Hydro-Québec launches plug-in vehicles project

By Hydro-Québec


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Hydro-Québec^^s research institute IREQ has chosen GRIDbot Canada—whose products are manufactured in Shawinigan, Québec—the contract for the development and supply of an advanced bidirectional charging station for an experimental project on vehicle-to-grid and vehicle-to-home power exchanges V2G-V2H.

The goal of vehicle-to-grid V2G systems is to use the electricity stored in the batteries of plug-in vehicles as backup energy for electricity grids, such as the Hydro-Québec power system, during peak periods.

Vehicle-to-home V2H systems, on the other hand, allow plug-in vehicle owners to use the energy stored in the battery as a temporary power source during outages, as they would a generator.

To carry out the project, IREQ will assemble an electric test vehicle that will showcase Québec-designed technologies. TM4, a Hydro-Québec subsidiary, will supply a latest-generation TM4 MФTIVE electric power train system.

B3CG Interconnect, a company from Saint-Eustache, along with its partners, the Centre National du Transport Avancé national centre for advanced transportation in Saint-Jérôme and Brioconcept, based in Laval, developed a bidirectional charger that will be integrated to the charging station built.

Exchanging power between vehicles and the home or the grid is a promising development opportunity. "We would like to better define the long-term potential of this technology," said Denis Faubert, General Manager of IREQ. "Through this initiative, Hydro-Québec will continue to spearhead the integration of electric vehicles into the power system and become a showcase for Québec know-how."

The project will receive financial support from the Québec government as part of its 2011 to 2020 Action Plan for Electric Vehicles. This plan gave Hydro-Québec a mandate to define the implications of these innovative concepts and to carry out all required experiments.

"The Hydro-Québec project is a unique occasion to develop GRIDbot Canada's V2G and V2H technologies. Our Shawinigan-built bidirectional charging station will be based on the ingenuity developed here in Québec with the support and expertise of the IREQ team," said Éric Martel, administrator and project manager at GRIDbot Canada.

"This type of project is important for Hydro-Québec since it allows us to work with our partners in Québec to develop promising and interesting long-term technologies for our customers who will purchase plug-in electric vehicles," added Pierre-Luc Desgagné, Senior Director - Strategic Planning at Hydro-Québec.

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Typical Ontario electricity bill set to increase nearly 2% as fixed pricing ends

Ontario Electricity Rates update: OEB sets time-of-use and tiered pricing for residential customers, with kWh charges for peak, mid-peak, and off-peak periods reflecting COVID-19 impacts on demand, supply costs, and pricing.

 

Key Points

Ontario Electricity Rates are OEB-set time-of-use and tiered prices that set per-kWh costs for residential customers.

✅ Time-of-use: 21.7 peak, 15.0 mid-peak, 10.5 off-peak cents/kWh

✅ Tiered: 12.6 cents/kWh up to 1000 kWh, then 14.6 cents/kWh

✅ Average 700 kWh home pays about $2.24 more per month

 

Energy bills for the typical Ontario home are going up by about two per cent with fixed pricing coming to an end on Nov. 1, the Ontario Energy Board says. 

The province's electricity regulator has released new time-of-use pricing and says the rate for the average residential customer using 700 kWh per month will increase by about $2.24.

The change comes as Ontario stretches into its eight month of the COVID-19 pandemic with new case counts reaching levels higher than ever seen before.

Time-of-use pricing had been scrapped for residential bills for much for the pandemic with a single fixed COVID-19 hydro rate set for all hours of the day. The move, which came into effect June 1, was meant "to support families, small business and farms while Ontario plans for the safe and gradual reopening of the province," the OEB said at the time.

Ontario later set the off-peak price until February 7 around the clock to provide additional relief.

Fixed pricing meant customers' bills reflected how much power they used, rather than when they used it. Customers were charged 12.8 cents/kWh under the COVID-19 recovery rate no matter their time of use.

