Electrifying GO train system to be studied

By Toronto Star


NFPA 70e Training

Our customized live online or in‑person group training can be delivered to your staff at your location.

  • Live Online
  • 6 hours Instructor-led
  • Group Training Available
Regular Price:
$199
Coupon Price:
$149
Reserve Your Seat Today
Metrolinx will mount an unprecedented study of electrifying the entire GO train system, including the controversial Georgetown line.

Expected to cost more than $2 million, the study is the most comprehensive in GO's history, say transit officials, who are under pressure from the community concerned about diesel pollution to electrify the Georgetown line, due for a $1 billion expansion. The expansion is necessary for GO to offer two-way, all-day service to Brampton and Georgetown and to run a rail link between Union Station and Pearson airport.

This will be the first broad look at the health and community impacts, as well as the economics of electrification, Metrolinx officials said at a board meeting. Earlier studies examined electrifying the Lakeshore line only and focused on the cost of electric versus diesel.

This latest study will also consider alternative rail technologies.

But whether electric trains or clean diesel locomotives run up the expanded Georgetown corridor, it will be years before commuters in Brampton and Georgetown see all-day, two-way service, said Gary McNeil, managing director of GO, which has merged with Metrolinx.

Despite a Metrolinx report projecting 59 GO trains running up the corridor to Georgetown in 2015 when the expansion opens, McNeil said only 10 additional trains might be added to the existing 19.

About 460 trains are expected to use the lower ends of the corridor when expansion is complete, including about 140 that will provide a rail link between Union Station and Pearson, and those that branch off to Bolton, Barrie and Milton.

The study, to be finished next December, is critical for GO to make the business case for electrification in the future, which transit officials have been looking at for 30 years on the Lakeshore line, said McNeil.

Many Toronto residents living along the Georgetown line tracks say the study is a waste of time and money. A 2009 GO analysis showed it would cost about $1 billion to electrify the Lakeshore line.

But that outlay would be offset by $100 million in annual operational savings, said Keith Brooks of the Clean Train Coalition, which opposes diesel trains on the Georgetown line.

"That study clearly indicated this is the best economic case, not to mention all the environmental and health impacts," he said.

Related News

Energy minister unveils Ontario's plan to address growing energy needs

Powering Ontario's Growth accelerates clean electricity, pairing solar, wind, and hydro with energy storage, efficiency investments, and new nuclear, including SMRs, to meet rising demand and net-zero goals while addressing supply planning across the province.

 

Key Points

Ontario's clean energy plan adds renewables, storage, efficiency, and nuclear to meet rising electricity demand.

✅ Over $1B for energy-efficiency programs through 2030+

✅ Largest clean power procurement in Canadian history

✅ Mix of solar, wind, hydro, storage, nuclear, and SMRs

 

Energy Minister Todd Smith has announced a new plan that outlines the actions the government is taking to address the province's growing demand for electricity.

The government is investing over a billion dollars in "energy-efficiency programs" through 2030 and beyond, Smith said in Windsor.

Experts at Ontario's Independent Electricity System recommended the planning start early to meet demand they predict will require the province to be able to generate 88,000 megawatts (MW) in 20 years.

"That means all of our current supply ... would need to double to meet the anticipated demand by 2050," he said during the announcement.

"While we may not need to start building today, government and those in the energy sector need to start planning immediately, so we have new clean, zero emissions projects ready to go when we need them."

The project is called Powering Ontario's Growth and will advance new clean energy generation from a number of sources, including solar, hydroelectric and wind.

He said this would be the biggest acquisition of clean energy in Canada's history.

Smith made the announcement at Hydro One's Keith Transmission Station.

He said the new planned procurement of green power will pair well with recent energy storage procurements, so that power generated by solar panels, for example, can be stored and injected into the system when needed.

NDP Opposition Leader Marit Stiles said Monday's announcement lacks specifics.

"It's light on details, including key questions of cost, climate impact, waste management and financial risk," said Stiles.

"Ford's Conservatives should be playing catch-up after undermining clean energy in their first term. Instead, they're offering generalities and a vague sense of what they might do."

The Green Party criticized the move Monday afternoon, noting that clean, affordable electricity remains a key Ontario election issue today.

"Ontario is facing an energy crunch – and the Ford government is making it worse by choosing more expensive, dirtier options," said MPP for Guelph Mike Schreiner in the statement.

