Will electric cars survive?

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Lowell Leifso hasn't filled up at a gas station once since he bought a sparkling grey Toyota RAV4 earlier this year.

He hasn't needed to.

His commuter vehicle would look like any of the other popular Toyota crossovers on the road, if it weren't for the bright "electric vehicle" decals stuck to it.

"It's quite an attention grabber," Leifso admits. "People ask questions like, 'Did you build it? Where can I get one?'"

Leifso's 2003 model was among the last of the plug-in electric vehicles Toyota retailed in California before shutting down its line.

It's proven its worth to Leifso already.

Although acceleration is noticeably sluggish, the car can zip down the highway at 130 km/h.

And with a range of about 160 km, it costs about $2 to "fill up" when he charges up the RAV4 at home through a paddle that slips in under the front grill.

That's about one-fifth of the cost of filling up a regular gas-powered RAV4, Leifso says.

And as gas prices head north of $1 per litre and car companies continue their public struggle to survive, the interest in alternative fuel technologies is only spiking.

Today, most major manufacturers have rushed to promise electric vehicles for the market within years. Canadian auto-parts magnate Frank Stronach wants to mass-produce electric cars within three years.

But what are the chances of the technology succeeding? Is the idea that electric vehicles will be widespread in just a few years merely a pipe dream?

"It's never been more serious," says auto industry analyst Dennis DesRosiers, of manufacturers' renewed interest in electric vehicles. "They're investing billions into developing the technology."

But still, DesRosiers doesn't believe there will be wide acceptance of the technology any time soon.

"Electric vehicles' ability to get into the mainstream is probably at least a decade, if not two decades, out into the future," he says. "It's just that daunting a technological challenge."

He points to the popularity of hybrid vehicles, which have been readily available for several years now.

Out of 1.6 million new vehicles sold in Canada last year, he says, only 25,000 were hybrids.

There are significant barriers to widespread acceptance as well as a wide range of other alternative technologies from biodiesel and ethanol to solar and hydrogen power.

"Promoters of electric vehicles tend to isolate themselves, that they are the only competing technology to gas. There are actually 10 or 12 different technologies."

Some manufacturers, too, are casting a wide net.

"We have not backed any particular solution," says Honda Canada executive vice-president Jerry Chenkin, who calls his company's strategy a "portfolio approach."

"We are recognizing the fact that nobody knows which solution will be the best in the end. The key for us is to invest in several different alternative solutions."

Proponents of electrical vehicles, however, see the technology only growing.

"It is where cell phones were in 1985," says John Stonier, of the Vancouver Electric Vehicle Association.

"The cell phone in 1985 was a brick. It had a huge battery and there was very little production. The electric car industry is at the exact same point."

Even with today's technology, Stonier argues, electric vehicles would be fine for most consumers, getting them from point A to B and back in time for a charge-up.

"People's needs are actually a lot less than they think. If you look at the statistics, only one per cent of trips made with a car are above 100 miles long."

Government policy has to keep up with investments to stimulate the industry, as well as supports for the infrastructure needed to support electric vehicles, Stonier says.

Behind the scenes, steps are being taken to streamline market acceptance for EVs. Developer Concord Pacific, for example, recently announced it would build a condominium project in Vancouver with a parkade equipped to handle EV charging needs.

But provincial and federal authorities are still trying to predict exactly what kind of infrastructure will be needed to handle widespread EV acceptance.

BC Hydro, for example, is part of a provincial working group studying the demands plug-in EVs may have on infrastructure.

"We've been monitoring it," says spokesperson Dag Sharman. "The amount of electricity they would use is something we simply don't know because we don't know how many electric vehicles there would be."

A federal working group is tackling similar issues. The federally coordinated Canadian Electric Vehicle Technology Roadmap, or evTRM, is composed of industry players and is set to submit its recommendations to Ottawa.

However, initial projections for electric vehicles in Canada are modest.

By 2018, the group is envisioning 500,000 highway-capable plug-in EVs on the road, a number that adds up to about 15 per cent of new vehicles sold in Canada over the next decade, the group says.

It's not an earth-shattering number, admits Mike Elwood, chair of evTRM's steering committee.

"It's enough to get the ball rolling," says Elwood, vice-president of marketing at Azure Dynamics, a player in electric drive technology for commercial vehicles.

"Even though I personally would like to see it at 100 per cent, I know that's probably not attainable."

But although he admits the figure is conservative compared to the paradigm shift many observers see as necessary for the auto industry, it's still a daunting leap from today, he says.

"We don't have time to waste. We don't have time to sit there and say, well, in 10 years, maybe things will be different," Elwood said.

