Why daylight saving time is bad for the environment

By Toronto Star


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What if fighting climate change was as easy as not setting your clock forward?

Always sold as a conservation measure, the practice of daylight savings actually jacked electricity use in homes across one central U.S. state by up to four per cent, according to a new American study.

"If you could actually get energy savings and decrease carbon dioxide emissions just by adjusting the clock, that's certainly something we should at least consider," says Matthew Kotchen, a University of California-Santa Barbara economics professor who, together with a graduate student, combed over almost 8 million residential meter readings across Indiana to quantify the change in electricity use over three years.

The state offered a perfect case study: Up until 2006, only a handful of its counties pushed their clocks around at all. The vast majority, mostly rural farm communities where daily routines are still largely dictated by sunrise and not an electric clock, stuck stubbornly to standard time year-round. Then, two years ago, the entire state standardized their clocks and joined the daylight savings movement. That provided both a bulk of data and a control group.

The results? Instead of saving electricity and money by adding an extra hour of sunlight to evenings most of the year, it cost Indiana homes an extra $8.6 million in electricity bills – mostly from chugging air conditioners – each year. And since 95 per cent of that extra energy was generated by coal-fired power plants, that meant much more atmosphere-warming carbon dioxide was spewed into the air.

Expanded nationally, those results would translate to at least two coal-fired electricity plants pumping power just to feed the daylight savings habit.

"In Indiana, I can tell you unambiguously now, there are social and environmental costs associated with daylight savings time because of the pollution emissions and carbon dioxide emissions contributing to climate change," Kotchen says.

The irony is that daylight savings has always been promoted as an energy conservation measure; theoretically, one extra hour of natural light in the evening would erase an hour of electrical light. In 2005, when the American Congress voted to extend daylight savings by four weeks, pushing the start date back three weeks to today, it was advertised as saving Americans the equivalent of 100,000 barrels of oil daily. Ontario decided to follow suit for trade reasons.

"If we're staking our national policy on conservation on daylight savings, we're in big trouble," says Jeff Deyette, an energy analyst with the Union of Concerned Scientists in the United States. "This was one of the few victories of the energy bill of 2005 that otherwise was entirely focused on increasing supply."

The American Congress has promised to review the extension of daylight savings after the U.S. Department of Energy does an audit of its effect. Those findings should be presented by June, says department spokesperson Chris Kielich.

"If daylight saving time doesn't save energy, it's hard to find a cogent reason to continue the experiment," says Ralph Cavanagh, energy program co-director of the Natural Resources Defense Council.

Since first conceived of by Benjamin Franklin more than two centuries ago, the principle behind daylight savings has always been to save on lighting bills. But what the American inventor couldn't envision in 1784 was the rise of the power-sucking central air conditioner. In Indiana, people might not have been flipping on the lights when they returned home after work. But they were cranking their air conditioners, because that extra hour of evening sunlight meant another hour of "solar build-up on your house," says Kotchen.

"Take an hour at dawn versus an hour at sunset. When do you think you're going to run the air conditioner harder?"

Kotchen is now studying the effect of daylight savings on the rest of the country. He figures the air conditioning effect will be even more profound in southern states. And in the north, there is the opposite problem: waking up an hour earlier in the spring and fall means more time roaming around a cold house, rather than dozing under a duvet.

It likely has a similar effect in Ontario, where hot, humid summers are not unlike Indiana's, Kotchen says. On a hot summer day in Ontario, air conditioning can account for a quarter of our total electricity demand.

(A preliminary examination of the extended daylight savings hours last fall showed a very marginal reduction in electricity use – about 0.1 per cent, says Terry Young, spokesperson for the Independent Electricity System Operator, which manages Ontario's electrical system.)

Another way daylight savings might be fuelling our warming climate? Increased carbon dioxide fumes sputtering out of car tailpipes, says Michael Downing, author of Spring Forward: The Annual Madness of Daylight Saving Time. Last March's early spring forward coincided with increased gas prices at the pumps.

But the hikes had no effect on gas sales, a result dubbed by many analysts as the "daylight savings effect," he says.

"When you give people more light after work, they do go to the mall or ball park and they don't walk there. They get in their cars," says Downing, adding that in the 1930s, the petroleum industry lobbied hard to reintroduce daylight savings.