Beginning November, the province says customers can choose between time-of-use and tiered pricing options. Rates for time-of-use plans will be 21.7 cents/kWh during peak hours, 15 cents/kWh for mid-peak use and 10.5 cents/kWh for off-peak use. 

Customers choosing tiered pricing will pay 12.6 cents/kWh for the first 1000 kWh each month and then 14.6 cents/kWh for any power used beyond that.

The energy board says the increase in pricing reflects "a combination of factors, including those associated with the COVID-19 pandemic, that have affected demand, supply costs and prices in the summer and fall of 2020."

Asked for his reaction to the move Tuesday, Premier Doug Ford said, "I hate it," adding the province inherited an energy "mess" from the previous Liberal government and are "chipping away at it."

 

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Explainer: Why nuclear-powered France faces power outage risks

France Nuclear Power Outages threaten the grid as EDF reactors undergo stress corrosion inspections, maintenance delays, and staff shortages, driving electricity imports, peak-demand curtailment plans, and potential rolling blackouts during a cold snap across Europe.

 

Key Points

EDF maintenance and stress corrosion cut reactor output, forcing imports and blackouts as cold weather lifts demand.

✅ EDF inspects stress corrosion cracks in reactor piping

✅ Maintenance backlogs and skilled labor shortages slow repairs

✅ Government plans demand cuts, imports, and rolling blackouts

 

France is bracing for possible power outages in the coming days as falling temperatures push up demand while state-controlled nuclear group EDF struggles to bring more production on line.


WHY CAN'T FRANCE MEET DEMAND?
France is one of the most nuclear-powered countries in the world, with a significant role of nuclear power in its energy mix, typically producing over 70% of its electricity with its fleet of 56 reactors and providing about 15% of Europe's total power through exports.

However, EDF (EDF.PA) has had to take a record number of its ageing reactors offline for maintenance this year just as Europe is struggling to cope with cuts in Russian natural gas supplies used for generating electricity, with electricity prices surging across the continent this year.

That has left France's nuclear output at a 30-year low, and mirrors how Europe is losing nuclear power more broadly, forcing France to import electricity and prepare plans for possible blackouts as a cold snap fuels demand for heating.


WHAT ARE EDF'S MAINTENANCE PROBLEMS?
While EDF normally has a number of its reactors offline for maintenance, it has had far more than usual this year due to what is known as stress corrosion on pipes in some reactors, and during heatwaves river temperature limits have constrained output further.

At the request of France's nuclear safety watchdog, EDF is in the process of inspecting and making repairs across its fleet since detecting cracks in the welding connecting pipes in one reactor at the end of last year.

Years of under-investment in the nuclear sector mean that there is precious little spare capacity to meet demand while reactors are offline for maintenance, and environmental constraints such as limits on energy output during high river temperatures reduce flexibility.

France also lacks specialised welders and other workers in sufficient numbers to be able to make repairs fast enough to get reactors back online.

 

WHAT IS BEING DONE?
In the very short term, after a summer when power markets hit records as plants buckled in heat, there is little that can be done to get more reactors online faster, leaving the government to plan for voluntary cuts at peak demand periods and limited forced blackouts.

In the very short term, there is little that can be done to get more reactors online faster, leaving the government to plan for voluntary cuts at peak demand periods and limited forced blackouts.

Meanwhile, EDF and others in the French nuclear industry are on a recruitment drive for the next generation of welders, pipe-fitters and boiler makers, going so far as to set up a new school to train them.

President Emmanuel Macron wants a new push in nuclear energy, even as a nuclear power dispute with Germany persists, and has committed to building six new reactors at a cost his government estimates at nearly 52 billion euros ($55 billion).

As a first step, the government is in the process of buying out EDF's minority shareholders and fully nationalising the debt-laden group, which it says is necessary to make the long-term investments in new reactors.
 