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Canada Extends Net-Zero Target to 2050

Canada Clean Electricity Regulations 2050 balance net-zero goals with grid reliability and affordability, setting emissions caps, enabling offset credits, and flexible provincial pathways, including support for non-grid facilities during the clean energy transition.

 

Key Points

A federal plan for a net-zero grid by 2050 with emissions caps, offsets, and flexible provincial compliance.

✅ Emissions cap targeting 181 Mt CO2 from the power sector by 2050

✅ Offset credits and annual limits enable compliance flexibility

✅ Support for remote, non-grid facilities and regional pathways

 

In December 2024, the Government of Canada announced a significant policy shift regarding its clean electricity objectives. The initial target to achieve a net-zero electricity grid by 2035 has been extended to 2050. This decision reflects the government's response to feedback from provinces and energy industry stakeholders, who expressed concerns about the feasibility of meeting the 2035 deadline.

Revised Clean Electricity Regulations

The newly finalized Clean Electricity Regulations (CER) outline the framework for Canada's transition to a net-zero electricity grid by 2050, advancing the goal of 100 per cent clean electricity nationwide.

  • Emissions Reduction Targets: The regulations set a cap on emissions from the electricity sector, targeting a reduction of 181 megatonnes of CO₂ by 2050. This is a decrease from the previous goal of 342 megatonnes, reflecting a more gradual approach to emissions reduction.

  • Flexibility Mechanisms: To accommodate the diverse energy landscapes across provinces, the CER introduces flexibility measures. These include annual emissions limits and the option to use offset credits, allowing provinces to tailor their strategies while adhering to national objectives.

  • Support for Non-Grid Connected Facilities: Recognizing the unique challenges of remote and off-grid communities, the regulations provide accommodations for certain non-grid connected facilities, ensuring that all regions can contribute to the national clean electricity goals.

Implications for Canada's Energy Landscape

The extension of the net-zero electricity target to 2050 signifies a strategic recalibration of Canada's energy policy. This adjustment acknowledges the complexities involved in transitioning to a clean energy future, including:

  • Grid Modernization: Upgrading the electrical grid to accommodate renewable energy sources and ensure reliability is a critical component of the transition, especially as Ontario's EV wave accelerates across the province.

  • Economic Considerations: Balancing environmental objectives with economic impacts is essential. The government aims to create over 400,000 clean energy jobs, fostering economic growth while reducing emissions, supported by ambitious EV goals in the transport sector.

  • Regional Variations: Provinces have diverse energy profiles and resources, and British Columbia's power supply challenges highlight planning constraints. The CER's flexibility mechanisms are designed to accommodate these differences, allowing for tailored approaches that respect regional contexts.

Public and Industry Reactions

The policy shift has elicited varied responses:

  • Environmental Advocates: Some environmental groups express concern that the extended timeline may delay critical climate action, while debates over Quebec's push for EV dominance underscore policy trade-offs. They emphasize the need for more ambitious targets to address the escalating impacts of climate change.

  • Industry Stakeholders: The energy sector generally welcomes the extended timeline, viewing it as a pragmatic approach that allows for a more measured transition, particularly amid criticism of the 2035 EV mandate in transportation policy. The flexibility provisions are particularly appreciated, as they provide the necessary leeway to adapt to evolving market and technological conditions.

Looking Forward

As Canada moves forward with the implementation of the Clean Electricity Regulations, the focus will be on:

  • Monitoring Progress: Establishing robust mechanisms to track emissions reductions and ensure compliance with the new targets.

  • Stakeholder Engagement: Continuing dialogue with provinces, industry, and communities to refine strategies and address emerging challenges, including coordination on EV sales regulations as complementary measures.

  • Innovation and Investment: Encouraging the development and deployment of clean energy technologies through incentives and support programs.

The extension of Canada's net-zero electricity target to 2050 represents a strategic adjustment aimed at achieving a balance between environmental goals and practical implementation considerations. The Clean Electricity Regulations provide a framework that accommodates regional differences and industry concerns, setting the stage for a sustainable and economically viable energy future.

 

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Starved of electricity, Lebanon picks Dubai's ENOC to swap Iraqi fuel

Lebanon-ENOC Fuel Swap secures Iraqi high sulphur fuel oil, Grade B fuel oil, and gasoil via tender, easing electricity generation shortfalls, diesel shortages, and grid outages amid Lebanon's energy crisis and power sector emergency.

 

Key Points

A tender-based exchange trading Iraqi HSFO for cleaner fuel oil and gasoil to stabilize Lebanon's electricity generation.

