Electric cars: a boon for Canada?

By Globe and Mail


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Canada is well-positioned to take advantage of moves by auto makers to bring electric vehicles and other fuel-efficient technologies to market, say analysts who have studied these developments.

The opportunities for Canada are exemplified by Ford Motor Co.'s partnership with Canadian auto parts manufacturer Magna International to produce a fully electric car that goes up to 160 kilometres on a single charge.

Magna officials say the partnership will create jobs at Magna, and there are more opportunities out there.

Bill Pochiluk, president of industry adviser AutomotiveCompass LLC, has said Canada has all the resources it needs to be a global leader in green automotive technology. Canadian governments can help by funding more research and development.

The United States has already put in place a $25-billion (US) fund for research and development of green automotive technology. Canada only invests $500,000 annually.

Opportunities for Canada exist in developing lightweight aluminum components that help improve fuel efficiency of gasoline vehicles and extend the range of electric and hybrid ones. Federal organizations such as the National Research Council have a role to play in funding the development of these sorts of green vehicle technologies, say advocates.

There is much at stake. One in every 20 new cars sold in Canada could be electrically powered within a decade, say members of a task force on the future of plug-in vehicles.

The group was set up by the federal government last winter to design Canada's Electric Vehicle and Technology Road Map for shifting the transportation industry away from fossil fuels.

"It's going to be an electric vehicle revolution," says Michael Elwood, chairperson of the task force and vice-president of marketing at Vancouver-based Azure Dynamics, which specializes in electric and hybrid electric drive technology.

"Hybrid electric, plug-in hybrid electric and electric vehicles are all part of the equation," he says.

If one in 20 new cars sold in Canada is electric — 5 per cent of the market — about 80,000 electric vehicles would be sold each year, based on current sales volumes.

"Electricity may be the only fuel for land transportation that can substantially replace oil products while continuing to provide for the amount of movement of people and freight that is essential for modern society," says the report.

"Oil products now fuel 95 per cent of world transport activity and transport activity consumes 60 per cent of oil production. Both shares are higher in Canada. The need to reduce demand for oil, to avert scarcity and high prices is gathering urgency."

Auto manufacturers are, of course, moving ahead with hybrid and electric technologies in their new models. But the success of electrics and hybrids is contingent on consumer demand, fuel prices and, perhaps above all, research and development funding.

At present, auto companies, even ones with a relatively strong balance sheet and a pristine credit rating, are finding it impossible to get the financing needed to develop the batteries and other technologies that will make clean electric cars safe, reliable, practical and affordable.

"If we want to transform this industry, in a radical way, we are going to need a lot of investment," says Nissan CEO Carlos Ghosn. "You cannot take an existing car and retrofit it and say, 'It's electric.' You have to start from zero.

"If we are serious about transforming the industry into something that's as clean as possible, [governments] have to make long-term financing available at a reasonable interest rate."

Ghosn adds that "even Triple-A companies" are having problems getting financing simply for operations.

"The industry today is unable to finance itself to make the transition. But when you are investing massively in batteries, when the financial market doesn't care about it, it is impossible. Who is struggling is not the issue. This is not a Big Three issue. It is valid for Europeans. It is valid for the Japanese," Ghosn said.

Ghosn and others say the industry is in the early stages of a revolutionary change in technology — from internal combustion engines that have dominated for a century to electric vehicles that most believe are the future. But research into creating more powerful, longer-lasting batteries is expensive, as is developing sufficient infrastructure for owners of electric vehicles to charge their vehicles.

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Electricity rates are about to change across Ontario

Ontario Electricity Rate Changes lower OEB Regulated Price Plan costs, adjust Time-of-Use winter hours and tiered thresholds, and modify the Ontario Electricity Rebate, affecting off-peak, mid-peak, and on-peak pricing for households and small businesses.

 

Key Points

OEB updates lowering RPP prices, shifting TOU hours, adjusting tiers, and modifying the Ontario Electricity Rebate.

✅ Winter TOU: Off-peak 7 p.m.-7 a.m.; weekends, holidays all day.