He said Premier Doug Ford has "grossly" mismanaged the province's energy supply by cancelling 750 renewable energy projects and slashing efficiency programs.

"Now, faced with an opportunity to become a leader in a world that's rapidly embracing renewable energy, this government has chosen to funnel taxpayer dollars into polluting fossil gas plants and expensive new nuclear that will take decades to come online," said Schreiner.

Smith announced last week the plan for three more small modular reactors at the site of the Darlington nuclear power plant. The province also shared its intention to add a third nuclear generating station to Bruce Power near Kincardine. 

"With this backwards approach, the Ford government is squandering a once-in-a-generation opportunity to make Ontario a global leader in attracting investment dollars and creating better jobs in the trillion-dollar clean energy sector," said Schreiner.

 

Related News

View more

ERCOT Issues RFP to Procure Capacity to Alleviate Winter Concerns

ERCOT Winter Capacity RFP seeks up to 3,000 MW through generation and demand response to bolster Texas grid reliability during peak load, leveraging Reliability Must-Run, incentive factors, and EEA risk mitigation for the 2023-24 season.

 

Key Points

An ERCOT initiative to procure 3,000 MW of generation and demand response to reduce EEA risk and improve reliability.

✅ Targets 3,000 MW from generation and demand response

✅ Uses RMR-style contracts with flexible incentive factors

✅ Aims to lower EEA probability below 10% this winter

 

The Electric Reliability Council of Texas (ERCOT) issued a request for proposals to stakeholders to procure up to 3,000 MW of generation or demand response capacity to meet load and reserve requirements during the winter 2023-24 peak load season (Dec. 1, 2023, through Feb. 29, 2024), amid ongoing Texas power grid challenges across the region.

ERCOT cited “several factors, including significant peak load growth since last winter, recent and proposed retirements of dispatchable Generation Resources, and recent extreme winter weather events, including Winter Storm Elliott in December 2022, Winter Storm Uri in February 2021, and the 2018 and 2011 winter storms, each of which resulted in abnormally high demand during winter weather.” It now seeks additional capacity under its “authority to prevent an anticipated Emergency Condition,” reflecting nationwide blackout risks identified by grid experts.

In its notice regarding the RFP, ERCOT identified a number of mothballed and recently decommissioned generation resources that may be eligible to offer capacity under the RFP. It further stated that offers must comport with the format of its “Reliability Must-Run” agreement but could include a proposed “Incentive Factor” that reflects the revenues the unit owners determine would be necessary to bring the unit back to operation. It added that the Incentive Factor is not necessarily limited to 10%. Providers of eligible demand response can submit offers based on similar principles that are not necessarily constrained by cost. The notice identifies potential acceptable sources of demand response, describes certain parameters for the kinds of demand response that are permitted to respond to the RFP, and outlines the time periods during which ERCOT must be able to deploy the demand response resources to improve electricity reliability across the system.

To meet the Dec. 1, 2023, service start date, ERCOT developed an aggressive timeline to solicit and evaluate proposals through the RFP. Responses to the RFP are due Nov. 6, 2023. ERCOT’s schedule provides that it will notify market participants that obtain awards on Nov. 23, 2023. Expect contracts to be executed by Nov. 30, 2023.

Unlike Regional Transmission Organizations in the Northeastern United States, ERCOT does not have a capacity market. Instead, ERCOT relies on a high price cap of $5,000 per MWh for its energy market (decreased from the $9,000 per MWh cap in effect during Winter Storm Uri) and an Operating Reserve Demand Curve adder that pays additional funds to generators supplying power and ancillary services, an area recently scrutinized for improper payments when supply conditions are tight. In the wake of Winter Storm Uri, some calls were made to have ERCOT adopt a capacity market for reliability reasons, and a number of legal battles continue to play out in the wake of Winter Storm Uri. (See recent McGuireWoods legal alert “Winter Storm Uri Power Dispute Reaches the Supreme Court of Texas.”) Though a capacity market was not adopted, the Texas Legislature approved a $7.2 billion loan program, widely described as an electricity market bailout for generators, to build up to 10,000 MW of dispatchable generation. The legislature also approved a version of the Public Utility Commission of Texas’ proposal to establish a “Performance Credit Mechanism,” but with a cost cap of $1 billion.