✅ Swaps 84,000t Iraqi HSFO for 30,000t Grade B fuel oil and 33,000t gasoil

✅ Supports state electricity generation during acute power shortages

✅ Tender won by ENOC under Lebanon-Iraq goods-for-fuel deal

 

Lebanon's energy ministry said it had picked Dubai's ENOC in a tender to swap 84,000 tonnes of Iraqi high sulphur fuel oil, as LNG export authorizations expand globally, with 30,000 tonnes of Grade B fuel oil and 33,000 tonnes of gasoil.

ENOC won the tender, part of a deal between the two countries that allows the cash-strapped Lebanese government, even as electricity tensions persist, to pay for 1 million tonnes of Iraqi heavy fuel oil a year in goods and services.

As Lebanon suffers what the World Bank has described as one of the deepest depressions of modern history, shortages of fuel this month have meant state-powered electricity, alongside ongoing electricity sector reform, has been available for barely a few hours a day if at all.

Residents turning to private generators for their power supply face diesel shortages, even as other countries roll out measures to secure electricity supplies to mitigate risks.

The swap tenders are essential as Iraqi fuel is unsuitable for Lebanese electricity generation, and regional projects like the Jordan-Saudi electricity linkage underscore broader grid strategies.

Lebanese caretaker Energy Minister Raymond Ghajar said in July the fuel from the Iraqi deal would be used for electricity generation by the state provider, even as France advances a new electricity pricing scheme in Europe, and was enough for around four months.

ENOC is set to receive the Iraq fuel between Sept. 3-5 and will deliver it to Lebanon two weeks after, the energy ministry said, following a recent deal on electricity prices abroad that could influence markets.

 

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U.S. Announces $28 Million To Advance And Deploy Hydropower Technology

DOE Hydropower Funding advances clean energy R&D, pumped storage hydropower, retrofits for non-powered dams, and fleet modernization under the Bipartisan Infrastructure Law and Inflation Reduction Act, boosting long-duration energy storage, licensing studies, and sustainability engagement.

 

Key Points

A $28M DOE initiative supporting hydropower R&D, pumped storage, retrofits, and stakeholder sustainability efforts.

✅ Funds retrofits for non-powered dams, expanding low-impact supply

✅ Backs studies to license new pumped storage facilities

✅ Engages stakeholders on modernization and environmental impacts

 

The U.S. Department of Energy (DOE) today announced more than $28 million across three funding opportunities to support research and development projects that will advance and preserve hydropower as a critical source of clean energy. Funded through President Biden’s Bipartisan Infrastructure Law, this funding will support the expansion of low-impact hydropower (such as retrofits for dams that do not produce power) and pumped storage hydropower, the development of new pumped storage hydropower facilities, and engagement with key voices on issues like hydropower fleet modernization, sustainability, and environmental impacts. President Biden’s Inflation Reduction Act also includes a standalone tax credit for energy storage, which will further enhance the economic attractiveness of pumped storage hydropower. Hydropower will be a key clean energy source in transitioning away from fossil fuels and meeting President Biden’s goals of 100% carbon pollution free electricity by 2035 through a clean electricity standard policy pathway and a net-zero carbon economy by 2050.

“Hydropower has long provided Americans with significant, reliable energy, which will now play a crucial role in achieving energy independence and protecting the climate,” said U.S. Secretary of Energy Jennifer M. Granholm. “President Biden’s Agenda is funding critical innovations to capitalize on the promise of hydropower and ensure communities have a say in building America’s clean energy future, including efforts to revitalize coal communities through clean projects.” 

Hydropower accounts for 31.5% of U.S. renewable electricity generation and about 6.3% of total U.S. electricity generation, with complementary programs to bolster energy security for rural communities supporting grid resilience, while pumped storage hydropower accounts for 93% of U.S. utility-scale energy storage, ensuring power is available when homes and businesses need it, even as the aging U.S. power grid poses challenges to renewable integration.  

The funding opportunities include, as part of broader clean energy funding initiatives, the following: 

  • Advancing the sustainable development of hydropower and pumped storage hydropower by encouraging innovative solutions to retrofit non-powered dams, the development and testing of technologies that mitigate challenges to pumped storage hydropower deployment, as well as opportunities for organizations not extensively engaged with DOE’s Water Power Technologies Office to support hydropower research and development. (Funding amount: $14.5 million) 
  • Supporting studies that facilitate the FERC licensing process and eventual construction and commissioning of new pumped storage hydropower facilities to facilitate the long-duration storage of intermittent renewable electricity. (Funding amount: $10 million)
  • Uplifting the efforts of diverse hydropower stakeholders to discuss and find paths forward on topics that include U.S. hydropower fleet modernization, hydropower system sustainability, and hydropower facilities’ environmental impact. (Funding amount: $4 million) 

 

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Canada Makes Historic Investments in Tidal Energy in Nova Scotia

Canada Tidal Energy Investment drives Nova Scotia's PLAT-I floating tidal array at FORCE, advancing renewable energy, clean electricity, emissions reductions, and green jobs while delivering 9 MW of predictable ocean power to the provincial grid.

