China To Generate Electricity From Compressed Air


China To Generate Electricity From Compressed Air

Electrical Testing & Commissioning of Power Systems

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China Compressed-Air Energy Storage enables grid flexibility using salt caverns in Jiangsu, delivering long-duration storage for wind and solar, 60 MW capacity, dispatchable power, and low-cost, safe, round-the-clock clean energy integration.

 

Key Points

Stores off-peak power by compressing air in salt caverns, then drives turbines on demand to balance renewables.

✅ 60 MW Jintan plant connects to grid; commercial CAES milestone

✅ Uses salt caverns; low-cost long-duration storage; high safety

✅ Balances wind and solar; improves grid flexibility and reliability

 

China is set to connect its first commercial compressed-air energy storage plant to the grid as it seeks more ways to harness fast-growing clean power resources, including new hydropower alongside other long-duration options such as gravity power technologies for around-the-clock use.

China Huaneng Group Co. said its Jiangsu Jintan Salt Cave project recently underwent four days of successful trials and is now ready for commercial operations. The 60-megawatt plant will be the largest compressed air energy storage plant built anywhere in the world since 1991, and the first in China outside of small-scale technology demonstration projects, as China's electricity demand patterns remain in flux, according to BloombergNEF.

The plant will use electricity at night when demand is low to pump air into an underground salt cavern. Then, when demand is high during the day, it can release the compressed air at high enough pressure to spin a turbine and produce electricity, aligning with projections that 60% electricity by 2060 could be reached according to industry outlooks.

Underground compressed air is considered one of the least costly forms of long-term energy storage and has low safety concerns, according to BloombergNEF. But its reliance on certain topographical features such as underground caverns may limit wider deployment, a challenge shared by other regions weighing large-scale storage options for reliability. It’s gained a foothold in China, with nearly four gigawatts of projects in the pipeline, while there are less than two gigawatts combined planned in the rest of the world. Shandong province said just this week in this year's work plan that it would build three projects using the technology.

The Jintan salt caves in Jiangsu, China’s second-biggest provincial economy just north of Shanghai, can store about 10 million cubic meters of gas, enough to power four gigawatts of compressed air plants, according to a Science and Technology Daily report from last year. 

Energy storage is a key part of China’s plan to build a larger and more flexible grid as it tries to peak carbon emissions before 2030 and zero them out before 2060, alongside continued nuclear energy development to stabilize baseload supply. The country is adding a world-leading amount of wind and solar power every year, but their intermittency strains grids that need to be able to deliver electricity all the time, spurring interest in green hydrogen as a flexible complement. China has set targets of 30 gigawatts of new-energy storage by 2025 and 120 gigawatts of pumped hydro storage by 2030. 

 

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Toronto to start trial run of 'driverless' electric vehicle shuttles

Toronto Olli 2.0 Self-Driving Shuttle connects West Rouge to Rouge Hill GO with autonomous micro-transit. Electric shuttle pilot by Local Motors and Pacific Western Transportation, funded by Transport Canada, features accessibility, TTC and Metrolinx support.

 

Key Points

An autonomous micro-transit pilot linking West Rouge to Rouge Hill GO, with accessibility and onboard staff.

✅ Last-mile link: West Rouge to Rouge Hill GO

✅ Accessible: ramp, wheelchair securement, A/V announcements

✅ Operated with attendants; funded by Transport Canada

 

The city of Toronto, which recently opened an EV education centre to support adoption, has approved the use of a small, self-driving electric shuttle vehicle that will connect its West Rouge neighbourhood to the Rouge Hill GO station, a short span of a few kilometres.

It’s called the Olli 2.0, and it’s a micro-shuttle with service provided by Local Motors, in partnership with Pacific Western Transportation, as the province makes it easier to build EV charging stations to support growing demand.

The vehicle is designed to hold only eight people, and has an accessibility ramp, a wheelchair securement system, audio and visual announcements, and other features for providing rider information, aligning with transit safety policies such as the TTC’s winter lithium-ion device restrictions across the system.