The loss of life and economic impacts of Winter Storm Uri in 2021, along with the energy crunches and calls for conservation this past summer, are driving changes to ERCOT’s “energy-only” market, including electricity market reforms under consideration. Texas policymakers are providing multiple financial incentives to promote investment in dispatchable on-demand generation, and voters will consider funding to modernize generation measures this year to make the Texas grid more reliable and able to deal with power demand from a growing economy and increased demand for electricity driven by weather. In the meantime, ERCOT’s plan to procure 3,000 MW through this RFP process is a stopgap measure intended to bolster reliability for the upcoming winter season and lower the probability of load shed in the event of severe winter weather.

 

Related News

View more

Energy Vault Lands $110M From SoftBank’s Vision Fund for Gravity Storage

Energy Vault Gravity Storage uses crane-stacked concrete blocks to deliver long-duration, grid-scale renewable energy; a SoftBank Vision Fund-backed, pumped-hydro analog enabling baseload power and a lithium-ion alternative with proprietary control algorithms.

 

Key Points

Gravity-based cranes stack blocks to store and dispatch power for hours, enabling grid-scale, low-cost storage.

✅ 4 MW/35 MWh modules; ~9-hour duration

✅ Estimated $200-$250/kWh; lower LCOE than lithium-ion

✅ Backed by SoftBank Vision Fund; Cemex and Tata support

 

Energy Vault, the Swiss-U.S. startup that says it can store and discharge electrical energy through a super-sized concrete-and-steel version of a child’s erector set, has landed a $110 million investment from Japan’s SoftBank Vision Fund to take its technology to commercial scale.

Energy Vault, a spinout of Pasadena-based incubator Idealab and co-founded by Idealab CEO and billionaire investor Bill Gross, unstealthed in November with its novel approach to using gravity to store energy.

Simply put, Energy Vault plans to build storage plants — dubbed “Evies” — consisting of a 35-story crane with six arms, surrounded by a tower consisting of thousands of concrete bricks, each weighing about 35 tons.

This plant will “store” energy by using electricity to run the cranes that lift bricks from the ground and stack them atop of the tower, and “discharge” energy by reversing that process. It’s a mechanical twist on the world’s most common energy storage technology, pumped hydro, which “stores” energy by pumping water uphill, and lets it fall to spin turbines when electricity is needed, even as California funds 100-hour long-duration storage pilots to expand flexibility worldwide.

But behind this simplicity lies some heavy-duty software to orchestrate the cranes and blocks, with a "unique stack of proprietary algorithms" to balance energy supply and demand, volatility, grid stability, weather elements and other variables.

CEO and co-founder Robert Piconi said in a November interview with GTM that the standard array would deliver 4 megawatts/35 megawatt-hours of storage, which translates to nearly 9 hours of duration — the equivalent of building the tower to its height, and then reducing it to ground level. It can be built on-site in partnership with crane manufacturers and recycled concrete material, and can run fully automated for decades with little deterioration, he said.

And the cost, which Piconi pegged in the $200 to $250 per kilowatt-hour range, with room to decline further, is roughly 50 percent below the upfront price of the conventional storage market today, and 80 percent below it on levelized cost, he said, a trend utilities see benefits in as they plan resources.

The result, according to Wednesday’s statement, is a technology that could allow “renewables to deliver baseload power for less than the cost of fossil fuels 24 hours a day,” in applications such as community microgrids serving low-income housing.

Wednesday’s announcement builds on a recent investment from Mexico's Cemex Ventures, the corporate venture capital unit of building materials giant Cemex, along with a promise of deployment support from Cemex's strategic network, and also follows project financing for a California green hydrogen microgrid led by the company. Piconi said in November that the company had sufficient investment from two funding rounds to carry it through initial customer deployments, though he declined to disclose figures.

This is the first energy storage investment for Vision Fund, the $100 billion venture fund set up by SoftBank founder Masayoshi Son. While large by startup standards, it’s in keeping with the capital costs that Energy Vault will face in scaling up its technology to meet its commitments, amid mounting demand in regions like Ontario energy storage that face supply crunches. Those include a 35 megawatt-hour order with Tata Power Company, the energy-producing arm of the Indian industrial conglomerate, first unveiled in November, as well as plans to demonstrate its first storage tower in northern Italy in 2019.

