OEB approves transmission line from Bruce to Milton

By Canada News Wire


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The Ontario Energy Board approved Hydro One's application for leave to construct approximately 180 kilometres of a double-circuit 500 kilovolt transmission line extending from the Bruce Power Facility in Kincardine Township to Hydro One's Milton Switching Station in the town of Milton, with conditions.

The transmission line will run adjacent to the existing transmission corridor (500 kV or 230 kV) and is expected to be in service by Year 2011.

Hydro One submitted that the project is required to meet the increased need for transmission capacity associated with the development of wind power in the Bruce area and the return to service of nuclear units at the Bruce Nuclear Generating Station.

In its decision, the Board found the project to be in the public interest in regard to its impact on price, reliability and quality of electricity service to consumers. As well, the Board found that the economic benefits of the transmission line exceed its estimated costs of $635 million, and that it improves system reliability, which benefits all electricity consumers.

The Board's approval is subject to a number of conditions. Most notable is the Minister of the Environment's approval of the Environmental Assessment.

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Edmonton's 1st electric bus hits city streets

Edmonton Electric Buses usher in zero-emission public transit with Proterra battery-electric vehicles, 350 km range, quiet rides, winter-ready performance, and overhead depot chargers, as ETS rolls out Canada's largest electric fleet across city routes.

 

Key Points

Battery-electric ETS vehicles from Proterra deliver zero-emission service, 350 km range, and winter-capable operation.

✅ Up to 350 km per charge; overhead depot fast chargers

✅ Quiet, smooth rides; zero tailpipe emissions

✅ Winter-tested performance across ETS routes

 

Your next trip on Edmonton transit could be a historical one as the city’s first battery-electric bus is now on city streets, marking a milestone for Edmonton Transit Service, and neighboring St. Albert has also introduced electric buses as part of regional goals.

“Transit has been around since 1908 in Edmonton. We had some really small buses, we had some trolley buses several years later. It’s a special day in history today,” Ryan Birch, acting director of transit operations, said. “It’s a fresh experience… quiet, smooth riding. It’s going to be absolutely wonderful.”

In a news release, Mayor Don Iveson called it the largest purchase of electric buses in Canadian history, while North America's largest electric bus fleet operates in Toronto today, and Metro Vancouver has buses on the road as well this year.

“Electric buses are a major component of the future of public transit in our city and across Canada.”

As of Tuesday, 21 of the 40 electric buses had arrived in the city, and the Toronto Transit Commission has introduced battery-electric buses in Toronto as well this year.

“We’re going to start rolling these out with four or five buses per day until we’ve got all the buses in stock rolled out. On Wednesday we will have three or four buses out,” Birch said.

The remaining 19 are scheduled to arrive in the fall.

The City of Edmonton ordered the battery-electric buses from Proterra, an electric bus supplier, while Montreal's STM has begun rolling out electric buses of its own recently.

The fleet can travel up to 350 kilometres on a single charge and the batteries work in all weather conditions, including Edmonton’s harsh winters, and electric school buses in B.C. have also taken to the roads in cold climates recently.

In 2015, ETS winter tested a few electric buses to see if the technology would be suitable for the city’s climate and geography amid barriers to wider adoption that many agencies consider.

“These buses are designed to handle most of our routes,” Birch said. “We are confident they will be able to stand up to what we expect of them.”

ETS is the first transit agency in North America to have overhead chargers installed inside transit facilities, which helps to save floor space.

 

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Advanced Reactors Will Stand On The Shoulders Of Giants

Advanced Nuclear Reactors redefine nuclear energy with SMRs, diverse fuels, passive safety, digital control rooms, and flexible heat and power, pairing veteran operator expertise with cost-efficient, carbon-free electricity for a resilient grid.

 

Key Points

SMR-based advanced reactors with passive cooling and digital controls deliver flexible power and process heat.

✅ Veteran operators transfer proven safety culture and risk management.

✅ SMRs, passive safety, and digital controls simplify operations.

✅ Flexible output: electricity, process heat, and grid support.