 

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Warren Buffett’s Secret To Cheap Electricity: Wind

Berkshire Hathaway Energy Wind Power drives cheap electricity rates in Iowa via utility-scale wind turbines, integrated transmission, battery storage, and grid management, delivering renewable energy, stable pricing, and long-term rate freezes through 2028.

 

Key Points

A vertically integrated wind utility lowering Iowa rates via owned generation, transmission, and advanced grid control.

✅ Owned wind assets meet Iowa residential demand

✅ Integrated transmission lowers costs and losses

✅ Rate freeze through 2028 sustains cheap power

 

In his latest letter to Berkshire Hathaway shareholders, Warren Buffett used the 20th anniversary of Berkshire Hathaway Energy to tout its cheap electricity bills for customers.

When Berkshire purchased the majority share of BHE in 2000, the cost of electricity for its residential customers in Iowa was 8.8 cents per kilowatt-hour (kWh) on average. Since then, these electricity rates have risen at a paltry <1% per year, with a freeze on rate hikes through 2028. As anyone who pays an electricity bill knows, that is an incredible deal.  

As Buffett himself notes with alacrity, “Last year, the rates [BHE’s competitor in Iowa] charged its residential customers were 61% higher than BHE’s. Recently, that utility received a rate increase that will widen the gap to 70%.”

 

The Winning Strategy

So, what’s Buffett’s secret to cheap electricity? Wind power.

“The extraordinary differential between our rates and theirs is largely the result of our huge accomplishments in converting wind into electricity,” Buffett explains. 

Wind turbines in Iowa that BHE owns and operates are expected to generate about 25.2 million megawatt-hours (MWh) of electricity for its customers, as projects like Building Energy operations begin to contribute. By Buffett’s estimations, that will be enough to power all of its residential customers’ electricity needs in Iowa.  


The company has plans to increase its renewable energy generation in other regions as well. This year, BHE Canada is expected to start construction on a 117.6MW wind farm in Alberta, Canada with its partner, Renewable Energy Systems, that will provide electricity to 79,000 homes in Canada’s oil country.

Observers note that Alberta is a powerhouse for both green energy and fossil fuels, underscoring the region's unique transition.

But I would argue that the secret to BHE’s success perhaps goes deeper than transitioning to sources of renewable energy. There are plenty of other utility companies that have adopted wind and solar power as an energy source. In the U.S., where renewable electricity surpassed coal in 2022, at least 50% of electricity customers have the option to buy renewable electricity from their power supplier, according to the Department of Energy. And some states, such as New York, have gone so far as to allow customers to pick from providers who generate their electricity.

What differentiates BHE from a lot of the competition in the utility space is that it owns the means to generate, store, transmit and supply renewable power to its customers across the U.S., U.K. and Canada, with lessons from the U.K. about wind power informing policy.

In its financial filings for 2019, the company reported that it owns 33,600MW of generation capacity and has 33,400 miles of transmission lines, as well as a 50% interest in Electric Transmission Texas (ETT) that has approximately 1,200 miles of transmission lines. This scale and integration enables BHE to be efficient in the distribution and sale of electricity, including selling renewable energy across regions.

BHE is certainly not alone in building renewable-energy fueled electricity dominions. Its largest competitor, NextEra, built 15GW of wind capacity and has started to expand its utility-scale solar installations. Duke Energy owns and operates 2,900 MW of renewable energy, including wind and solar. Exelon operates 40 wind turbine sites across the U.S. that generate 1,500 MW.

 

Integrated Utilities Power Ahead

It’s easy to see why utility companies see wind as a competitive source of electricity compared to fossil fuels. As I explained in my previous post, Trump’s Wrong About Wind, the cost of building and generating wind energy have fallen significantly over the past decade. Meanwhile, improvements in battery storage and power management through new technological advancements have made it more reliable (Warren Buffett bet on that one too).