For Vision Fund, it’s also an unusual choice for a storage investment, given that the vast majority of venture capital in the industry today is being directed toward lithium-ion batteries, and even Mercedes-Benz energy storage ventures targeting the U.S. market. Lithium-ion batteries are limited in terms of how many hours they can provide cost-effectively, with about 4 hours being seen as the limit today.

The search for long-duration energy storage has driven investment into flow battery technologies such as grid-scale vanadium systems deployed on utility networks, compressed-air energy storage and variations on gravity-based storage, including a previous startup backed by Gross and Idealab, Energy Cache, whose idea of using a ski lift carrying buckets of gravel up a hill to store energy petered out with a 50-kilowatt pilot project.

 

Related News

View more

Power Outage Disrupts Travel at BWI Airport

BWI Power Outage caused flight delays, cancellations, and diversions after a downed power line near Baltimore/Washington International. BGE crews responded as terminal operations, security screening, and boarding slowed, exposing infrastructure gaps and backup power needs.

 

Key Points

A downed power line disrupted BWI, causing delays, diversions, and slowed operations after power was restored by noon.

✅ Downed power line near airport spurred terminal-wide disruptions

✅ 150+ delays, dozens of cancellations; diversions to nearby airports

✅ BGE response, backup power gaps highlight infrastructure resilience

 

On the morning of March 3, 2025, a major power outage at Baltimore/Washington International Thurgood Marshall Airport (BWI) caused significant disruptions to air travel, much like the London morning outage that upended routines, affecting both departing and incoming flights. The outage, which began around 7:40 a.m., was caused by a downed power line near the airport, according to officials from Baltimore Gas and Electric Company. Although power was restored by noon, the effects were felt for several hours, resulting in flight delays, diversions, and a temporary disruption to airport operations.

Flight Disruptions and Delays

The outage severely impacted operations at BWI, with more than 150 flights delayed and dozens more canceled. The airport, which serves as a major hub for both domestic and international travel, was thrown into chaos, similar to the Atlanta airport blackout that snarled operations, as power outages affected various critical areas, including parts of the main terminal and an adjacent parking garage. The downed power line created a ripple effect throughout the airport’s operations, delaying not only the check-in and security screening processes but also the boarding of flights. In addition to the delays, some inbound flights had to be diverted to nearby airports, further complicating an already strained travel schedule.

With the disruption affecting vital functions of the airport, passengers were advised to stay in close contact with their airlines for updated flight statuses and to prepare for longer-than-usual wait times.

Impact on Passengers

As power began to return to different parts of the terminal, airport officials reported that airlines were improvising solutions to continue the deplaning process, such as using air stairs to help passengers exit planes that were grounded due to the power outage, a reminder of how transit networks can stall during grid failures, as seen with the London Underground outage that frustrated commuters. This created further delays for passengers attempting to leave the airport or transfer to connecting flights.

Many passengers, who were left stranded in the terminal, faced long lines at ticket counters, security checkpoints, and concessions as the airport worked to recover from the loss of power, a situation mirrored during the North Seattle outage that affected thousands. The situation was compounded by the fact that while power was restored by midday, the airport still struggled to return to full operational capacity, creating significant inconvenience for travelers.

Power Restoration and Continued Delays

By around noon, officials confirmed that power had been fully restored across the main terminal. However, the full return to normalcy was far from immediate. Airport staff continued to work on clearing backlogs and assisting passengers, but the effects of the outage lingered throughout the day. Passengers were warned to expect continued delays at ticket counters, security lines, and concessions as the airport caught up with the disruption caused by the morning’s power outage.

For many travelers, the experience was a reminder of how dependent airports and airlines are on uninterrupted power to function smoothly. The disruption to BWI serves as a case study in the potential vulnerabilities of critical infrastructure that is not immune to the effects of power failure, including weather-driven events like the windstorm outages that can sever lines. Moreover, it highlights the difficulties of recovering from such incidents while managing the expectations of a large number of stranded passengers.

Investigations into the Cause of the Outage

As of the latest reports, Baltimore Gas and Electric Company (BGE) crews were still investigating the cause of the power line failure, including weather-related factors seen when strong winds in the Miami Valley knocked out power. While no definitive cause had been provided by early afternoon, BGE spokesperson Stephanie Weaver confirmed that the company was working diligently to restore service. She noted that the downed line had caused widespread disruptions to electrical service in the area, which were exacerbated by the airport’s significant reliance on a stable power supply.

