sonderhoff testified that Chief Campbell seemed supportive of the project at the time,” Loo said.

 

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