Website tracks worst polluting power plants

By Toronto Star


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How dirty is your electricity?

The information is on a new website, and its creators hope the public disclosure will inspire a global cleanup of polluting power plants.

Around the world, 50,000 plants generate electricity: Every year, the thousands that burn coal and other fossil fuels spew 10 billion tons of carbon dioxide, making a major contribution to climate change, according to the Carbon Monitoring for Action (CARMA) site.

The problem stands to get worse, with hundreds more coal-fired plants set to be built during the next decade, says David Wheeler of the Centre for Global Development, which compiled the database.

Political rhetoric increasingly stresses the need to cut emissions, "but the reality on the ground is going in the other direction," Wheeler said in an interview.

"Information leads to action.... If you can get a coherent database to the public, you can have quite a substantial impact."

About 60 per cent of the world's electricity is generated by burning fossil fuels, and those power plants create one-quarter of all greenhouse gas emissions, CARMA says.

The countries with, by far, the most dirty plants are the United States and China: Together, they produce more than half the global power plant emissions.

Canada is well back in 15th place. Thanks to its many sources of hydro and nuclear power, Canada also produces relatively few greenhouse gases in proportion to the electricity generated.

Among individual plants, the biggest emitters are in China, Taiwan, South Korea, Russia and the U.S.

Ontario Power Generation's Nanticoke plant on Lake Erie is 65th on the list, at about 17.6 million tons of greenhouse gases a year.

It operates only intermittently to generate electricity at times of peak demand. If it ran as often as most large plants it would be a "world scale" polluter, Wheeler said.

While 4,000 companies run power plants, only 100 produce 57 per cent of the emissions, Wheeler noted. "One hundred CEOs are accountable for that much."

Research for the site – CARMA.org – confirmed "the dismaying persistence" of coal as a fuel, despite its well-known contribution to climate change, he said.

Along with hundreds of coal-fired plants being built in Asia, the U.S. plans 83 and Western Europe, 38.

The work also undermined the argument, often made in international negotiations, that climate change is caused by wealthy industrialized nations and, therefore, the developing world merits a pass while it attempts to rise out of poverty. This year, for the first time, greenhouse emissions from power plants in developing nations will exceed those in the developed world.

The view that the "South" can wait is outmoded, Wheeler said.

It's "moving into crisis territory on its own now, even if there was no more carbon dioxide from the 'North.'"

The solution, Wheeler said, must be "some grand bargain" among all 203 nations included in the database to regulate emissions and reduce them through new technology, renewable sources, conservation and efficiency.

Public disclosure is already credited with reducing air and water emissions of toxic substances in Canada, the U.S. and even in China, Wheeler said.

It can lead to public pressure on polluters. As well, he said, banks are sometimes unwilling to back companies that might face pollution lawsuits or appear to be wasteful. And corporate executives occasionally want to improve their image. Disclosure can, "set off soul-searching in corporate suites."

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Yet another Irish electricity provider is increasing its prices

Electric Ireland Electricity Price Increase stems from rising wholesale costs as energy suppliers adjust tariffs. Customers face higher electricity bills, while gas remains unchanged; switching provider could deliver savings during winter.

 

Key Points

A 4% increase in Electric Ireland electricity prices from 1 Feb 2018, driven by wholesale costs; gas unchanged.

✅ 4% electricity rise effective 1 Feb 2018

✅ Increase attributed to rising wholesale energy costs

✅ Switching supplier may reduce bills and boost savings

 

ELECTRIC IRELAND has announced that it will increase its household electricity prices by 4% from 1 February 2018.

This comes just a week after both Bord Gáis Energy and SSE Airtricity announced increases in their gas and electricity prices, while national efforts to secure electricity supplies continue in parallel.

Electric Ireland has said that the electricity price increase is unavoidable due to the rising wholesale cost of electricity, with EU electricity prices trending higher as well.

The electricity provider said it has no plans to increase residential gas prices at the moment.

Commenting on the latest announcement, Eoin Clarke, managing director of Switcher.ie, said: “This is the third largest energy supplier to announce a price increase in the last week, so the other suppliers are probably not far behind.

“The fact that the rise is not coming into effect until 1 February will be welcomed by Electric Ireland customers who are worried about the rising cost of energy as winter sets in,” he said.

However, any increase is still bad news, especially as a quarter of consumers (27%) say their energy bill already puts them under financial pressure, and EU energy inflation has disproportionately affected lower-income households.

According to Electric Ireland, this will amount to a €2.91 per month increase for an average electricity customer, amounting to €35 per year.