BWI officials remained in close contact with BGE to monitor the situation and ensure that necessary precautions were taken to prevent further disruptions. With power largely restored by midday, focus turned to the logistical challenges of clearing the resulting delays and assisting passengers in resuming their travel plans.

Response from the Airport and Airlines

In response to the power outage, BWI officials encouraged travelers to remain patient, a familiar message during prolonged events like Houston's extended outage in recent months, and continue checking their flight statuses. Although flight tracking websites and social media posts provided timely updates, passengers were urged to expect long delays throughout the day as the airport struggled to return to full capacity.

Airlines, for their part, worked swiftly to accommodate affected passengers, although the situation created a ripple effect across the airport's operations. With delayed flights and diverted planes, air traffic control and ground crews had to adjust flight schedules accordingly, resulting in even more congestion at the airport. Airlines coordinated with the airport to prioritize urgent cases, and some flights were re-routed to other nearby airports to mitigate the strain on the terminal.

Long-Term Effects on Airport Infrastructure

This incident underscores the importance of maintaining resilient infrastructure at key transportation hubs like BWI. Airports are vital nodes in the air travel network, and any disruption, whether from power failure or other factors, can have far-reaching consequences on both domestic and international travel. Experts suggest that BWI and other major airports should consider implementing backup power systems and other safeguards to ensure that they can continue to function smoothly during unforeseen disruptions.

While BWI officials were able to resolve the situation relatively quickly, the power outage left many passengers frustrated and inconvenienced. This incident serves as a reminder of the need for airports and utilities to have robust contingency plans in place to handle emergencies and prevent delays from spiraling into more significant disruptions.

The power outage at Baltimore/Washington International Airport highlights the vulnerability of critical infrastructure to power failures and the cascading effects such disruptions can have on travel. Although power was restored by noon, the delays, diversions, and logistical challenges faced by passengers underscore the need for greater resilience in airport operations. With travel back on track, BWI and other airports will likely revisit their contingency plans to ensure that they are better prepared for future incidents that could affect air travel.

 

Related News

View more

Ontario confronts reality of being short of electricity in the coming years

Ontario electricity shortage is looming, RBC and IESO warn, as EV electrification surges, Pickering nuclear faces delays, and gas plants backstop expiring renewables, raising GHG emissions and grid reliability concerns across the province.

 

Key Points

A projected supply shortfall as demand rises from electrification, expiring contracts, and delayed nuclear capacity.

✅ RBC warns shortages as early as 2026, significant by 2030

✅ IESO sees EV-driven demand; 5,000-15,000 MW by 2035

✅ Gas reliance boosts GHGs; Pickering life extension assessed

 

In a fit of ideological pique, Doug Ford’s government spent more than $200 million to scrap more than 700 green energy projects soon after winning the 2018 election, amid calls to make clean, affordable power a central issue, portraying them as “unnecessary and expensive energy schemes.”

A year later, then Associate Energy Minister Bill Walker defended the decision, declaring, “Ontario has an adequate supply of power right now.”

Well, life moves fast. At the time, scrapping the renewable energy projects was criticized as short-sighted and wasteful, raising doubts about whether Ontario was embracing clean power in a meaningful way. It seems especially so now as Ontario confronts the reality of being short of electricity in the coming years.

How short? A recent report by RBC calls the situation “urgent,” saying that Canada’s most populous province could face energy shortages as early as 2026. As contracts for non-hydro renewables and gas plants expire, the shortages could be “significant” by 2030, the bank report said, with grid greening costs adding to the challenge.

The Independent Electricity System Operator (IESO), which manages the electrical supply in Ontario, says demand for electricity could rise at rates not seen in many years, as the government moves to add new gas plants to boost capacity. “Economic growth coming out of the pandemic, along with electrification in many sectors, is driving energy use up,” the agency said in a December assessment.

The good news is that demand is being driven, in part, by the transition to “green” power – carbon-emission-free electricity – by sectors such as transportation and manufacturing. That will help reduce emissions. Yet meeting that demand presents some challenges, prompting the province to outline a plan to address growing needs across the system. The shift to electric vehicles alone is expected to cause a spike in demand starting in 2030. By 2035, the province could need an additional 5,000 to 15,000 megawatts of electricity, the IESO estimates.