“We are continuing to move our city forward on many fronts including micro-transit as we manage the effects of COVID-19,” said Mayor John Tory. “This innovative project will provide valuable insight, while embracing innovation that could help us build a better, more sustainable and equitable transportation network.”

At the provincial level, the public EV charging network has faced delays, underscoring infrastructure challenges.


Although the vehicle is “self-driving,” it will still require two people onboard for every trip during the six- to 12-month trial; those people will be a certified operator from Pacific Western Transportation, and either a TTC ambassador from an agency introducing battery electric buses across its fleet, or a Metrolinx customer service ambassador.

Funding for the program comes from Transport Canada, as part of a ten-year pilot program to test automated vehicles on Ontario’s roads that was approved in 2016, and it complements lessons from the TTC’s largest battery-electric bus fleet as well as emerging vehicle-to-grid programs that engage EV owners.

 

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Hitachi Energy to accelerate sustainable mobility in Germany's biggest city

Grid-eMotion Fleet Smart Charging enables BVG Berlin to electrify bus depots with compact grid-to-plug DC infrastructure, smart charging software, and high reliability, accelerating zero-emission electric buses, lower noise, and space-efficient e-mobility.

 

Key Points

Grid-to-plug DC charging for bus depots, with smart software to reliably power zero-emission electric bus fleets.

✅ Up to 60% less space and 40% less cabling than alternatives

✅ DC charging with smart scheduling for depot operations

✅ Scalable, grid-code compliant, low-noise, high reliability

 

Grid-eMotion Fleet smart charging solution to help the City of Berlin reach its goal of a zero-emission bus fleet by 2030

Dubai, UAE: Hitachi Energy has won an order from Berliner Verkehrsbe-triebe (BVG), Germany’s biggest municipal public transportation company, to supply its Grid-eMotionTM Fleet smart charging infrastructure to help BVG transition to sustainable mobility in Berlin, the country’s capital, where an electric flying ferry initiative underscores the city’s e-mobility momentum.

Hitachi Energy will provide a complete Grid-eMotion Fleet grid-to-plug charging infrastructure solution for the next two bus depots to be converted in the bus electrification program. Hitachi Energy’s solution offers the smallest footprint for both the connection, as well as low noise emissions and high reliability that support grid stability across operations – three key requirements for bus depots in a densely populated urban environment, where space is limited and flawless charging is vital to ensure buses run on time.

The solution comprises a connection to the distribution grid, where effective grid coordination streamlines integration, power distribution and DC charging infrastructure with charging points and smart charging systems. Hitachi Energy will perform the engineering and integrate, install and service the entire solution. The solution has a compact and robust design that requires less equipment than competing infrastructure, which results in a small footprint, lower operating and maintenance costs, and higher reliability. Typically, Grid-eMotion Fleet requires 60 percent less space and 40 percent less cabling than alternative charging systems; it also provides superior overall system reliability.

“We are delighted to help the City of Berlin in its transition to quiet and emission-free transportation and a sustainable energy future for the people of this iconic capital,” said Niklas Persson, Managing Director of Hitachi Energy’s Grid Integration business. “We feel the urgency and have the pioneering technology and commitment to advance sustainable mobility, thus improving the quality of life of millions of people.”

BVG operates Germany’s biggest city bus fleet of around 1,500 vehicles, which it aims to make completely electric and emission-free by 2030, and could benefit from vehicle-to-grid pilots to enhance flexibility. This requires the installation of charging infra-structure in its large network of bus depots.

About Grid-eMotion:

Grid-eMotion comprises two unique, innovative solutions – Fleet and Flash. Grid-eMotion Fleet is a grid-code compliant and space-saving grid-to-plug charging solution that can be in-stalled in new and existing bus depots. The charging solution can be scaled flexibly as the fleet gets bigger and greener. It includes a robust and compact grid connection and charging points, and is also available for commercial vehicle fleets, including last-mile delivery and heavy-duty trucks, as electric truck fleets scale up, requiring high power charging of several megawatts. Grid-eMotionTM Flash enables operators to flash-charge buses within seconds at passenger stops and fully recharge within minutes at the route terminus, without interrupting the bus schedule.