The practice was first introduced, temporarily, in the United States during World War I, and then again during World War II. In 1966, it was reintroduced across most of the United States and Canada, beginning the last Sunday in April and ending six months later in late October. Since then, it has been expanded twice.

While energy conservation has always been the window dressing, the true motivation was repeatedly economic, says Downing, who spent two years reading all the U.S. congressional and senate hearings on DST dating back to 1919.

"The most persistent lobby on behalf of daylight savings has long been retailers and merchants. If you give people more light when they leave work, they will stop and shop on their way home," says Downing, a writing professor at Tufts University.

"There is a reason we continue to get daylight savings under the rubric of energy conservation because as a policy, it costs individual consumers nothing and asks them to conserve nothing. So it's wildly popular," he says.

"Unfortunately, it's entirely ineffective."

Previous studies on daylight savings have had similar findings. But most have been based on simulation models, not concrete data. An exception was a study on the extension of daylight savings in two Australian territories for the 2000 Summer Olympic Games, which showed more electricity used.

But even that didn't dissuade the Australian government from introducing daylight savings to the western part of the country more than a year ago, says David Prerau, author of Seize the Daylight: The Curious and Contentious Story of Daylight Saving Time.

"Most people feel they are gaining an extra hour to do things in," says Prerau, adding other benefits include decreased traffic accidents, a more active population and a boost to the economy. "There's a lot of benefits that generally outweigh the negatives. Energy is just one of the impact areas."

A broader study would be needed to convince even Ontario's chief conservation officer, Peter Love, to include ending the practice in his campaigns to cut back Ontario's electricity usage. "Ontario, quite frankly, is not doing this for energy efficiency reasons," Love says. "We did it to be in sync with our major trading partner to the south," he says. "It's not something I'd want to do alone."

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LNG powered with electricity could be boon for B.C.'s independent power producers

B.C. LNG Electrification embeds clean hydro and wind power into low-emission liquefied natural gas, cutting carbon intensity, enabling coal displacement in Asia, and opening grid-scale demand for independent power producers and ITMO-based climate accounting.

 

Key Points

Powering LNG with clean electricity cuts carbon intensity, displaces coal, and grows demand for B.C.'s clean power.

✅ Electric-drive LNG cuts emissions intensity by up to 80%.

✅ Creates major grid load, boosting B.C. independent power producers.

✅ Enables ITMO crediting when coal displacement is verified.

 

B.C. has abundant clean power – if only there was a way to ship those electrons across the sea to help coal-dependent countries reduce their emissions, and even regionally, Alberta–B.C. grid link benefits could help move surplus power domestically.

Natural gas that is liquefied using clean hydro and wind power and then exported would be, in a sense, a way of embedding B.C.’s low emission electricity in another form of energy, and, alongside the Canada–Germany clean energy pact, part of a broader export strategy.

Given the increased demand that could come from an LNG industry – especially one that moves towards greater electrification and, as the IEA net-zero electricity report notes, broader system demand – poses some potentially big opportunities for B.C.’s clean energy independent power sector, as those attending the Clean Energy Association of BC's annual at the Generate conference heard recently.

At a session on LNG electrification, delegates were told that LNG produced in B.C. with electricity could have some significant environmental benefits.

Given how much power an LNG plant that uses electric drive consumes, an electrified LNG industry could also pose some significant opportunities for independent power producers – a sector that had the wind taken out of its sails with the sanctioning of the Site C dam project.

Only one LNG plant being built in B.C. – Woodfibre LNG – will use electric drive to produce LNG, although the companies behind Kitimat LNG have changed their original design plans, and now plan to use electric drive drive as well.

Even small LNG plants that use electric drive require a lot of power.

“We’re talking about a lot of power, since it’s one of the biggest consumers you can connect to a grid,” said Sven Demmig, head of project development for Siemens.

Most LNG plants still burn natural gas to drive the liquefaction process – a choice that intersects with climate policy and electricity grids in Canada. They typically generate 0.35 tonnes of CO2e per tonne of LNG produced.

Because it will use electric drive, LNG produced by Woodfibre LNG will have an emissions intensity that is 80% less than LNG produced in the Gulf of Mexico, said Woodfibre president David Keane.