But what is also striking is that integrated power and transmission enables these utility companies to make those decisions; both in terms of sourcing power from renewable energy, as well as the pricing of the final product. Until wind and solar power are widespread, these utility companies are going to have an edge of the more fragmented ends of the industry who can’t make these purchasing or pricing decisions independently. 

Warren Buffett very rarely misses a beat. He’s not the Oracle of Omaha for nothing. Berkshire Hathaway’s ownership of BHE has been immensely profitable for its shareholders. In the year ended December 31, 2019, BHE and its subsidiaries reported net income attributable to BHE shareholders of $2.95 billion.

There’s no question that renewable energy will transform the utility industry over the next decade. That change will be led by the likes of BHE, who have the power to invest, control and manage their own energy generation assets.

 

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Christmas electricity spike equivalent to roasting 1.5 million turkeys: BC Hydro

BC Hydro Holiday Energy Saving Tips highlight electricity usage trends and power conservation during Christmas cooking. Use efficient appliances, lower the thermostat, and track consumption with MyHydro to reduce bills while hosting guests.

 

Key Points

Guidelines from BC Hydro to cut holiday electricity usage via efficient cooking, smart thermostats, and MyHydro tracking.

✅ Use microwave, toaster oven, or slow cooker to save power.

✅ Batch-bake cookies and pies to minimize oven cycles.

✅ Set thermostat to 18 C and monitor use with MyHydro.

 

BC Hydro is reminding British Columbians to conserve power over the holidays after a report commissioned by the utility found the arrival of guests for Christmas dinner results in a 15% increase in electricity usage, and it expects holiday usage to rise as gatherings ramp up.

Cooking appears to be the number one culprit for the uptick in peoples’ hydro bills. According to BC Hydro press release, British Columbians use about 8,000 megawatt hours more of electricity by mid-day Christmas — that's about 1.5 million turkeys roasted in electric ovens — while Ontario electricity demand shifted as people stayed home during the pandemic.
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About 95% of British Columbians said they would make meals at home from scratch over the holiday season, mirroring the uptick in residential electricity use observed during the pandemic. The survey found that inviting friends or family over trumped any plans people had to buy pre-made meals or order take-out. Six in 10 respondents said they would also rather bake holiday treats than pick them up pre-made from the store. 

The survey also showed people in B.C. are taking steps to reduce their electricity usage, echoing earlier findings that many British Columbians changed daily electricity habits during the pandemic. When participants were asked whether they were conscious of how much electricity they used when visiting friends or family, 80% said they would be taking steps to limit their usage.


And while cooking meals from scratch over the holidays may contribute to a spike in a person's electricity bill, some studies have found that, when comparing their overall environmental impact against that of ready-made meals, a roasted dinner has a lower negative impact.

Still, there are many ways to improve your energy efficiency and save some money over the holiday season, and conserving can also help the grid during events like the recent atypical storm response noted by BC Hydro. BC Hydro recommends:

• using smaller appliances whenever possible, such as a microwave, crockpot or toaster oven as they use less than half the power of a regular electric oven;

• baking cookies or pies in batches to save energy;

• turning down the household thermostat to 18 C when possible to reduce costs during peak hydro rates where applicable;

• and tracking how much electricity you use through the MyHydro tool alongside potential time-of-use rates for smarter scheduling

 

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NDP takes aim at approval of SaskPower 8 per cent rate hike

SaskPower Rate Hike 2022-2023 signals higher electricity rates in Saskatchewan as natural gas costs surge; the Rate Review Panel approved increases, affecting residential utility bills amid affordability concerns and government energy policy shifts.

 

Key Points

An 8% SaskPower electricity rate increase split 4% in Sept 2022 and 4% in Apr 2023, driven by natural gas costs.

✅ 4% increase Sept 1, 2022; +4% on Apr 1, 2023

✅ Panel-approved amid natural gas price surge and higher fuel costs

✅ Avg residential bill up about $5 per step; affordability concerns

 

The NDP Opposition is condemning the provincial government’s decision to approve the Saskatchewan Rate Review Panel’s recommendation to increase SaskPower’s rates for the first time since 2018, despite a recent 10% rebate pledge by the Sask. Party.