Both solutions are equipped with configurable smart charging digital platforms that can be em-bedded with larger fleet and energy management systems, enabling vehicle-to-grid capabilities for bidirectional charging. Additional offerings from Hitachi Energy for EV charging systems consist of e-meshTM energy management and optimization solutions and Lumada APM, EAM and FSM solutions, to help transportation operators make informed decisions that maximize their uptime and improve efficiency.

In the past few months alone, Hitachi Energy has won orders from customers and partners all over the world for its smart charging portfolio – a sign that Grid-eMotion is changing the e-mobility landscape for electric buses and commercial vehicles, as advances in energy storage and mobile charging bolster resilience. Grid-eMotion solutions are al-ready operating or under development in Australia, Canada, China, India, the Middle East, the United States and several countries in Europe.

 

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Scores more wind turbines proposed for Long Island’s South Shore

New York Offshore Wind Expansion adds Equinor's Empire Wind 2 and Beacon Wind, boosting megawatts, turbines, and grid connections for Long Island and Queens, with jobs, assembly at South Brooklyn Marine Terminal, and clean energy.

 

Key Points

A statewide initiative proposing new Equinor and partner projects to scale offshore wind capacity, jobs, and grid links.

✅ Adds 2,490 MW via Empire Wind 2 and Beacon Wind

✅ Connects to Nassau County and Queens grids for reliability

✅ Creates 3,000+ NY jobs with South Brooklyn Marine Terminal work

 

Scores more 600-foot tall wind turbines would be built off Jones Beach under a new proposal.

Norwegian energy conglomerate Equinor has bid to create another 2,500 megawatts of offshore wind power for New York state and Long Island, where offshore wind sites are being evaluated, with two projects. One, which would connect to the local electric grid in Nassau County, would more than double the number of turbines off Long Island to some 200. A second would be built around 50 miles from Montauk Point and connect to the state grid in Queens. The plan would also include conducting assembly work in Brooklyn.

In disclosures Tuesday in response to a state request for proposals, Equinor said it would bolster its already state-awarded, 819-megawatt Empire Wind project off Long Island’s South Shore with another called Empire Wind 2 that will add 1,260 megawatts. Turbines of at least 10 megawatts each would mean that the prior project’s 80 or so turbines could be joined by another 120. Equinor’s federally approved lease area off Long Island encompasses some 80,000 acres, starting 15 miles due south of Long Beach and extending east and south.

Equinor on Tuesday also submitted plans to offer a second project called Beacon Wind that would be built 50 miles from Montauk Point, off the Massachusetts South Coast area. It would be 1,230 megawatts and connect through Long Island Sound to Queens.

Equinor said its latest energy projects would generate more than 3,000 New York jobs, including use of the South Brooklyn Marine Terminal for “construction activities” and an operations and maintenance base.

The new proposals came in response to a New York State Energy Research and Development Authority bid request for renewable projects in the state. In a statement, Siri Espedal Kindem, president of Equinor Wind U.S., said the company’s plans would include “significant new benefits for New York – from workforce training, economic development, and community benefits – alongside a tremendous amount of homegrown, renewable energy.”

Meanwhile, Denmark-based Orsted, working with New England power company Eversource, has also submitted plans for a new offshore wind project called Sunrise Wind 2, a proposal that includes “multiple bids” that would create “hundreds of new jobs, and infrastructure investment,” according to a company statement. Con Edison Transmission will also work to develop transmission facilities for that project, the companies said.

Orsted and Eversource already have contracts to develop a 130-megawatt wind farm for LIPA to serve the South Fork, and an 880-megawatt wind farm for the state. All of its hundreds of turbines would be based in a lease area off the coast of Massachusetts and Rhode Island, where Vineyard Wind has progressed as a key project.

“Sunrise Wind 2 will create good-paying jobs for New York, support economic growth, and further reduce emissions while delivering affordable clean energy to Long Island and the rest of New York,” Joe Nolan, executive vice president for Eversource, said in a statement.