✅ Tiered pricing adds 400 kWh at lower rate for residential users.

✅ Ontario Electricity Rebate falls to 11.7% from 17% on Nov 1.

 

Electricity rates are about to change for consumers across Ontario.

On November 1, households and small businesses will see their electricity rates go down under the Ontario Energy Board's (OEB) Regulated Price Plan framework.

Customer's on the OEB's tiered pricing plan will also see their bills lowered on November 1, a shift from the 2021 increase when fixed pricing ended, as winter time-of-use hours and the seasonal change in the killowatt-hour threshold take effect.

Off-peak time-of-use hours will run from 7 p.m. to 7 a.m. during weekdays, including the ultra-low overnight rates option for some customers, and all day on weekends and holidays. On-peak hours will be from 7 a.m. to 11 a.m. and 5 p.m. to 7 p.m. on weekdays, and mid-peak hours from 11 a.m. to 5 p.m. on weekdays.

The winter-tier threshold provides residential customers with an extra 400 kilowatt-hours per month at a lower price during the colder weather, alongside the off-peak price freeze in effect.

The Ontario Electricity Rebate - a pre-tax credit that shows up at the bottom of electricity bills - will also see changes as a hydro rate change takes effect on November 1. Starting next month, the rebate will drop from 17 per cent to 11.7 per cent.

For a typical residential customer, the credit will decrease electricity bills by about $13.91 per month, according to the OEB.

Under the board's winter disconnection ban, electricity providers can't turn off a residential customer's power between November 15, 2022 and April 30, 2023 for failing to pay, and earlier pandemic relief included a fixed COVID-19 hydro rate for customers.

 

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'Pakistan benefits from nuclear technology'

Pakistan Nuclear Energy advances clean power with IAEA guidance, supporting SDGs via electricity generation, nuclear security, and applications in healthcare, agriculture, and COVID-19 testing, as new 1,100 MW reactors near grid connection.

 

Key Points

Pakistan Nuclear Energy is the nation's atomic program delivering clean electricity, SDGs gains, and IAEA-guided safety.

✅ Two 1,100 MW reactors nearing grid connection

✅ IAEA-aligned safety and nuclear security regime

✅ Nuclear tech supports healthcare, agriculture, COVID-19 tests

 

Pakistan is utilising its nuclear technology to achieve its full potential by generating electricity, aligning with China's steady nuclear development trends, and attaining socio-economic development goals outlined by the United Nations Sustainable Development Goals.

This was stated by Pakistan Atomic Energy Commission (PAEC) Chairperson Muhammad Naeem on Tuesday while addressing the 64th International Atomic Energy Agency (IAEA) General Conference (GC) which is being held in Vienna from September 21, a forum taking place amid regional milestones like the UAE's first Arab nuclear plant startup as well.

Regarding nuclear security, the PAEC chief stated that Pakistan considered it as a national responsibility and that it has developed a comprehensive and stringent safety and security regime, echoing IAEA praise for China's nuclear security in the region, which is regularly reviewed and upgraded in accordance with IAEA's guidelines.

Many delegates are attending the event through video link due to the novel coronavirus (Covid-19) pandemic.

On the first day of the conference, IAEA Director General Rafael Mariano Grossi highlighted the role of the nuclear watchdog in the monitoring and verification of nuclear activities across the globe, as seen in Barakah Unit 1 at 100% power milestones reported worldwide.

He also talked about the various steps taken by the IAEA to help member states contain the spread of coronavirus such as providing testing kits etc.

In a recorded video statement, the PAEC chairperson said that Pakistan has a mutually beneficial relationship with IAEA, similar to IAEA assistance to Bangladesh on nuclear power development efforts. He also congratulated Ambassador Azzeddine Farhane on his election to become the President of the 64th GC and assured him of Pakistan's full support and cooperation.

Naeem stated that as a clean, affordable and reliable source, nuclear energy can play a key role, with India's nuclear program moving back on track, in fighting climate change and achieving the Sustainable Development Goals (SDGs).