It was perhaps no surprise then to see the province announce last week that it wants to delay the long-planned closing of the Pickering nuclear plant by a year to 2026, even as others note the station is slated to close as planned. Operations beyond that would require refurbishing the facility. The province said it’s taking a fresh look at whether that would make sense to extend its life by another 30 years.

In the interim, the province will be forced to dramatically ramp up its reliance on natural gas plants for electricity generation – and, as analysts warn, Ontario’s power mix could get dirtier even before new non-emitting capacity is built, and in the process, increase greenhouse gas emissions from the energy grid by 400 per cent. Broader electrification is expected to produce “significant” GHG emissions reductions in Ontario over the next two decades, according to the IESO. Still, it’s working at cross-purposes if your electric car is charged by electricity generated by fossil fuels.

 

Related News

View more

Duke Energy Florida's smart-thinking grid improves response, power restoration for customers during Hurricane Ian

Self-healing grid technology automatically reroutes power to reduce outages, speed restoration, and boost reliability during storms like Hurricane Ian in Florida, leveraging smart grid sensors, automation, and grid hardening to support Duke Energy customers.

 

Key Points

Automated smart grid systems that detect faults and reroute power to minimize outages and accelerate restoration.

✅ Cuts outage duration via automated fault isolation

✅ Reroutes electricity with sensors and distribution automation

✅ Supports storm resilience and faster field crew restoration

 

As Hurricane Ian made its way across Florida, where restoring power in Florida can take weeks in hard-hit areas, Duke Energy's grid improvements were already on the job helping to combat power outages from the storm.

Smart, self-healing technology, similar to smart grid improvements elsewhere, helped to automatically restore more than 160,000 customer outages and saved nearly 3.3 million hours (nearly 200 million minutes) of total lost outage time.

"Hurricane Ian is a strong reminder of the importance of grid hardening and storm preparedness to help keep the lights on for our customers," said Melissa Seixas, Duke Energy Florida state president. "Self-healing technology is just one of many grid improvements that Duke Energy is making to avoid outages, restore service faster and increase reliability for our customers."

Much like the GPS in your car can identify an accident ahead and reroute you around the incident to keep you on your way, self-healing technology is like a GPS for the grid. The technology can quickly identify power outages and alternate energy pathways to restore service faster for customers when an outage occurs.

Additionally, self-healing technology provides a smart tool to assist crews in the field with power restoration after a major storm like Ian, helping reduce outage impacts and freeing up resources to help restore power in other locations.

Three days after Hurricane Ian exited the state, Duke Energy Florida wrapped up restoration of approximately 1 million customers. This progress enabled the company to deploy more than 550 Duke Energy workers from throughout Florida, as well as contractors from across the country, to help restore power for Lee County Electric Cooperative customers.

Crews worked in Cape Coral and Pine Island, one of the hardest-hit areas in the storm's path, as Canadian power crews have in past storms, and completed power restoration for the majority of customers on Pine Island within approximately one week after arriving to the island.

Prior to Ian in 2022, smart, self-healing technology had helped avoid nearly 250,000 extended customer outages in Florida, similar to Hydro One storm recovery efforts, saving around 285,000 hours (17.1 million minutes) of total lost outage time.

Duke Energy currently serves around 59% of customers in Florida with self-healing capabilities on its main power distribution lines, with a goal of serving around 80% over the next few years.

 

Related News

View more

Sign Up for Electricity Forum’s Newsletter

Stay informed with our FREE Newsletter — get the latest news, breakthrough technologies, and expert insights, delivered straight to your inbox.

Electricity Today T&D Magazine Subscribe for FREE

Stay informed with the latest T&D policies and technologies.
  • Timely insights from industry experts
  • Practical solutions T&D engineers
  • Free access to every issue

Live Online & In-person Group Training

Advantages To Instructor-Led Training – Instructor-Led Course, Customized Training, Multiple Locations, Economical, CEU Credits, Course Discounts.

Request For Quotation

Whether you would prefer Live Online or In-Person instruction, our electrical training courses can be tailored to meet your company's specific requirements and delivered to your employees in one location or at various locations.