In B.C., the benchmark for GHG intensities for LNG plants has been set at 0.16 tonnes of CO2e per tonne of LNG. Above that, LNG producers would need to pay higher carbon taxes than those that are below the benchmark.

The LNG Canada plant has an intensity of 0.15 tonnes og CO2e per tonne of LNG. Woodfibre LNG will have an emissions intensity of just 0.059, thanks to electric drive.

“So we will be significantly less than any operating facility in the world,” Keane said.

Keane said Sinopec has recently estimated that it expects China’s demand for natural gas to grow by 82% by 2030.

“So China will, in fact, get its gas supply,” Keane said. “The question is: where will that supply come from?

“For every tonne of LNG that’s being produced today in the United States -- and tonne of LNG that we’re not producing in Canada -- we’re seeing about 10 million tonnes of carbon leakage every single year.”

The first Canadian company to produce LNG that ended up in China is FortisBC. Small independent operators have been buying LNG from FortisBC’s Tilbury Island plant and shipping to China in ISO containers on container ships.

David Bennett, director of communications for FortisBC, said those shipments are traced to industries in China that are, indeed, using LNG instead of coal power now.

“We know where those shipping containers are going,” he said. “They’re actually going to displace coal in factories in China.”

Verifying what the LNG is used for is important, if Canadian producers want to claim any kind of climate credit. LNG shipped to Japan or South Korea to displace nuclear power, for example, would actually result in a net increase in GHGs. But used to displace coal, the emissions reductions can be significant, since natural gas produces about half the CO2 that coal does.

The problem for LNG producers here is B.C.’s emissions reduction targets as they stand today. Even LNG produced with electricity will produce some GHGs. The fact that LNG that could dramatically reduce GHGs in other countries, if it displaces coal power, does not count in B.C.’s carbon accounting.

Under the Paris Agreement, countries agree to set their own reduction targets, and, for Canada, cleaning up Canada’s electricity remains critical to meeting climate pledges, but don’t typically get to claim any reductions that might result outside their own country.

Canada is exploring the use of Internationally Transferred Mitigation Outcomes (ITMO) under the Under the Paris Agreement to allow Canada to claim some of the GHG reductions that result in other countries, like China, through the export of Canadian LNG.

“For example, if I were producing 4 million tonnes of greenhouse gas emissions in B.C. and I was selling 100% of my LNG to China, and I can verify that they’re replacing coal…they would have a reduction of about 60 or million tonnes of greenhouse gas emissions,” Keane said.

“So if they’re buying 4 million tonnes of emissions from us, under these ITMOs, then they have net reduction of 56 million tonnes, we’d have a net increase of zero.”

But even if China and Canada agreed to such a trading arrangement, the United Nations still hasn’t decided just how the rules around ITMOs will work.

 

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Chief Scientist: we need to transform our world into a sustainable ‘electric planet’

Hydrogen Energy Transition advances renewable energy integration via electrolysis, carbon capture and storage, and gas hybrids to decarbonize industry, steel, and transport, enable grid storage, replace ammonia feedstocks, and export clean power across continents.

 

Key Points

Scaling clean hydrogen with renewables and CCS to cut emissions in power and industry, and enable clean transport.

✅ Electrolysis and CCS provide low-emission hydrogen at scale.

✅ Balances renewables with storage and flexible gas assets.

✅ Decarbonizes steel, ammonia, heavy transport, and exports.

 

I want you to imagine a highway exclusively devoted to delivering the world’s energy. Each lane is restricted to trucks that carry one of the world’s seven large-scale sources of primary energy: coal, oil, natural gas, nuclear, hydro, solar and wind.

Our current energy security comes at a price, as Europe's power crisis shows, the carbon dioxide emissions from the trucks in the three busiest lanes: the ones for coal, oil and natural gas.

We can’t just put up roadblocks overnight to stop these trucks; they are carrying the overwhelming majority of the world’s energy supply.

But what if we expand clean electricity production carried by the trucks in the solar and wind lanes — three or four times over — into an economically efficient clean energy future?

Think electric cars instead of petrol cars. Think electric factories instead of oil-burning factories. Cleaner and cheaper to run. A technology-driven orderly transition. Problems wrought by technology, solved by technology.

Read more: How to transition from coal: 4 lessons for Australia from around the world

Make no mistake, this will be the biggest engineering challenge ever undertaken. The energy system is huge, and even with an internationally committed and focused effort the transition will take many decades.