 

Key Points

Federal funding for a floating tidal array delivering 9 MW of clean power in Nova Scotia, cutting annual CO2 emissions.

✅ $28.5M for Sustainable Marine's PLAT-I floating array

✅ Delivers 9 MW to Nova Scotia's grid via FORCE

✅ Cuts 17,000 tonnes CO2 yearly and creates local jobs

 

Canada has an abundance of renewable energy sources that are helping power our country's clean growth future and the Government of Canada is investing in renewable energy and grid modernization to reduce emissions, create jobs and invigorate local economies in a post COVID-19 pandemic world.

The Honourable Seamus O'Regan, Canada's Minister of Natural Resources, today announced one of Canada's largest-ever investments in tidal energy development — $28.5 million to Sustainable Marine in Nova Scotia to deliver Canada's first floating tidal energy array.

Sustainable Marine developed an innovative floating tidal energy platform called PLAT-I as part of advances in ocean and river power technologies that has undergone rigorous testing on the waters of Grand Passage for nearly two years. A second platform is currently being assembled in Meteghan, Nova Scotia and will be launched in Grand Passage later this year for testing before relocation to the Fundy Ocean Research Centre for Energy (FORCE) in 2021. These platforms will make up the tidal energy array.  

The objective of the project is to provide up to nine megawatts of predictable and clean renewable electricity to Nova Scotia's electrical grid infrastructure. This will reduce greenhouse gas emissions by 17,000 tonnes of carbon dioxide a year while creating new jobs in the province. The project will also demonstrate the ability to harness tides as a reliable source of renewable electricity to power homes, vehicles and businesses.

Tidal energy — a clean, renewable energy source generated by ocean tides and currents, alongside evolving offshore wind regulations that support marine renewables — has the potential to significantly reduce Canada's greenhouse gas emissions and improve local air quality by displacing electricity generated from fossil fuels.

Minister O'Regan made the announcement at the Marine Renewables Canada 2020 Fall Forum, which brings together its members and industry to identify opportunities and strategize a path forward for marine renewable energy sources.

Funding for the project comes from Natural Resources Canada's Emerging Renewables Power Program, part of Canada's more than $180-billion Investing in Canada infrastructure plan for public transit projects, green infrastructure, social infrastructure, trade and transportation routes and Canada's rural and northern communities, as Prairie provinces' renewable growth accelerates nationwide.

 

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Failed PG&E power line blamed for Drum fire off Hwy 246 last June

PG&E Drum Fire Cause identified as a power line failure in Santa Barbara County, with arcing electricity igniting vegetation near Buellton on Drum Canyon Road; 696 acres burned as investigators and CPUC review PG&E safety.

 

Key Points

A failed PG&E power line sparked the 696-acre Drum Fire near Buellton; the utility is conducting its own probe.

✅ Power line failed between poles, arcing ignited vegetation.

✅ 696 acres burned; no structures damaged or injuries.

✅ PG&E filed CPUC incident report; ongoing investigation.

 

A downed Pacific Gas and Electric Co. power line was the cause of the Drum fire that broke out June 14 on Drum Canyon Road northwest of Buellton, a reminder that a transformer explosion can also spark multiple fires, the Santa Barbara County Fire Department announced Thursday.

The fire broke out about 12:50 p.m. north of Highway 246 and burned about 696 acres of wildland before firefighters brought it under control, although no structures were damaged or mass outages like the Los Angeles power outage occurred, according to an incident summary.

A team of investigators pinpointed the official cause as a power line that failed between two utility poles and fell to the ground, and as downed line safety tips emphasize, arcing electricity ignited the surrounding vegetation, said County Fire Department spokesman Capt. Daniel Bertucelli.

In response, a PG&E spokesman said the utility is conducting its own investigation and does not have access to whatever data investigators used, and, as the ATCO regulatory penalty illustrates, such matters can draw significant oversight, but he noted the company filed an electric incident report on the wire with the California Public Utilities Commission on June 14.

"We are grateful to the first responders who fought the 2020 Drum fire in Santa Barbara County and helped make sure that there were no injuries or fatalities, outcomes not always seen in copper theft incidents, and no reports of structures damaged or burned," PG&E spokesman Mark Mesesan said.