The Crown electrical utility’s rates will increase four per cent this fall, and another four per cent in 2023, a trajectory comparable to BC Hydro increases over two years. According to a government news release issued Thursday, the new rates will result in an average increase of approximately $5 on residential customers’ bills starting on Sept. 1, 2022, and an additional $5 on April 1, 2023.

“The decision to increase rates is not taken lightly and came after a thorough review by the independent Saskatchewan Rate Review Panel,” Minister Responsible for SaskPower Don Morgan said in a news release, amid Nova Scotia’s 14% hike this year. “World events have caused a significant rise in the price of natural gas, and with 42 per cent of Saskatchewan’s electricity coming from natural gas-fueled facilities, SaskPower requires additional revenue to maintain reliable operations.”

But NDP SaskPower critic Aleana Young says the rate hike is coming just as businesses and industries are struggling in an “affordability crisis,” even as Manitoba Hydro scales back a planned increase next year.

She called the announcement of an eight per cent increase in power bills on a summer day before the long weekend “a cowardly move” by the premier and his cabinet, amid comparable changes such as Manitoba’s 2.5% annual hikes now proposed.

“Not to mention the Sask. Party plans to hike natural gas rates by 17% just days from now,” said Young in a news release issued Friday, as Manitoba rate hearings get underway nearby. “If Scott Moe thinks his choices — to not provide Saskatchewan families any affordability relief, to hike taxes and fees, then compound those costs with utility rate hikes — are defensible, he should have the courage to get out of his closed-door meetings and explain himself to the people of this province.”

The province noted natural gas is the largest generation source in SaskPower’s fleet. As federal regulations require the elimination of conventional coal generation in Canada by 2030, SaskPower’s reliance on natural gas generation is expected to grow, with experts in Alberta warning of soaring gas and power prices in the region. Fuel and Purchased Power expense increases are largely driven by increased natural gas prices, and SaskPower’s fuel and purchased power expense is expected to increase from $715 million in 2020-21 to $1.069 billion in 2023-24. This represents a 50 per cent increase in fuel and purchased power expense over three years.

“In the four years since our last increase SaskPower has worked to find internal efficiencies, but at this time we require additional funding to continue to provide reliable and sustainable power,” SaskPower president & CEO Rupen Pandya said in the release “We will continue to be transparent about our rate strategy and the need for regular, moderate increases.”

 

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Should California Fund Biofuels or Electric Vehicles?

California Biofuels vs EV Subsidies examines tradeoffs in decarbonization, greenhouse gas reductions, clean energy deployment, charging infrastructure, energy security, lifecycle emissions, and transportation sector policy to meet climate goals and accelerate sustainable mobility.

 

Key Points

Policy tradeoffs weighing biofuels and EVs to cut GHGs, boost energy security, and advance clean transportation.

✅ Near-term blending cuts emissions from existing fleets

✅ EVs scale with a cleaner grid and charging buildout

✅ Lifecycle impacts and costs guide optimal subsidy mix

 

California is at the forefront of the transition to a greener economy, driven by its ambitious goals to reduce greenhouse gas emissions and combat climate change. As part of its strategy, the state is grappling with the question of whether it should subsidize out-of-state biofuels or in-state electric vehicles (EVs) to meet these goals. Both options come with their own sets of benefits and challenges, and the decision carries significant implications for the state’s environmental, economic, and energy landscapes.

The Case for Biofuels

Biofuels have long been promoted as a cleaner alternative to traditional fossil fuels like gasoline and diesel. They are made from organic materials such as agricultural crops, algae, and waste, which means they can potentially reduce carbon emissions in comparison to petroleum-based fuels. In the context of California, biofuels—particularly ethanol and biodiesel—are viewed as a way to decarbonize the transportation sector, which is one of the state’s largest sources of greenhouse gas emissions.