 

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Canada’s Clean Energy Sector Growth

Canada’s clean energy sector is expanding as Indigenous communities lead electricity transmission projects, drive sustainable growth, and strengthen energy independence through renewable power, community ownership, and grid connections across remote and regional areas of Canada.

 

What is Canada’s Clean Energy Sector?

Canada’s clean energy sector encompasses industries and initiatives that generate, transmit, and manage low-carbon electricity to meet the country's national climate goals. It emphasizes Indigenous participation, renewable innovation, and equitable economic growth.

✅ Expands renewable electricity generation and transmission

✅ Builds Indigenous-led ownership and partnerships

✅ Reduces emissions through sustainable energy transition

 

Canada’s clean energy sector is entering a pivotal era of transformation, with Indigenous communities emerging as leading partners in expanding electricity transmission and renewable infrastructure, including grid modernization projects that are underway nationwide. These communities are not only driving projects that connect remote regions to the grid but also redefining what energy leadership and equity look like in Canada.

At a recent webinar co-hosted by the Canadian Climate Institute and the Indigenous Power Coalition, panellists discussed the growing wave of Indigenous-led electricity transmission projects and the policies needed to strengthen Indigenous participation. The event, moderated by Frank Busch, featured Margaret Kenequanash, CEO of Wataynikaneyap Power; Kahsennenhawe Sky-Deer, Grand Chief of the Mohawk Council of Kahnawà:ke; and Blaise Fontaine, Co-Founder of ProACTIVE Planning Inc. and Indigenous Power Coalition.

The discussion comes at a crucial moment for Canada’s clean energy transition. As the country races to meet its climate commitments and zero-emissions electricity by 2035 targets, demand for clean power is rising rapidly. Historically, energy development in Canada occurred on Indigenous lands without consent or fair participation, but today, Indigenous communities collectively represent the largest clean energy asset owners outside Crown and private utilities.

“There is a genuine appetite for Indigenous communities to not just own transmission projects but to also lead,” said Fontaine. He noted that Indigenous communities are increasingly setting the terms of engagement, selecting partners, and shaping projects in line with their cultural and environmental values.

One of the strongest examples of this transformation is the Wataynikaneyap (Watay) Power Project in northern Ontario, a 1,800-kilometre transmission line connecting 17 remote First Nations communities to the provincial grid. “Communities must fully understand what they are getting into, since it is their homelands that will be impacted,” said Kenequanash. She emphasized that the project’s success came from five years of inter-community meetings to agree on shared principles before any external engagement.

The panel also highlighted the Hertel–New York Interconnection Line, co-owned by Hydro-Québec and the Mohawk Council of Kahnawà:ke, as another milestone in Indigenous energy leadership. Sky-Deer noted that the project’s co-ownership model required Quebec’s National Assembly to pass Bill 13, a first-of-its-kind legal framework. “That was a breakthrough,” she said, “but it also shows that true partnership still depends on one-off exceptions rather than standard policy.”

Panellists agreed that Canada’s regulatory systems have not kept pace with Indigenous leadership. Fontaine called on governments to “think outside the box to avoid staying stuck in the status quo,” emphasizing the need for enabling policies that align with an electric, connected and clean vision for Canada while making Indigenous-led ownership the norm rather than the exception.

Financial readiness is another key factor driving Indigenous participation. Communities are now accessing capital through partnerships with financial institutions and government loan programs, and growing evidence that a 2035 zero-emissions grid is practical and profitable is strengthening investor confidence. The collaboration between the Mohawk Council of Kahnawà:ke and the Caisse de dépôt et placement du Québec exemplifies tailored financing and long-term investment that supports community ownership and sustainable growth.

True equity, however, goes beyond financial participation. “It’s not just about having a percentage stake,” Fontaine explained. “True equity means meaningful decision-making power and control.” Indigenous leaders are insisting on co-governance structures that align with their worldviews, prioritizing environmental protection, cultural respect, and intergenerational stewardship.

The benefits of this approach extend far beyond project economics. Communities involved in ownership experience tangible local benefits, including employment and training opportunities, as well as new investments in education and culture. Hydro-Québec’s $10 million contribution to the Kahnawà:ke Cultural Arts Center is one example of how partnerships can support cultural renewal and community development.