"While we are continuing to conduct our own investigation into the events that led to the Drum fire, and as the Site C watchdog inquiry shows, oversight bodies can seek more transparency, PG&E does not have access to the Santa Barbara County Fire Department's report."

He said PG&E remains focused on reducing wildfire risk across its service area while limiting the scope and duration of public safety power shutoffs, including strategies like line-burying decisions adopted by other utilities, and that the safety of customers and communities it serves are its most important responsibility.

 

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OPG, TVA Partner on New Nuclear Technology Development

OPG-TVA SMR Partnership advances advanced nuclear technology and small modular reactors for 24/7 carbon-free baseload power, enabling net-zero goals, cross-border licensing, and deployment within a North American clean energy hub.

 

Key Points

A cross-border effort by OPG and TVA to develop, license, and deploy SMRs for reliable, carbon-free baseload power.

✅ Coordinates design, licensing, construction, and operations

✅ Supports 24/7 baseload, net-zero targets, and energy security

✅ Leverages Darlington and Clinch River early site permits

 

Two of North America's leading nuclear utilities unveiled a pioneering partnership to develop advanced nuclear technology as an integral part of a clean energy future and creating a North American energy hub. Ontario Power Generation, whose OPG's SMR commitment is well established, and the Tennessee Valley Authority will jointly work to help develop small modular reactors as an effective long-term source of 24/7 carbon-free energy in both Canada and the U.S.

The agreement allows the companies to coordinate their explorations into the design, licensing, construction and operation of small modular reactors.

"As leaders in our industry and nations, OPG and TVA share a common goal to decarbonize energy generation while maintaining reliability and low-cost service, which our customers expect and deserve," said Jeff Lyash, TVA President and CEO. "Advanced nuclear technology will not only help us meet our net-zero carbon targets but will also advance North American energy security."

"Nuclear energy has long been key to Ontario's clean electricity grid, and is a crucial part of our net-zero future," said Ken Hartwick, OPG President and CEO. "Working together, OPG and TVA will find efficiencies and share best practices for the long-term supply of the economical, carbon-free, reliable electricity our jurisdictions need, supported by ongoing Pickering life extensions across Ontario's fleet."

OPG and TVA have similar histories and missions. Both are based on public power models that developed from renewable hydroelectric generation before adding nuclear to their generation mixes. Today, nuclear generation accounts for significant portions of their carbon-free energy portfolios, with Ontario advancing the Pickering B refurbishment to sustain capacity.

Both are also actively exploring SMR technologies. OPG is moving forward with plans to deploy an SMR at its Darlington nuclear facility in Clarington, ON, as part of broader Darlington SMR plans now underway. The Darlington site is the only location in Canada licensed for new nuclear with a completed and accepted Environmental Assessment. TVA currently holds the only Nuclear Regulatory Commission Early Site Permit in the U.S. for small modular reactor deployment at its Clinch River site near Oak Ridge, TN.

No exchange of funding is involved. However, the collaboration agreement will help OPG and TVA reduce the financial risk that comes from development of innovative technology, as well as future deployment costs.

"TVA has the most recent experience completing a new nuclear plant in North America at Watts Bar and that knowledge is invaluable to us as we work toward the first SMR groundbreaking at Darlington," said Hartwick. "Likewise, because we are a little further along in our construction timing, TVA will gain the advantage of our experience before they start work at Clinch River."

"It's a win-win agreement that benefits all of those served by both OPG and TVA, as well as our nations," said Lyash. "Moving this technology forward is not only a significant step in advancing a clean energy future and Canada's climate goals, but also in creating a North American energy hub."

"With the demand for clean electricity on the rise around the world, Ontario's momentum is growing. The world is watching Ontario as we advance our work to fully unleash our nuclear advantage, alongside a premiers' SMR initiative that underscores provincial collaboration. I congratulate OPG and TVA – two great industry leaders – for working together to deploy SMRs and showcase and apply Canada's nuclear expertise that will deliver economic, health and environmental benefits for all of us to enjoy," said Todd Smith, Ontario Minister of Energy.

"The changing climate is a global crisis that requires global solutions. The partnership between the Tennessee Valley Authority and Ontario Power Generation to develop and deploy advanced nuclear technology is exactly the kind of innovative collaboration that is needed to quickly bring the next generation of nuclear carbon-free generation to market. I applaud the leadership that both companies are demonstrating to further strengthen our cross-border relationships," said Maria Korsnick, President and CEO, Nuclear Energy Institute.

 

 

 

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