Subsidizing out-of-state biofuels can help California reduce its reliance on imported oil while promoting the development of biofuel industries in other states. This approach may have immediate benefits, as biofuels are widely available and can be blended with conventional fuels to lower carbon emissions right away. It also allows the state to diversify its energy sources, improving energy security by reducing dependency on oil imports.

Moreover, biofuels can be produced in many regions across the United States, including rural areas. By subsidizing out-of-state biofuels, California could foster economic development in these regions, creating jobs and stimulating agricultural innovation. This approach could also support farmers who grow the feedstock for biofuel production, boosting the agricultural economy in the U.S.

However, there are drawbacks. The environmental benefits of biofuels are often debated. Critics argue that the production of biofuels—particularly those made from food crops like corn—can contribute to deforestation, water pollution, and increased food prices. Additionally, biofuels are not a silver bullet in the fight against climate change, as their production and combustion still release greenhouse gases. When considering whether to subsidize biofuels, California must also account for the full lifecycle emissions associated with their production and use.

The Case for Electric Vehicles

In contrast to biofuels, electric vehicles (EVs) offer a more direct pathway to reducing emissions from transportation. EVs are powered by electricity, and when coupled with renewable energy sources like solar or wind power, they can provide a nearly zero-emission solution for personal and commercial transportation. California has already invested heavily in EV infrastructure, including expanding its network of charging stations and exploring how EVs can support grid stability through vehicle-to-grid approaches, and offering incentives for consumers to purchase EVs.

Subsidizing in-state EVs could stimulate job creation and innovation within California's thriving clean-tech industry, with other states such as New Mexico projecting substantial economic gains from transportation electrification, and the state has already become a hub for electric vehicle manufacturers, including Tesla, Rivian, and several battery manufacturers. Supporting the EV industry could further strengthen California’s position as a global leader in green technology, attracting investment and fostering growth in related sectors such as battery manufacturing, renewable energy, and smart grid technology.

Additionally, the environmental benefits of EVs are substantial. As the electric grid becomes cleaner with an increasing share of renewable energy, EVs will become even greener, with lower lifecycle emissions than biofuels. By prioritizing EVs, California could further reduce its carbon footprint while also achieving its long-term climate goals, including reaching carbon neutrality by 2045.

However, there are challenges. EV adoption in California remains a significant undertaking, requiring major investments in infrastructure as they challenge state power grids in the near term, technology, and consumer incentives. The cost of EVs, although decreasing, still remains a barrier for many consumers. Additionally, there are concerns about the environmental impact of lithium mining, which is essential for EV batteries. While renewable energy is expanding, California’s grid is still reliant on fossil fuels to some degree, and in other jurisdictions such as Canada's 2019 electricity mix fossil generation remains significant, meaning that the full emissions benefit of EVs is not realized until the grid is entirely powered by clean energy.

A Balancing Act

The debate between subsidizing out-of-state biofuels and in-state electric vehicles is ultimately a question of how best to allocate California’s resources to meet its climate and economic goals. Biofuels may offer a quicker fix for reducing emissions from existing vehicles, but their long-term benefits are more limited compared to the transformative potential of electric vehicles, even as some analysts warn of policy pitfalls that could complicate the transition.

However, biofuels still have a role to play in decarbonizing hard-to-abate sectors like aviation and heavy-duty transportation, where electrification may not be as feasible in the near future. Thus, a mixed strategy that includes both subsidies for EVs and biofuels may be the most effective approach.

Ultimately, California’s decision will likely depend on a combination of factors, including technological advancements, 2021 electricity lessons, and the pace of renewable energy deployment, and the state’s ability to balance short-term needs with long-term environmental goals. The road ahead is not easy, but California's leadership in clean energy will be crucial in shaping the nation’s response to climate change.

 

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