The PAEC chief informed the audience that two 1,100-megawatt (MW) nuclear power plants are near completion and, like the UAE grid connection milestone, are expected to be connected to the national grid next year.

He also highlighted the role of PAEC in generating electricity through nuclear power plants, while also helping the country achieve the socio-economic development goals outlined under the United Nations SDGs through the application of nuclear technology in diverse fields like agriculture, healthcare, engineering and manufacturing, human resource development and other sectors.

 

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Covid-19 puts brake on Turkey’s solar sector

Turkey Net Metering Suspension freezes regulator reviews, stalling rooftop solar permits and grid interconnections amid COVID-19, pausing licensing workflows, EPC pipelines, and electricity bill credits that drive commercial and household prosumer adoption.

 

Key Points

A pause on technical reviews freezing net metering applications and slowing rooftop solar deployment in Turkey.

✅ Monthly technical committee meetings suspended indefinitely

✅ Rooftop solar permits and grid interconnections on hold

✅ EPC firms urge remote evaluations for transparency

 

The decision by the Turkish Energy Market Regulatory Authority to halt part of the system of processing net metering applications risks bringing the only vibrant segment of the nation’s solar industry to a grinding halt, a risk amplified as global renewables face Covid-19 disruptions across markets.

The regulator has suspended monthly meetings of the committee which makes technical evaluations of net metering applications, citing concerns about the spread of Covid-19, which has already seen U.S. utility-scale solar face delays this year.

The availability of electricity bill credits for net-metering-approved households which inject surplus power into the grid, similar to how British households can sell power back to energy firms, has seen the rooftop projects the scheme is typically associated with remain the only source of new solar generation capacity in Turkey of late.

However the energy regulator’s decision to suspend technical evaluation committee meetings until further notice has seen the largely online licensing process for new solar systems practically cease; by contrast, Berlin is being urged to remove PV barriers to keep projects moving.

The Turkish solar industry has claimed the move is unnecessary, with solar engineering, procurement and construction services businesses pointing out the committee could meet to evaluate projects remotely. It has been argued such a move would streamline the application process and make it more transparent, regardless of the current public health crisis.

 

Net metering 

Turkey introduced net metering for rooftop installations last May and pv magazine has reported the specifics of the scheme, amid debates like New England's grid upgrade costs over who pays.

National grid operator Teias confirmed recently the country added 109 MW of new solar capacity in the first quarter, most of it net-metered rooftop systems, even as Australian distributors warn excess solar can strain local networks.

Net metering has been particularly attractive to commercial electricity users because the owners of small and medium-sized businesses pay more for power, as solar reshapes electricity prices in Northern Europe, than either households or large scale industrial consumers.

Until the recent technical committee decision by the regulator, the chief obstacle to net metering adoption had been the nation’s economic travails. The Turkish lira has lost 14% of its value since January and around 36% over the last two years. The central bank has been using its foreign reserves to support state lenders and the lira but the national currency slipped near an all-time low on Friday and foreign analysts predict the central bank reserves could run dry in July.

The level of exports shipped last month was down 41% on April last year and imports fell 28% by the same comparison, further depressing the willingness of companies to make capital investments such as rooftop solar.

 

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Coronavirus could stall a third of new U.S. utility solar this year: report

U.S. Utility-Scale Solar Delays driven by the coronavirus pandemic threaten construction timelines, supply chains, and financing, with interconnection and commissioning setbacks, module sourcing risks in Southeast Asia, and tax credit deadline pressures impacting project delivery.

 

Key Points

Setbacks to large U.S. solar builds from COVID-19 impacting construction, supply, financing, and permitting.

✅ Construction, interconnection, commissioning site visits delayed

✅ Supply chain risks for modules from Southeast Asia

✅ Tax credit deadline extensions sought by developers

 

About 5 gigawatts (GW) of big U.S. solar energy projects, enough to power nearly 1 million homes, could suffer delays this year if construction is halted for months due to the coronavirus pandemic, as the Covid-19 crisis hits renewables across the sector, according to a report published on Wednesday.