 

Advanced reactors will break the mold of what we think next-gen nuclear power can accomplish: some will be smaller, some will use different kinds of fuel and others will do more than just make electricity. This new technology may seem like uncharted waters, but when operators, technicians and other workers start up the first reactors of the new generation, they will bring with them years of nuclear experience to run machines that have been optimized with lessons from the current fleet.

While advanced reactors are often portrayed as the future of nuclear energy, and atomic energy is heating up across markets, its our current plants that have paved the way for these exciting innovations and which will be workhorses for years to come.

 

Reactor Veterans Bring Their Expertise to New Designs

Many of the workers who will operate the next generation of reactors come from a nuclear background. Even though the design of an advanced reactor may be different, the experience and instincts these operators have gained from working at the current fleet will help new plants get off to a more productive start.

They have a questioning attitude; they are always exploring what could go wrong and always understanding the notion of risk management in nuclear operations, whether its the oldest design or the newest design, said Chip Pardee, the president of Terrestrial Energy USA, who is the former chief operating officer at two nuclear utilities, Exelon Corp. and the Tennessee Valley Authority.

They have respect for the technology and a bias towards conservative decision-making.

Jhansi Kandasamy, vice president of engineering at GE Hitachi Nuclear Energy, agrees. She said that the presence of industry veterans will benefit the new modelslike the 300 megawatt boiling water reactor her company is developing.

From the beginning, a new reactor will have people who have touched it, worked on it, and experienced it, she said.

Theyre going to be able to tell you if something doesnt look right, because theyve lived through it.

 

Experience Informs New Reactor Design

Advanced reactors are designed by engineers who are fully familiar with existing plants and can use that experience to optimize the new ones, like a family building a house and wanting the kitchen just so. New reactors will be simpler to operate because of insights gained from years of operations of the current fleet, and some designs even integrate molten salt energy storage to enhance flexibility.

NuScale Power LLC, for example, has a very different design from the current fleet amid an advanced nuclear push that is reshaping development: up to 12 small reactorsinstead of one or two large reactorsmanaged from a single digital control roominstead of one full of analog switches and dials. When the company designed its control room, it brought in industry veterans who had collectively worked at more than two dozen nuclear plants.

The experts that NuScale brought in critiqued everything, even down to the shape of the symbols on the computer screens to make them easier to read for operators who sometimes need to quickly interpret lots of incoming data. The control panels for NuScales small modular reactor (SMR) present information according to its importance and automatically call up appropriate procedures for operators.

Many advanced reactors are also smaller than those currently operating, which makes their components simpler and less expensive. Kandasamy pointed out that the giant mechanical pumps in todays reactors generate a lot of heat and require a lot of supporting systems, including air conditioning in the rooms that house them.

GE Hitachis SMR design relies more on passive cooling so it needs fewer pumps, and those that remain use magnets, so they generate less heat. Fewer, smaller pumps means a smaller building and less cost.

 

Advanced Nuclear Will Further the Work of Current Reactors

Advanced reactors promise improved flexibility and the ability to do more kinds of work, including nuclear beyond electricity applications, to displace carbon and stabilize the climate. And they will continue nuclear energys legacy of providing reliable, carbon-free electricity, as a recent new U.S. reactor startup illustrates in practice. As new designs come on line over the next decade, we will continue to rely on operating plants which provide nearly 55 percent of the countrys carbon-free electricity.

The world will need all the carbon-free generation it can get for many years to come, as companies, states and countries aim for zero emissions by mid-century and pursue strategies like the green industrial revolution to accelerate deployment. That means it will need wind, solar, advanced reactors and current plants.

 

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FPL Proposes Significant Rate Hikes Over Four Years

FPL Rate Increase Proposal 2026-2029 outlines $9B base-rate hikes as Florida grows, citing residential demand, grid infrastructure investments, energy mix diversification, and Florida PSC review impacting customer bills, reliability, and fuel price volatility mitigation.