It will also require respectful planning and retraining to ensure affected individuals and communities, who have fuelled our energy progress for generations, are supported throughout the transition.

As Tony, a worker from a Gippsland coal-fired power station, noted from the audience on this week’s Q+A program:

The workforce is highly innovative, we are up for the challenge, we will adapt to whatever is put in front of us and we have proven that in the past.

This is a reminder that if governments, industry, communities and individuals share a vision, a positive transition can be achieved.

The stunning technology advances I have witnessed in the past ten years, such as the UK's green industrial revolution shaping the next waves of reactors, make me optimistic.

Renewable energy is booming worldwide, and is now being delivered at a markedly lower cost than ever before.

In Australia, the cost of producing electricity from wind and solar is now around A$50 per megawatt-hour.

Even when the variability is firmed with grid-scale storage solutions, the price of solar and wind electricity is lower than existing gas-fired electricity generation and similar to new-build coal-fired electricity generation.

This has resulted in substantial solar and wind electricity uptake in Australia and, most importantly, projections of a 33% cut in emissions in the electricity sector by 2030, when compared to 2005 levels.

And this pricing trend will only continue, with a recent United Nations report noting that, in the last decade alone, the cost of solar electricity fell by 80%, and is set to drop even further.

So we’re on our way. We can do this. Time and again we have demonstrated that no challenge to humanity is beyond humanity.

Ultimately, we will need to complement solar and wind with a range of technologies such as high levels of storage, including gravity energy storage approaches, long-distance transmission, and much better efficiency in the way we use energy.

But while these technologies are being scaled up, we need an energy companion today that can react rapidly to changes in solar and wind output. An energy companion that is itself relatively low in emissions, and that only operates when needed.

In the short term, as Prime Minister Scott Morrison and energy minister Angus Taylor have previously stated, natural gas will play that critical role.

In fact, natural gas is already making it possible for nations to transition to a reliable, and relatively low-emissions, electricity supply.

Look at Britain, where coal-fired electricity generation has plummeted from 75% in 1990 to just 2% in 2019.

Driving this has been an increase in solar, wind, and hydro electricity, up from 2% to 27%. At the same time, and this is key to the delivery of a reliable electricity supply, electricity from natural gas increased from virtually zero in 1990 to more than 38% in 2019.

I am aware that building new natural gas generators may be seen as problematic, but for now let’s assume that with solar, wind and natural gas, we will achieve a reliable, low-emissions electricity supply.

Is this enough? Not really.

We still need a high-density source of transportable fuel for long-distance, heavy-duty trucks.

We still need an alternative chemical feedstock to make the ammonia used to produce fertilisers.

We still need a means to carry clean energy from one continent to another.

Enter the hero: hydrogen.


Hydrogen could fill the gaps in our energy needs. Julian Smith/AAP Image
Hydrogen is abundant. In fact, it’s the most abundant element in the Universe. The only problem is that there is nowhere on Earth that you can drill a well and find hydrogen gas.

Don’t panic. Fortunately, hydrogen is bound up in other substances. One we all know: water, the H in H₂O.

We have two viable ways to extract hydrogen, with near-zero emissions.

First, we can split water in a process called electrolysis, using renewable electricity or heat and power from nuclear beyond electricity options.

Second, we can use coal and natural gas to split the water, and capture and permanently bury the carbon dioxide emitted along the way.

I know some may be sceptical, because carbon capture and permanent storage has not been commercially viable in the electricity generation industry.

But the process for hydrogen production is significantly more cost-effective, for two crucial reasons.

First, since carbon dioxide is left behind as a residual part of the hydrogen production process, there is no additional step, and little added cost, for its extraction.

And second, because the process operates at much higher pressure, the extraction of the carbon dioxide is more energy-efficient and it is easier to store.

Returning to the electrolysis production route, we must also recognise that if hydrogen is produced exclusively from solar and wind electricity, we will exacerbate the load on the renewable lanes of our energy highway.

Think for a moment of the vast amounts of steel, aluminium and concrete needed to support, build and service solar and wind structures. And the copper and rare earth metals needed for the wires and motors. And the lithium, nickel, cobalt, manganese and other battery materials needed to stabilise the system.

It would be prudent, therefore, to safeguard against any potential resource limitations with another energy source.