The forecast, a worst-case scenario laid out in an analysis by energy research firm Wood Mackenzie, would amount to about a third of the utility-scale solar capacity expected to be installed in the United States this year, even as US solar and wind growth continues under favorable plans.

The report comes two weeks after the head of the top U.S. solar trade group called the coronavirus pandemic (as solar jobs decline nationwide) "a crisis here" for the industry. Solar and wind companies are pleading with Congress to extend deadlines for projects to qualify for sunsetting federal tax credits.

Even the firm’s best-case scenario would result in substantial delays, mirroring concerns that wind investments at risk across the industry. With up to four weeks of disruption, the outbreak will push out 2 GW of projects, or enough to power about 380,000 homes. Before factoring in the impact of the coronavirus, Wood Mackenzie had forecast 14.7 GW of utility-scale solar projects would be installed this year.

In its report, the firm said the projects are unlikely to be canceled outright. Rather, they will be pushed into the second half of 2020 or 2021. The analysis assumes that virus-related disruptions subside by the end of the third quarter.

Mid-stage projects that still have to secure financing and receive supplies are at the highest risk, Wood Mackenzie analyst Colin Smith said in an interview, adding that it was too soon to know whether the pandemic would end up altering long-term electricity demand and therefore utility procurement plans, where policy shifts such as an ITC extension could reshape priorities.

Currently, restricted travel is the most likely cause of project delays, the report said. Developers expect delays in physical site visits for interconnection and commissioning, and workers have had difficulty reaching remote construction sites.

For earlier-stage projects, municipal offices that process permits are closed and in-person meetings between developers and landowners or local officials have slowed down.

Most solar construction is proceeding despite stay at home orders in many states because it is considered critical infrastructure, and long-term proposals like a tenfold increase in solar could reshape the outlook, the report said, adding that “that could change with time.”

Risks to supplies of solar modules include potential manufacturing shutdowns in key producing nations in Southeast Asia such as Malaysia, Vietnam and Thailand. Thus far, solar module production has been identified as an essential business and has been allowed to continue.

 

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Company Becomes UK's Second-Largest Electricity Operator

Second-Largest UK Grid Operator advancing electricity networks modernization, smart grid deployment, renewable integration, and resilient distribution, leveraging acquisitions, data analytics, and infrastructure upgrades to boost reliability, efficiency, and service quality across regions and energy sector.

 

Key Points

A growing electricity networks operator advancing smart grids, renewable integration, and reliability.

✅ Expanded via acquisitions and regional growth

✅ Investing in smart grid, data analytics, automation

✅ Enhancing reliability, resilience, renewable integration

 

In a significant shift within the UK’s energy sector, a major company has recently ascended to become the second-largest electricity networks operator in the country. This milestone marks a pivotal moment in the industry, reflecting ongoing changes and competitive dynamics in the energy landscape, such as the shift toward an independent system operator in Great Britain. The company's ascent underscores its growing influence and its role in shaping the future of energy distribution across the UK.

The company, whose identity is a result of strategic acquisitions and operational expansions, now holds a substantial position within the electricity networks sector. This new ranking is the result of a series of investments and strategic moves aimed at strengthening its network capabilities and, amid efforts to fast-track grid connections across the UK, expanding its geographical reach. By achieving this status, the company is set to play a crucial role in managing and maintaining the electricity infrastructure that serves millions of households and businesses across the UK.

The rise to the second-largest position follows a period of significant growth and transformation for the company. Recent acquisitions have enabled it to enhance its network infrastructure, integrate advanced technologies, adopting a more digital grid approach, and improve service delivery. These developments come at a time when the UK is undergoing a significant transition in its energy sector, driven by the need for modernization, sustainability, and resilience in response to evolving energy demands.

One of the key factors contributing to the company's new status is its focus on upgrading and expanding its electricity networks. Investments in modernizing infrastructure, such as the commissioning of a 2GW substation to boost capacity, incorporating smart grid technologies, and enhancing operational efficiencies have been central to its strategy. By leveraging cutting-edge technology and data analytics, the company is able to optimize network performance, reduce outages, and improve overall reliability.