As Canada looks to build east–west electricity interties and expand renewable energy generation, including solar where Canada has lagged in deployment nationwide, Indigenous leadership is becoming increasingly central to national energy policy. Fontaine noted that this shift offers “even greater opportunities for Indigenous-led transmission as Canada connects its provinces rather than just exporting power south.”

In particular, Alberta's energy profile highlights both rapid growth in renewables and ongoing fossil fuel strength, informing intertie planning and market design.

On the National Truth and Reconciliation Day, panellists urged reflection on both the barriers that remain and the opportunities ahead. Indigenous leadership in Canada’s clean energy sector is proving that reconciliation can take tangible form, through ownership, partnership, and shared prosperity.

This transformation represents more than an energy transition; it’s a rebalancing of power, respect, and responsibility, carried out “in a good way,” as the panellists emphasized, and essential to building a clean, inclusive energy future for all Canadians while strengthening the global electricity market position of the country.

 

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Solar and wind power curtailments are rising in California

CAISO Renewable Curtailments reflect grid balancing under transmission congestion and oversupply, reducing solar and wind output while leveraging WEIM trading, battery storage, and transmission expansion to integrate renewables and stabilize demand-supply.

 

Key Points

CAISO renewable curtailments are reductions in wind and solar output to balance grid amid congestion or oversupply.

✅ Driven mainly by transmission congestion, less by oversupply.

✅ Peaks in spring when demand is low and solar output is high.

✅ Mitigated by WEIM trades, new lines, and battery storage growth.

 

The California Independent System Operator (CAISO), the grid operator for most of the state, is increasingly curtailing solar- and wind-powered electricity generation, as reported in rising curtailments, as it balances supply and demand during the rapid growth of wind and solar power in California.

Grid operators must balance supply and demand to maintain a stable electric system as advances in solar and wind continue to scale. The output of wind and solar generators are reduced either through price signals or rarely, through an order to reduce output, during periods of:

Congestion, when power lines don’t have enough capacity to deliver available energy
Oversupply, when generation exceeds customer electricity demand

In CAISO, curtailment is largely a result of congestion. Congestion-related curtailments have increased significantly since 2019 because California's solar boom has been outpacing upgrades in transmission capacity.

In 2022, CAISO curtailed 2.4 million megawatthours (MWh) of utility-scale wind and solar output, a 63% increase from the amount of electricity curtailed in 2021. As of September, CAISO has curtailed more than 2.3 million MWh of wind and solar output so far this year, even as the US project pipeline is dominated by wind, solar, and batteries.

Solar accounts for almost all of the energy curtailed in CAISO—95% in 2022 and 94% in the first seven months of 2023. CAISO tends to curtail the most solar in the spring when electricity demand is relatively low (because moderate spring temperatures mean less demand for space heating or air conditioning) and solar output is relatively high, although wildfire smoke impacts can reduce available generation during fire season as well.

CAISO has increasingly curtailed renewable generation as renewable capacity has grown in California, and the state has even experienced a near-100% renewables moment on the grid in recent years. In 2014, a combined 9.0 gigawatts (GW) of wind and solar capacity had been built in California. As of July 2023, that number had grown to 17.6 GW. Developers plan to add another 3.0 GW by the end of 2024.

CAISO is exploring and implementing various solutions to its increasing curtailment of renewables, including:

The Western Energy Imbalance Market (WEIM) is a real-time market that allows participants outside of CAISO to buy and sell energy to balance demand and supply. In 2022, more than 10% of total possible curtailments were avoided by trading within the WEIM. A day ahead market is expected to be operational in Spring 2025.

CAISO is expanding transmission capacity to reduce congestion. CAISO’s 2022–23 Transmission Planning Process includes 45 transmission projects to accommodate load growth and a larger share of generation from renewable energy sources.