 

Key Points

A $9B base-rate plan FPL filed with the Florida PSC to fund growth, grid upgrades, and energy diversification through 2029.

✅ Adds 275k since 2021; +335k customers projected by 2029.

✅ Monthly bills rise to about $157 by 2029, up ~22% total.

✅ Investments in poles, wires, transformers, substations, renewables.

 

Florida Power & Light (FPL), the state's largest utility provider, has submitted a proposal to the Florida Public Service Commission (PSC) seeking a substantial increase in customer base rates over the next four years, amid ongoing scrutiny, including a recent hurricane surcharge controversy that heightened public attention.

Rationale Behind the Rate Increase

FPL's request is primarily influenced by Florida's robust population growth. Since 2021, the utility has added about 275,000 customers and projects an additional 335,000 by the end of 2029. This surge necessitates significant investments in transmission and distribution infrastructure, including poles, wires, transformers, and substations, to maintain reliable service. Moreover, FPL aims to diversify its energy mix to shield customers from fuel price volatility, even as the state declined federal solar incentives that could influence renewable adoption, ensuring a stable and sustainable power supply.

Impact on Customer Bills

If approved, the proposed rate increases would affect residential customers as follows:

  • 2026: An estimated increase of $11.52 per month, raising the typical bill to $145.66.

  • 2027: An additional $6.05 per month, bringing the bill to $151.71.

  • 2028: A further increase of $3.64 per month, totaling $155.35.

  • 2029: An extra $2.06 per month, resulting in a final bill of $157.41.

These adjustments represent a cumulative increase of approximately 22% over the four-year period, while in other regions some customers face sharper spikes, such as Pennsylvania's winter price increases this season.

Comparison with Previous Rate Hikes

This proposal follows a series of rate increases approved in recent years, as California electricity bills have soared and prompted calls for action in that state. For instance, Tampa Electric Co. (TECO) received approval for rate hikes totaling $287.9 million in 2025, with additional increases planned for 2026 and 2027. Consumer groups have expressed intentions to challenge these rate hikes, indicating a trend of growing scrutiny over utility rate adjustments.

Regulatory Review Process

The PSC is scheduled to review FPL's rate increase proposal in the coming months. A staff recommendation is expected by March 14, 2025, with a final decision anticipated at a commission conference on March 20, 2025. This process allows for public input and thorough evaluation of the proposed rate changes, while elsewhere some utilities anticipate stabilization, such as PG&E's 2025 outlook in California.

Customer and Consumer Advocacy Responses

The proposed rate hikes have elicited concerns from consumer advocacy groups. Organizations like Food & Water Watch have criticized the scale of the increase, labeling it as the largest rate hike request in U.S. history, amid mixed signals such as Gulf Power's one-time 40% bill decrease earlier this year. They argue that such substantial increases could place undue financial strain on households, especially those with fixed incomes.

Additionally, the Florida Public Service Commission has faced challenges in approving rate hikes for other utilities, such as TECO, and a recent Florida court decision on electricity monopolies that may influence the policy landscape, with consumer groups planning to appeal these decisions. This backdrop of heightened scrutiny suggests that FPL's proposal will undergo rigorous examination.

As Florida continues to experience rapid growth, balancing the need for infrastructure development and reliable energy services with the financial impact on consumers remains a critical challenge. The PSC's forthcoming decisions will play a pivotal role in shaping the state's energy landscape, influencing both the economy and the daily lives of Floridians.

 

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British Columbia Accelerates Clean Energy Shift

BC Hydro Grid Modernization accelerates clean energy and electrification, upgrading transmission lines, substations, and hydro dams to deliver renewable power for EVs and heat pumps, strengthen grid reliability, and enable industrial decarbonization in British Columbia.

 

Key Points

A $36B, 10-year plan to expand and upgrade B.C.'s clean grid for electrification, reliability, and industrial growth.