The company’s expansion into new regions has also played a crucial role in its growth. By extending its network coverage, including assets like the London electricity tunnel that enhance supply routes, the company has been able to provide electricity to a larger customer base, increasing its market share and influence in the sector. This expansion not only enhances its position as a major player in the industry but also supports the broader goal of ensuring reliable and efficient electricity distribution across the UK.

The shift to becoming the second-largest operator also reflects broader trends in the UK energy sector. The industry is experiencing a period of consolidation and transformation, driven by regulatory changes, technological advancements, and the push towards decarbonization, with similar momentum seen in British Columbia's clean energy shift that underscores global trends. The company’s ascent is indicative of these broader dynamics, as firms adapt to new challenges and opportunities in a rapidly evolving market.

In addition to operational and strategic advancements, the company’s rise is aligned with the UK’s broader energy goals. The government has set ambitious targets for reducing carbon emissions and increasing the use of renewable energy sources. As a major electricity networks operator, the company is positioned to support these goals by integrating renewable energy into the grid, including projects like the Scotland-to-England subsea link that carry remote generation, enhancing energy efficiency, and contributing to the transition towards a low-carbon energy system.

The company’s new status also brings with it a range of responsibilities and opportunities. As one of the largest operators in the sector, it will have a significant role in shaping the future of electricity distribution in the UK. This includes addressing challenges such as grid reliability, energy security, and the integration of emerging technologies. The company’s ability to manage these responsibilities effectively will be crucial in ensuring that it continues to deliver value to customers and stakeholders.

The transition to becoming the second-largest operator is not without its challenges. The company will need to navigate a complex regulatory environment, manage stakeholder expectations, and address any operational issues that may arise from its expanded network. Additionally, the competitive nature of the energy sector means that the company will need to continuously innovate and adapt to maintain its position and drive further growth.

In summary, the company’s achievement of becoming the second-largest electricity networks operator in the UK represents a significant milestone in the energy sector. Through strategic acquisitions, infrastructure investments, and operational enhancements, the company has strengthened its position and expanded its reach. This development highlights the evolving landscape of the UK energy sector and underscores the importance of modernization and innovation in meeting the country’s energy needs. As the company moves forward, it will play a key role in shaping the future of electricity distribution and supporting the UK’s energy transition goals.

 

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"Kill the viability": big batteries to lose out from electricity grid rule change

AEMC Storage Charging Rules spark industry backlash as Tesla, Snowy Hydro, and investors warn transmission charges on batteries and pumped hydro could deter grid-scale storage, distort the National Electricity Market, and slow decarbonisation.

 

Key Points

AEMC Storage Charging Rules are proposals to bill grid storage for network use, shaping costs and investment.

✅ Charges apply when batteries draw power; double-charging concerns.

✅ Tesla and Snowy Hydro warn of reduced viability and delays.

✅ AEMO recommends exemptions; investors seek certainty.

 

Tesla, Snowy Hydro and other big suppliers of storage capacity on Australia’s main electricity grid warn proposed rule changes amount to a tax on their operations that will deter investors and slow the decarbonisation of the industry.

The Australian Energy Market Commission (AEMC) will release its final decision this Thursday on new rules for integrating batteries, pumped hydro and other forms of storage.

The AEMC’s draft decision, released in July, angered many firms because it proposed charging storage providers for drawing power, ignoring a recommendation by the Australian Electricity Market Operator (AEMO) that they be exempt.

Battery maker Tesla, which has supplied some of the largest storage to the National Electricity Market, said in a submission that the charges would “kill the commercial viability of all grid storage projects, causing inefficient investment in alternative network”, with consumers paying higher costs.

Snowy Hydro, which is building the giant Snowy 2 pumped storage project and already operates a smaller one, said in its submission the proposed changes if implemented would jeopardise investment.

“This is a major policy change, amounting to a tax on infrastructure critical to achieving a renewable future,” Snowy Hydro said.

AEMO itself argued it was important storage providers were not “disincentivised from connecting to the transmission network, as they generally provide a net benefit to the power system by charging at periods of low demand”.