Well, by producing hydrogen from natural gas or coal, using carbon capture and permanent storage, we can add back two more lanes to our energy highway, ensuring we have four primary energy sources to meet the needs of the future: solar, wind, hydrogen from natural gas, and hydrogen from coal.

Read more: 145 years after Jules Verne dreamed up a hydrogen future, it has arrived

Furthermore, once extracted, hydrogen provides unique solutions to the remaining challenges we face in our future electric planet.

First, in the transport sector, Australia’s largest end-user of energy.

Because hydrogen fuel carries much more energy than the equivalent weight of batteries, it provides a viable, longer-range alternative for powering long-haul buses, B-double trucks, trains that travel from mines in central Australia to coastal ports, and ships that carry passengers and goods around the world.

Second, in industry, where hydrogen can help solve some of the largest emissions challenges.

Take steel manufacturing. In today’s world, the use of coal in steel manufacturing is responsible for a staggering 7% of carbon dioxide emissions.

Persisting with this form of steel production will result in this percentage growing frustratingly higher as we make progress decarbonising other sectors of the economy.

Fortunately, clean hydrogen can not only provide the energy that is needed to heat the blast furnaces, it can also replace the carbon in coal used to reduce iron oxide to the pure iron from which steel is made. And with hydrogen as the reducing agent the only byproduct is water vapour.

This would have a revolutionary impact on cutting global emissions.

Third, hydrogen can store energy, as with power-to-gas in pipelines solutions not only for a rainy day, but also to ship sunshine from our shores, where it is abundant, to countries where it is needed.

Let me illustrate this point. In December last year, I was privileged to witness the launch of the world’s first liquefied hydrogen carrier ship in Japan.

As the vessel slipped into the water I saw it not only as the launch of the first ship of its type to ever be built, but as the launch of a new era in which clean energy will be routinely transported between the continents. Shipping sunshine.

And, finally, because hydrogen operates in a similar way to natural gas, our natural gas generators can be reconfigured in the future as hydrogen-ready power plants that run on hydrogen — neatly turning a potential legacy into an added bonus.

Hydrogen-powered economy
We truly are at the dawn of a new, thriving industry.

There’s a nearly A$2 trillion global market for hydrogen come 2050, assuming that we can drive the price of producing hydrogen to substantially lower than A$2 per kilogram.

In Australia, we’ve got the available land, the natural resources, the technology smarts, the global networks, and the industry expertise.

And we now have the commitment, with the National Hydrogen Strategy unanimously adopted at a meeting by the Commonwealth, state and territory governments late last year.

Indeed, as I reflect upon my term as Chief Scientist, in this my last year, chairing the development of this strategy has been one of my proudest achievements.

The full results will not be seen overnight, but it has sown the seeds, and if we continue to tend to them, they will grow into a whole new realm of practical applications and unimagined possibilities.

 

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Mines found at Ukraine's Zaporizhzhia nuclear plant, UN watchdog says

Zaporizhzhia Nuclear Plant Mines reported by IAEA at the Russian-occupied site: anti-personnel devices in a buffer zone, restricted areas; access limits to reactor rooftops and turbine halls heighten nuclear safety and security concerns in Ukraine.

 

Key Points

IAEA reports anti-personnel mines at Russian-held Zaporizhzhia, raising nuclear safety risks in buffer zones.

✅ IAEA observes mines in buffer zone at occupied site

✅ Restricted areas; no roof or turbine hall access granted

✅ Safety systems unaffected, but staff under pressure

 

The United Nations atomic watchdog said it saw anti-personnel mines at the site of Ukraine's Zaporizhzhia nuclear power plant which is occupied by Russian forces.

Europe's largest nuclear facility fell to Russian forces shortly after the invasion of Ukraine in February last year, as Moscow later sought to build power lines to reactivate it amid ongoing control of the area. Kyiv and Moscow have since accused each other of planning an incident at the site.

On July 23 International Atomic Energy Agency (IAEA) experts "saw some mines located in a buffer zone between the site's internal and external perimeter barriers," agency chief Rafael Grossi said in a statement on Monday.

The statement did not say how many mines the team had seen.

The devices were in "restricted areas" that operating plant personnel cannot access, Mr Grossi said, adding the IAEA's initial assessment was that any detonation "should not affect the site's nuclear safety and security systems".