✅ $36B for lines, substations, and hydro dam upgrades

✅ Enables EV charging, heat pumps, and smart demand response

✅ Prioritizes industrial electrification and Indigenous partnerships

 

In a significant move towards a clean energy transition, British Columbia has announced a substantial $36-billion investment to enlarge and upgrade its electricity grid over the next ten years. The announcement last Tuesday from BC Hydro indicates a substantial 50 percent increase from its prior capital plan. A major portion of this investment is directed towards new consumer connections and improving current infrastructure, including substations, transmission lines, and hydro dams for more efficient power generation.

The catalyst behind this major investment is the escalating demand for clean energy across residential, commercial, and industrial sectors in British Columbia. Projections show a 15 percent rise in electricity demand by 2030. According to the Canadian Climate Institute's models, achieving Canada’s climate goals will require extensive electrification across various sectors, raising questions about a net-zero grid by 2050 nationwide.

BC Hydro is planning substantial upgrades to the electrical grid to meet the needs of a growing population, decreasing industry carbon emissions, and the shift towards clean technology. This is vital, especially as the province works towards improving housing affordability and as households face escalating costs from the impacts of climate change and increasing exposure to harsh weather events. Affordable, reliable power and access to clean technologies such as electric vehicles and heat pumps are becoming increasingly important for households.

British Columbia is witnessing a significant shift from fossil fuels to clean electricity in powering homes, vehicles, and workplaces. Electric vehicle usage in B.C. has increased twentyfold in the past six years. Last year, one in every five new light-duty passenger vehicles sold in B.C. was electric – the highest rate in Canada. Additionally, over 200,000 B.C. homes are now equipped with heat pumps, indicating a growing preference for the province’s 98 percent renewable electricity.

The investment also targets reducing industrial emissions and attracting industrial investment. For instance, the demand for transmission along the North Coastline, from Prince George to Terrace, is expected to double this decade, especially from sectors like mining. Mining companies are increasingly looking for locations with access to clean power to reduce their carbon footprint.

This grid enhancement plan in B.C. is reflective of similar initiatives in provinces like Quebec and the legacy of Manitoba hydro history in building provincial systems. Hydro-Québec announced a substantial $155 to $185 billion investment in its 2035 Action Plan last year, aimed at supporting decarbonization and economic growth. By 2050, Hydro-Québec predicts a doubling of electricity demand in the province.

Both utilities’ strategies focus on constructing new facilities and enhancing existing assets, like upgrading dams and transmission lines. Hydro-Québec, for instance, includes energy efficiency goals in its plan to double customer savings and potentially save over 3,500 megawatts of power.

However, with this level of investment, provinces need to engage in dialogue about priorities and the optimal use of clean electricity resources, with concepts like macrogrids offering potential benefits. Quebec, for instance, has shifted from a first-come, first-served basis to a strategic review process for significant new industrial power requests.

B.C. is also moving towards strategic prioritization in its energy strategy, evident in its recent moratorium on new connections for virtual currency mining due to their high energy consumption.

Indigenous partnership and leadership are also key in this massive grid expansion. B.C.’s forthcoming Call for Power and Quebec’s financial partnerships with Indigenous communities indicate a commitment to collaborative approaches. British Columbia has also allocated $140 million to support Indigenous-led power projects.

Regarding the rest of Canada, electricity planning varies in provinces with deregulated markets like Ontario and Alberta. However, these provinces are adapting too, and the federal government has funded an Atlantic grid study to improve regional planning efforts. Ontario, for example, has provided clear guidance to its system operator, mirroring the ambition in B.C. and Quebec.

Utilities are rapidly working to not only expand and modernize energy grids but also to make them more resilient, affordable, and smarter, as demonstrated by recent California grid upgrades funding announcements across the sector. Hydro-Québec focuses on grid reliability and affordability, while B.C. experiments with smart-grid technologies.

Both Ontario and B.C. have programs encouraging consumers to reduce consumption in real-time, demonstrating the potential of demand-side management. A recent instance in Alberta showed how customer participation could prevent rolling blackouts by reducing demand by 150 megawatts.

This is a crucial time for all Canadian provinces to develop larger, smarter energy grids, including a coordinated western Canadian electricity grid approach for a sustainable future. Utilities are making significant strides towards this goal.
 