Australia’s electricity grid faces economic and engineering challenges, similar to Ontario's storage push as it adjusts to the arrival of lower cost and also lower carbon alternatives to fossil fuels.

While rule changes are necessary to account for operators that can both draw from and supply power, how they are implemented can have long-lasting effects on the technologies that get encouraged or repelled, including control of EV charging issues, independent experts say.

“It doesn’t have to be this way,” said Bruce Mountain, director of the Victoria Energy Policy Centre. “In Britain, where the UK grid transformation is underway, the regulator dealing with the same issues has said that storage devices don’t pay the system charges when they withdraw electricity from the grid,” he said.

The prospect that storage operators will have to pay transmission charges could “drastically” affect their profitability since their business models rely on the difference between the price their pay for power and how much they can sell it for. Gas generators and network monopolies would benefit from the change, Mountain said.

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An AEMC spokesperson said the commission had consulted widely, including from those who objected to the payment for transmission access.

“The market is moving towards a future that will be increasingly reliant on energy storage to firm up the growing volume of renewable energy and deliver on the increasing need for critical system security services, with examples such as EVs supporting grid stability in California as the ageing fleet of thermal generators retire,” the spokesperson said, declining to elaborate on the final ruling before it is published.

“The regulatory framework needs to facilitate this transition as the energy sector continues to decarbonise,” the official said.

AusNet, which operates the Victorian energy transmission grid, said that while “technological neutrality is paramount for battery and hybrid unit connections to both the distribution and transmission networks,” it did not back charging storage access to networks in all cases.

“[Ausnet] supports a clear exemptions framework for energy storage providers,” a spokesperson said. “We recommend that batteries and other hybrid facilities should have transmission use of system charges waived if they provide a net benefit to network customers.”

We are not aware of anyone that supports the charging storage access to networks in all circumstances.

“Batteries and hybrid facilities that consume energy from the network should be provided no preferential treatment relative to other customers and generators.”

Jonathan Upson, a principal at Strategic Renewable Consulting, though, said the AEMC wants electricity flowing through batteries to be taxed twice to pay network charges – once when the electricity charges the battery and then again when the same electricity is sent out by the battery an hour or two later but this time with customers paying.

“The AEMC’s draft decision has the identical rationale for eliminating franking credits on all dividends, resulting in double taxing of company profits,” he said.

Christiaan Zuur, director of energy transformation at the Clean Energy Council, said that while much of AEMC’s draft proposal was constructive, “those benefits are either nullified or maybe even outweighed” by uncertainty over charges.

“Risk perception” will be important since potential newcomers won’t be sure of what charges they will pay to connect to the grid and existing operators could have their connection agreements reopened, Zuur said.

“Investors focus on the potential risk. It does factor through to the integral costs for projects,” he said.

The outcome of new charges may prompt more people to put batteries on their premises and draw power from their own solar panels, Mountain said, with rising EV adoption introducing new grid challenges, cutting their reliance on a centralised network.

“Ironically, it encourages customers to depend less and less on the grid,” he said. “It’s almost like the capture of the dominant interests playing out over time at their own expense.”

Separately, the latest edition of the Clean Energy Council Confidence Index shows leadership by state governments is helping to shore up investor appetite for investing in renewable energy amid 2021 electricity lessons even with higher 2030 emissions reduction goals from the federal government.

Overall, investor confidence increased by a point in the last six months – from 6.3 to 7.3 out of 10 – following strong commitments and policy development from state governments, particularly on the east coast, the council said.

“The results of this latest survey illustrate the economic value in policy that lowers the emissions footprint of our electricity generation, supporting regional centres and creating jobs. Investors recognise the opportunities created by limiting global temperature rise to 1.5 degrees,” said council chief executive Kane Thornton.

Among the states, NSW, Victoria and Queensland led in terms of positive investor sentiment.

Correction: this article was amended on 30 November. An earlier version stated Ausnet supported charging storage for network access. A spokesperson said it backed a waiver on charges if certain conditions are met.        

 

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