Laying explosives at the site was "inconsistent with the IAEA safety standards and nuclear security guidance" and, amid controversial proposals on Ukraine's nuclear plants that have circulated internationally, created additional psychological pressure on staff, he added.

Ukrainians in Nikopol are out of water and within Russia's firing line. But Zaporizhzhia nuclear power plant could pose the biggest threat, even as Ukraine has resumed electricity exports to regional grids.

Last week the IAEA said its experts had carried out inspections at the plant, without "observing" the presence of any mines, although they had not been given access to the rooftops of the reactor buildings, while a possible agreement to curb attacks on plants was being discussed.

The IAEA had still not been given access to the roofs of the reactor buildings and their turbine halls, its latest statement said, even as a proposal to control Ukraine's nuclear plants drew scrutiny.

After falling into Russian hands, Europe's biggest power plant was targeted by gunfire and has been severed from the grid several times, raising nuclear risk warnings from the IAEA and others.

The six reactor units, which before the war produced around a fifth of Ukraine's electricity, have been shut down for months, prompting interest in wind power development as a harder-to-disrupt source.

 

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Trump Tariff Threat Delays Quebec's Green Energy Bill

Quebec Energy Bill Tariff Delay disrupts Canada-U.S. trade, renewable energy investment, hydroelectric expansion, and clean technology projects, as Trump tariffs on aluminum and steel raise costs, threatening climate targets and green infrastructure timelines.

 

Key Points

A policy pause in Quebec from U.S. tariff threats, disrupting clean investment, hydro expansion, and climate targets.

✅ Tariff risk inflates aluminum and steel project costs.

✅ Quebec delays clean energy legislation amid trade uncertainty.

✅ Hydroelectric reliance complicates emissions reduction timelines.

 

The Trump administration's tariff threat has had a significant impact on Quebec's energy sector, with tariff threats boosting support for projects even as the uncertainty resulted in the delay of a critical energy bill. Originally introduced to streamline energy development and tackle climate change, the bill was meant to help transition Quebec towards greener alternatives while fostering economic growth. However, the U.S. threat to impose tariffs on Canadian goods, including energy products, introduced a wave of uncertainty that led to a pause in the bill's legislative process.

Quebec’s energy bill had ambitious goals of transitioning to renewable sources like wind, solar, and hydroelectric power. It sought to support investments in clean technologies and the expansion of the province's clean energy infrastructure, as the U.S. demand for Canadian green power continues to grow across the border. Moreover, it emphasized the reduction of carbon emissions, an important step towards meeting Quebec's climate targets. At its core, the bill aimed to position the province as a leader in green energy development in Canada and globally.

The interruption caused by President Donald Trump's tariff rhetoric has, however, cast a shadow over the legislation. Tariffs, if enacted, would disproportionately affect Canada's energy exports, with electricity exports at risk under growing tensions, particularly in sectors like aluminum and steel, which are integral to energy infrastructure development. These tariffs could increase the cost of energy-related projects, thereby hindering Quebec's ability to achieve its renewable energy goals and reduce carbon emissions in a timely manner.

The tariff threat was seen as a part of the broader trade tensions between the U.S. and Canada, a continuation of the trade war that had escalated under Trump’s presidency. In this context, the Quebec government was forced to reconsider its legislative priorities, with policymakers citing concerns over the potential long-term consequences on the energy industry, as leaders elsewhere threatened to cut U.S.-bound electricity to exert leverage. With the uncertainty around tariffs and trade relations, the government opted to delay the bill until the geopolitical situation stabilized.

This delay underscores the vulnerability of Quebec’s energy agenda to external pressures. While the provincial government had set its sights on an ambitious green energy future, it now faces significant challenges in ensuring that its projects remain economically viable under the cloud of potential tariffs, even as experts warn against curbing Quebec's exports during the dispute. The delay in the energy bill also reflects broader challenges faced by the Canadian energy sector, which is highly integrated with the U.S. market.

The situation is further complicated by the province's reliance on hydroelectric power, a cornerstone of its energy strategy that supplies markets like New York, where tariffs could spike New York energy prices if cross-border flows are disrupted. While hydroelectric power is a clean and renewable source of energy, there are concerns about the environmental impact of large-scale dams, and these concerns have been growing in recent years. The tariff threat may prompt a reevaluation of Quebec’s energy mix and force the government to balance its environmental goals with economic realities.