 

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China power cuts: What is causing the country's blackouts?

China Energy Crisis drives electricity shortages, power cuts, and blackouts as coal prices surge, carbon-neutrality rules tighten, and manufacturing hubs ration energy, disrupting supply chains and industrial output ahead of winter demand peaks.

 

Key Points

A power shortfall from costly coal, price caps, and emissions targets, causing blackouts and industrial rationing.

✅ Coal prices soar while electricity tariffs are capped

✅ Factories in northeast hubs face rationing and downtime

✅ Supply chains risk delays ahead of winter demand

 

China is struggling with a severe shortage of electricity which has left millions of homes and businesses hit by power cuts.

Blackouts are not that unusual in the country but this year a number of factors have contributed to a perfect storm for electricity suppliers, including surging electricity demand globally.

The problem is particularly serious in China's north eastern industrial hubs as winter approaches - and is something that could have implications for the rest of the world.

Why has China been hit by power shortages?
The country has in the past struggled to balance electricity supplies with demand, which has often left many of China's provinces at risk of power outages.

During times of peak power consumption in the summer and winter the problem becomes particularly acute.

But this year a number of factors have come together to make the issue especially serious.

As the world starts to reopen after the pandemic, demand for Chinese goods is surging and the factories making them need a lot more power, highlighting China's electricity appetite in recent months.

Rules imposed by Beijing as it attempts to make the country carbon neutral by 2060 have seen coal production slow, even as the country still relies on coal for more than half of its power and as low-emissions generation is set to cover most global demand growth.

And as electricity demand has risen, the price of coal has been pushed up.

But with the government strictly controlling electricity prices, coal-fired power plants are unwilling to operate at a loss, with many drastically reducing their output instead.

Who is being affected by the blackouts?
Homes and businesses have been affected by power cuts as electricity has been rationed in several provinces and regions.

A coal-burning power plant can be seen behind a factory in China"s Inner Mongolia Autonomous Region

The state-run Global Times newspaper said there had been outages in four provinces - Guangdong in the south and Heilongjiang, Jilin and Liaoning in the north east. There are also reports of power cuts in other parts of the country.

Companies in major manufacturing areas have been called on to reduce energy usage during periods of peak demand or limit the number of days that they operate.

Energy-intensive industries such as steel-making, aluminium smelting, cement manufacturing and fertiliser production are among the businesses hardest hit by the outages.

What has the impact been on China's economy?
Official figures have shown that in September 2021, Chinese factory activity shrunk to the lowest it had been since February 2020, when power demand dropped as coronavirus lockdowns crippled the economy.

Concerns over the power cuts have contributed to global investment banks cutting their forecasts for the country's economic growth.

Goldman Sachs has estimated that as much as 44% of the country's industrial activity has been affected by power shortages. It now expects the world's second largest economy to expand by 7.8% this year, down from its previous prediction of 8.2%.

Globally, the outages could affect supply chains, including solar supply chains as the end-of-the-year shopping season approaches.

Since economies have reopened, retailers around the world have already been facing widespread disruption amid a surge in demand for imports.

China's economic planner, the National Development and Reform Commission (NDRC), has outlined a number of measures to resolve the problem, with energy supplies in the northeast of the country as its main priority this winter.

The measures include working closely with generating firms to increase output, ensuring full supplies of coal and promoting the rationing of electricity.

The China Electricity Council, which represents generating firms, has also said that coal-fired power companies were now "expanding their procurement channels at any cost" in order to guarantee winter heat and electricity supplies.

However, finding new sources of coal imports may not be straightforward.

Russia is already focused on its customers in Europe, Indonesian output has been hit by heavy rains and nearby Mongolia is facing a shortage of road haulage capacity,

Are energy shortages around the world connected?
Power cuts in China, UK petrol stations running out of fuel, energy bills jumping in Europe, near-blackouts in Japan and soaring crude oil, natural gas and coal prices on wholesale markets - it would be tempting to assume the world is suddenly in the grip of a global energy drought.