CAISO is promoting the development of flexible resources that can quickly respond to sudden increases and decreases in demand such as battery storage technologies that are rapidly becoming more affordable. California has 4.9 GW of battery storage, and developers plan to add another 7.6 GW by the end of 2024, according to our survey of recent and planned capacity changes. Renewable generators can charge these batteries with electricity that would otherwise have been curtailed.

 

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What cities can learn from the biggest battery-powered electric bus fleet in North America

Canadian Electric Bus Fleet leads North America as Toronto's TTC deploys 59 battery-electric, zero-emission buses, advancing public transit decarbonization with charging infrastructure, federal funding, lower maintenance, and lifecycle cost savings for a low-carbon urban future.

 

Key Points

Canada's leading battery-electric transit push, led by Toronto's TTC, scaling zero-emission buses and charging.

✅ Largest battery-electric bus fleet in North America

✅ TTC trials BYD, New Flyer, Proterra for range and reliability

✅ Charging infrastructure, funding, and specs drive 2040 zero-emissions

 

The largest battery-powered electric bus fleet in North America is Canadian. Toronto's transit system is now running 59 electric buses from three suppliers, and Edmonton's first electric bus is now on the road as well. And Canadian pioneers such as Toronto offer lessons for other transit systems aiming to transition to greener fleets for the low-carbon economy of the future.

Diesel buses are some of the noisier, more polluting vehicles on urban roads. Going electric could have big benefits, even though 18% of Canada's 2019 electricity from fossil fuels remains a factor.

Emissions reductions are the main reason the federal government aims to add 5,000 electric buses to Canada's transit and school fleets by the end of 2024. New funding announced this week as part of the government's fall fiscal update could also give programs to electrify transit systems a boost.

"You are seeing huge movement towards all-electric," said Bem Case, the Toronto Transit Commission's head of vehicle programs. "I think all of the transit agencies are starting to see what we're seeing ... the broader benefits."

While Vancouver has been running electric trolley buses (more than 200, in fact), many cities (including Vancouver) are now switching their diesel buses to battery-electric buses in Metro Vancouver that don't require overhead wires and can run on regular bus routes.

The TTC got approval from its board to buy its first 30 battery-electric buses in November 2017. Its plan is to have a zero-emissions fleet by 2040.

That's a crucial part of Toronto's plan to meet its 2050 greenhouse gas targets, which requires 100 per cent of vehicles to transition to low-carbon energy by then.

But Case said the transition can't happen overnight. 


Finding the right bus
For one thing, just finding the right bus isn't easy.

"There's no bus, by any manufacturer, that's been in service for the entire life of a bus, which is 12 years," Case said.

"And so really, until then, we don't have enough experience, nor does anyone else in the industry, have enough experience to commit to an all-electric fleet immediately."

In fact, Case said, there are only three manufacturers that make suitable long-range buses — the kind needed in a city the size of Toronto.

Having never bought electric buses before, the city had no specifications for what it needed in an electric bus, so it decided to try all three suppliers: Winnipeg-based New Flyer; BYD, which is headquartered in Shenzhen, China, but built the TTC buses at its Newmarket, Ont. facility; and California-based Proterra.

They all had their strengths and weaknesses, based on their backgrounds as a traditional non-electric bus manufacturer, a battery maker and a vehicle technology and design startup, respectively.

"Each bus type has its own potential challenges." Case said all three manufacturers are working to resolve any adoption challenges as quickly as possible.

But the biggest challenge of all, Case said, is getting the infrastructure in place. 

"There's no playbook, really, for implementing charging infrastructure," he said.

Each bus type needed their own chargers, in some cases using different types of current. Each type has been installed in a different garage in partnership with local utility Toronto Hydro.

Buying and installing them represented about $70 million, or about half the cost of acquiring Toronto's first 60 electric buses. The $140 million project was funded by the federal Public Transit Infrastructure Fund.

Case said it takes about three hours to charge a battery that has been fully depleted. To maximize use of the bus, it's typically put on a long route in the morning, covering 200 to 250 kilometres. Then it's partially charged and put on a shorter run in the late afternoon.

"That way we get as much mileage on the buses as we can."