The potential imposition of tariffs also raises questions about the future of North American energy cooperation. Historically, Canada and the U.S. have enjoyed a symbiotic energy relationship, with significant energy trade flowing across the border. The energy bill in Quebec was designed with the understanding that cross-border energy trade would continue to thrive. The Trump administration's tariff threat, however, casts doubt on this stability, forcing Quebec lawmakers to reconsider how they proceed with energy policy in a more uncertain trade environment.

Looking forward, Quebec's energy sector will likely need to adjust its strategies to account for the possibility of tariffs, while still pushing for a sustainable energy future, especially if Biden outlook for Canada's energy proves more favorable for the sector in the medium term. It may also open the door for deeper discussions about diversification, both in terms of energy sources and trade partnerships, as Quebec seeks to mitigate the impact of external threats. The delay in the energy bill, though unfortunate, may serve as a wake-up call for Canadian lawmakers to rethink how they balance environmental goals with global trade realities.

Ultimately, the Trump tariff threat highlights the delicate balance between regional energy ambitions and international trade dynamics. For Quebec, the delay in the energy bill could prove to be a pivotal moment in shaping the future of its energy policy.

 

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Wind Leading Power

UK Wind Power Surpasses Gas as offshore wind and solar drive record electricity generation, National Grid milestones, and net zero progress, despite grid capacity bottlenecks, onshore planning reforms, demand from heat pumps and transport electrification.

 

Key Points

A milestone where wind turbines generated more UK electricity than gas, advancing progress toward a net zero grid.

✅ Offshore wind delivered the majority of UK wind generation

✅ Grid connection delays stall billions in green projects

✅ Planning reforms may restart onshore wind development

 

Wind turbines have generated more electricity than gas, as wind becomes the main source for the first time in the UK.

In the first three months of this year a third of the country's electricity came from wind farms, as the UK set a wind generation record that underscored the trend, research from Imperial College London has shown.

National Grid has also confirmed that April saw a record period of solar energy generation, and wind and solar outproduced nuclear in earlier milestones.

By 2035 the UK aims for all of its electricity to have net zero emissions, after a 2019 stall in low-carbon generation highlighted the challenge.

"There are still many hurdles to reaching a completely fossil fuel-free grid, but wind out-supplying gas for the first time is a genuine milestone event," said Iain Staffell, energy researcher at Imperial College and lead author of the report.

The research was commissioned by Drax Electrical Insights, which is funded by Drax energy company.

The majority of the UK's wind power has come from offshore wind farms, and the country leads the G20 for wind's electricity share according to recent analyses. Installing new onshore wind turbines has effectively been banned since 2015 in England.

Under current planning rules, companies can only apply to build onshore wind turbines on land specifically identified for development in the land-use plans drawn up by local councils. Prime Minister Rishi Sunak agreed in December to relax these planning restrictions to speed up development.

Scientists say switching to renewable power is crucial to curb the impacts of climate change, which are already being felt, including in the UK, which last year recorded its hottest year since records began.

Solar and wind have seen significant growth in the UK, with wind surpassing coal in 2016 as a milestone. In the first quarter of 2023, 42% of the UK's electricity came from renewable energy, with 33% coming from fossil fuels like gas and coal.

But BBC research revealed on Thursday that billions of pounds' worth of green energy projects are stuck on hold due to delays with getting connections to the grid, as peak power prices also climbed amid system pressures.

Some new solar and wind sites are waiting up to 10 to 15 years to be connected because of a lack of capacity in the electricity system.

And electricity only accounts for 18% of the UK's total power needs. There are many demands for energy which electricity is not meeting, such as heating our homes, manufacturing and transport.

Currently the majority of UK homes use gas for their heating - the government is seeking to move households away from gas boilers and on to heat pumps which use electricity.

 

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Minnesota Power energizes Great Northern Transmission Line

Great Northern Transmission Line delivers 250 MW of carbon-free hydropower from Manitoba Hydro, strengthening Midwest grid reliability, enabling wind storage balancing, and advancing Minnesota Power's EnergyForward strategy for cleaner, renewable energy across the region.