However, it is not quite as simple as that - there are some distinctly different issues around the world.

For example, in the UK petrol stations have run dry as motorists rushed to fill up their vehicles over concerns that a shortage of tanker drivers would mean fuel would soon become scarce.

Meanwhile, mainland Europe's rising energy bills and record electricity prices are due to a number of local factors, including low stockpiles of natural gas, weak output from the region's windmills and solar farms and maintenance work that has put generating operations out of action.
 

 

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UK Anticipates a 16% Decrease in Energy Bills in April

UK Energy Price Cap Cut 2024 signals relief as wholesale gas prices fall; Ofgem price cap drops per Cornwall Insight, aided by LNG supply, mild winter, despite Red Sea tensions and Ukraine conflict impacts.

 

Key Points

A forecast cut to Great Britain's Ofgem price cap as wholesale gas falls, easing typical annual household bills in 2024.

✅ Cap falls from £1,928 to £1,620 in April 2024

✅ Forecast £1,497 in July, then about £1,541 from October

✅ Drivers: lower wholesale gas, LNG supply, mild winter

 

Households in Great Britain are set to experience a significant reduction in energy costs this spring, with bills projected to drop by over £300 annually. This decrease is primarily due to a decline in wholesale gas prices, offering some respite to those grappling with the cost of living crisis.

Cornwall Insight, a well-regarded industry analyst, predicts a 16% reduction in average bills from the previous quarter, potentially reaching the lowest levels since the onset of the Ukraine conflict.

The industry’s price cap, indicative of the average annual bill for a typical household, is expected to decrease from the current £1,928, set earlier this month, to £1,620 in April – a reduction of £308 and £40 less than previously forecasted in December, as ministers consider ending the gas-electricity price link to improve market resilience.

Concerns about escalating tensions in the Red Sea, where Houthi rebels have disrupted global shipping, initially led analysts to fear an increase in wholesale oil prices and subsequent impact on household energy costs.

Contrary to these concerns, oil prices have remained relatively stable, and European gas reserves have been higher than anticipated during a mild winter, with European gas prices returning to pre-Ukraine war levels since November.

Cornwall Insight anticipates that energy prices will continue to be comparatively low through 2024. They predict a further decline to £1,497 for a typical annual bill from July, followed by a slight increase to £1,541 starting in October.

This forecast is a welcome development for Britons who have been dealing with increased expenses across various sectors, from food to utilities, amidst persistently high inflation rates, with energy-driven EU inflation hitting lower-income households hardest across member states.

Energy bills saw a steep rise in 2021, which escalated further due to the Ukraine conflict in 2022, driving up wholesale gas prices. This surge prompted government intervention to subsidize bills, with the UK price cap estimated to cost around £89bn to the public purse, capping costs to a typical household at £2,500.

Cornwall Insight noted that the supply of liquified natural gas to Europe had not been as adversely affected by the Red Sea disruptions as initially feared. Moreover, the UK has been well-supplied with gas from the US, which has become a more significant supplier since the Ukraine war, even as US electricity prices have risen to multi-decade highs. Contributing factors also include lower gas prices in Asia, mild weather, and robust gas availability.

Craig Lowrey, a principal consultant at Cornwall Insight, remarked that concerns about Red Sea events driving up energy prices have not materialized, allowing households to expect a reduction in prices.

On Monday, the next-month wholesale gas price dropped by 4% to 65p a therm.

However, Lowrey cautioned that a complete return to pre-crisis energy bill levels remains unlikely due to ongoing market impacts from shifting away from Russian energy sources and persistent geopolitical tensions, as well as policy changes such as Britain’s Energy Security Bill shaping market reforms.

Richard Neudegg, director of regulation at Uswitch, welcomed the potential further reduction of the price cap in April. However, he pointed out that this offers little solace to households currently struggling with high winter energy costs during the winter. Neudegg urged Ofgem, the energy regulator, to prompt suppliers to reintroduce more competitive and affordable fixed-price deals.

 

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