Cost and reliability?
Besides the infrastructure cost of chargers, each electric bus can cost $200,000 to $500,000 more per bus than an average $750,000 diesel bus. 

Case acknowledges that is "significantly" more expensive, but it is offset by fuel savings over time, as electricity costs are cheaper. Because the electric buses have fewer parts than diesel buses, maintenance costs are also about 25 per cent lower and the buses are expected to be more reliable.

As with many new technologies, the cost of electric buses is also falling over time.

Case expects they will eventually get to the point where the total life-cycle cost of an electric and a diesel bus are comparable, and the electric bus may even save money in the long run.

As of this fall, all but one of the 60 new electric buses have been put into service. The last one is expected to hit the road in early December.

Summer testing showed that air conditioning the buses reduced the battery capacity by about 15 per cent. 

But the TTC needs to see how much of the battery capacity is consumed by heating in winter, at least when the temperature is above 5 C. Below that, a diesel-powered heater kicks in.

Once testing is complete, the TTC plans to develop specifications for its electric bus fleet and order 300 more in 2023, for delivery between 2023 and 2025.


Potential benefits
Even with some diesel heating, the TTC estimates electric buses reduce fuel usage by 70 to 80 per cent. If its whole fleet were switched to electric buses, it could save $50 million to $70 million in fuel a year and 150 tonnes of greenhouse gases per bus per year, or 340,000 tonnes for the entire fleet.

Other than greenhouse gases, electric buses also generate fewer emissions of other pollutants. They're also quieter, creating a more comfortable urban environment for pedestrians and cyclists.

But the benefits could potentially go far beyond the local city.

"If the public agencies start electrifying their fleet and their service is very demanding, I think they'll demonstrate to the broader transportation industry that it is possible," Case said.

"And that's where you'll get the real gains for the environment."

Alex Milovanoff, a postdoctoral researcher in the University of Toronto's department of civil engineering, did a U of T EV study that suggested electrified transit has a crucial role to play in the low-carbon economy of the future.

His calculations show that 90 per cent of U.S. passenger vehicles — 300 million — would need to be electric by 2050 to reach targets under the global Paris Agreement to fight climate change.

And that would put a huge strain on resources, including both the mining of metals, such as lithium and cobalt, that are used in electric vehicle batteries and the electrical grid itself.

A better solution, he showed, was combining the transition to electric vehicles with a reduction in the number of private vehicles, and higher usage of transit, cycling and walking.

"Then that becomes a feasible picture," he said.

What's needed to make the transition
But in order to make that happen, governments need to make investments and navigate the 2035 EV mandate debate on timelines, he added.

That includes subsidies for buying electric buses and building charging stations so transit agencies don't need to make fares too high. But it also includes more general improvements to the range and reliability of transit infrastructure.

"Electrifying the bus fleet is only efficient if we have a large public transit fleet and if we have many buses on the road and if people take them," Milovanoff said.

In its fall economic update on Monday, the federal government announced $150 million over three years to speed up the installation of zero-emission vehicle infrastructure.

Josipa Petrunic, CEO of the Canadian Urban Transit Research and Innovation Consortium, a non-profit organization focused on zero-carbon mobility and transportation, said that in the past, similar funding has paid for high-powered charging systems for transit systems in B.C. and Ontario. But that's only a small part of what's needed, she said.

"Infrastructure Canada needs to come to the table with the cash for the buses and the whole rest of the system."

She said funding is needed for:

Feasibility studies to figure out how many and what kinds of buses are needed for different routes in different transit systems.

Targets and incentives to motivate transit systems to make the switch.

Incentives to encourage Canadian procurement to build the industry in Canada.

Technology to collect and share data on the performance of electric vehicles so transit systems can make the best-possible decisions to meet the needs of their riders.

Petrunic said that a positive side-effect of electrifying transit systems is that the infrastructure can support, in addition to buses, electric trucks for moving freight.

"It's not a lot given that we have 15,000 buses out there in the transit fleet," she said.

"But we should be able to get a lot further ahead if we match the city commitments to zero emissions with federal and provincial funding for jobs creating zero-emissions technologies."

 

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