 

Key Points

A 500 kV cross-border line delivering 250 MW of carbon-free hydropower, strengthening reliability and enabling renewables.

✅ 500 kV, 224-mile line from Manitoba to Minnesota

✅ Delivers 250 MW hydropower via ALLETE-Minnesota Power

✅ Enables wind storage and grid balancing with Manitoba Hydro

 

Minnesota Power, a utility division of ALLETE Inc. (NYSE:ALE), has energized its Great Northern Transmission Line, bringing online an innovative delivery and storage system for renewable energy that spans two states and one Canadian province, similar to the Maritime Link project in Atlantic Canada.

The 500 kV line is now delivering 250 megawatts of carbon-free hydropower from Manitoba, Canada, to Minnesota Power customers.

Minnesota Power completed the Great Northern Transmission Line (GNTL) in February 2020, ahead of schedule and under budget. The 224-mile line runs from the Canadian border in Roseau County to a substation near Grand Rapids, Minnesota. It consists of 800 tower structures which were fabricated in the United States and used 10,000 tons of North American steel. About 2,200 miles of wire were required to install the line's conductors. The GNTL also is contributing significant property tax revenue to local communities along the route.

"This is such an incredible achievement for Minnesota Power, ALLETE, and our region, and is the culmination of a decade-long vision brought to life by our talented and dedicated employees," said ALLETE President and CEO Bethany Owen. "The GNTL will help Minnesota Power to provide our customers with 50 percent renewable energy less than a year from now. As part of our EnergyForward strategy, it also strengthens the grid across the Midwest and in Canada, enhancing reliability for all of our customers."

With the GNTL energized and connected to Manitoba Hydro's recently completed Manitoba-Minnesota Transmission Project at the border, the companies now have a unique "wind storage" mechanism that quickly balances energy supply and demand in Minnesota and Manitoba, and enables a larger role for renewables in the North American energy grid.

The GNTL and its delivery of carbon-free hydropower are important components of Minnesota Power's EnergyForward strategy to transition away from coal and add renewable power sources while maintaining reliable and affordable service for customers, echoing interties like the Maritime Link that facilitate regional power flows. It also is part of a broader ALLETE strategy to advance and invest in critical regional transmission and distribution infrastructure, such as the TransWest Express transmission project, to ensure grid integrity and enable cleaner energy to reduce carbon emissions.

"The seed for this renewable energy initiative was planted in 2008 when Minnesota Power proposed purchasing 250 megawatts of hydropower from Manitoba Hydro. Beyond the transmission line, it also included a creative asset swap to move wind power from North Dakota to Minnesota, innovative power purchase agreements, and a remarkable advocacy process to find an acceptable route for the GNTL," said ALLETE Executive Chairman Al Hodnik. "It marries wind and water in a unique connection that will help transform the energy landscape of North America and reduce carbon emissions related to the existential threat of climate change."

Minnesota Power and Manitoba Hydro, a provincial Crown Corporation, coordinated on the project from the beginning, navigating National Energy Board reviews along the way. It is based on the companies' shared values of integrity, environmental stewardship and community engagement.

"The completion of Minnesota Power's Great Northern Transmission Line and our Manitoba-Minnesota Transmission Project is a testament to the creativity, perseverance, cooperation and skills of hundreds of people over so many years on both sides of the border," said Jay Grewal, president and CEO of Manitoba Hydro. "Perhaps even more importantly, it is a testament to the wonderful, longstanding relationship between our two companies and two countries. It shows just how much we can accomplish when we all work together toward a common goal."

Minnesota Power engaged federal, state and local agencies; the sovereign Red Lake Nation and other tribes, reflecting First Nations involvement in major transmission planning; and landowners along the proposed routes beginning in 2012. Through 75 voluntary meetings and other outreach forums, a preferred route was selected with strong support from stakeholders that was approved by the Minnesota Public Utilities Commission in April 2016.

A four-year state and federal regulatory process culminated in late 2016 when the federal Department of Energy approved a Presidential Permit for the GNTL, similar to the New England Clean Power Link process, needed because of the international border crossing. Construction of the line began in early 2017.

"A robust stakeholder process is essential to the success of any project, but especially when building a project of this scope," Owen said. "We appreciated the early engagement and support from stakeholders, local communities and tribes, agencies and regulators through the many approval milestones to the completion of the GNTL."

 

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