Meanwhile, SSE Airtricity’s change amounts to an increase of 90 cent per week or €46.80 per year for someone with average consumption on their 24hr SmartSaver standard tariff, far below the dramatic Spain electricity price surge seen recently.

Bord Gáis Energy said its announcement will increase a typical gas bill by €2.12 a month and a typical electricity bill by €4.77 a month, reflecting wider trends such as the Germany power price spike reported recently.

In a statement, Bord Gáis Energy said: “The changes, which will take effect from 1st November 2017, are due to significant increases in the wholesale cost of energy as well as higher costs associated with distributing energy on the gas and electricity networks.

“In percentage terms, the increase represents 3.4% in a typical customer’s gas bill and an increase of 5.9% in a typical customer’s electricity bill.”

Clark said that if customers haven’t switched electricity provider in over a year that they should review the deals available at the moment.

“The market is highly competitive so there are huge savings to be made by switching,” he said.

“All suppliers use the same cables to supply electricity to your home, so you don’t need to worry about any loss in service, and you could save up to 324 by switching from typical standard tariffs to the cheapest deals on the market.”

 

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America’s Electricity is Safe From the Coronavirus—for Now

US Grid Pandemic Response coordinates control rooms, grid operators, and critical infrastructure, leveraging hydroelectric plants, backup control centers, mutual assistance networks, and deep cleaning protocols to maintain reliability amid reduced demand and COVID-19 risks.

 

Key Points

US Grid Pandemic Response encompasses measures by utilities and operators to safeguard power reliability during COVID-19

✅ Control rooms staffed on-site; operators split across backup centers

✅ Health screenings, deep cleaning, and isolation protocols mitigate contagion

✅ Reduced demand and mutual assistance improve grid resilience

 

Control rooms are the brains of NYPA’s power plants, which are mostly hydroelectric and supply about a quarter of all the electricity in New York state. They’re also a bit like human petri dishes. The control rooms are small, covered with frequently touched switches and surfaces, and occupied for hours on end by a half-dozen employees. Since social distancing and telecommuting isn’t an option in this context, NYPA has instituted regular health screenings and deep cleanings to keep the coronavirus out.

The problem is that each power plant relies on only a handful of control room operators. Since they have a specialized skill set, they can’t be easily replaced if they get sick. “They are very, very critical,” says Gil Quiniones, NYPA president and CEO. If the pandemic worsens, Quiniones says that NYPA may require control room operators to live on-site at power plants to reduce the chance of the virus making it in from the outside world. It sounds drastic, but Quiniones says NYPA has done it before during emergencies—once during the massive 2003 blackout, and again during Hurricane Sandy.

Meanwhile, PJM is one of North America’s nine regional grid operators and manages the transmission lines that move electricity from power plants to millions of customers in 13 states on the Eastern seaboard, including Washington, DC. PJM has had a pandemic response plan on the books for 15 years, but Mike Bryson, senior vice president of operations, says that this is the first time it’s gone into full effect. As of last week, about 80 percent of PJM’s 750 full-time employees have been working from home. But PJM also requires a skeleton crew of essential workers to be on-site at all times in its control centers. As part of its emergency planning, PJM built a backup control center years ago, and now it is splitting control center operators between the two to limit contact.

Past experience with large-scale disasters has helped the energy sector keep the lights on and ventilators running during the pandemic. Energy is one of 16 sectors that the US government has designated as “critical infrastructure,” which also includes the communications industry, transportation sector, and food and water systems. Each is seen as vital to the country and therefore has a duty to maintain operations during national emergencies.

“We need to be treated as first responders,” says Scott Aaronson, the vice president of security and preparedness at the Edison Electric Institute, a trade group representing private utilities. “Everybody's goal right now is to keep the public healthy, and to keep society functioning as best we can. A lack of electricity will certainly create a challenge for those goals.”

America’s electricity grid is a patchwork of regional grid operators connecting private and state-owned utilities. This means simply figuring out who’s in charge and coordinating among the various organizations is one of the biggest challenges to keeping the electricity flowing during a national emergency, according to Aaronson.

Generally, a lot of this responsibility falls on formal energy organizations like the nonprofit North American Electric Reliability Corporation and the Federal Energy Regulatory Commission. But during the coronavirus outbreak, an obscure organization run by the CEOs of electric utilities called the Electricity Subsector Coordinating Council has also served as a primary liaison between the federal government and the thousands of utility companies around the US. Aaronson says the organization has been meeting twice a week for the past three weeks to ensure that utilities are implementing best practices in their response to the coronavirus, as well as to inform the government of material needs to keep the energy sector running smoothly.

This tight-knit coordination will be especially important if the pandemic gets worse, as many forecasts suggest it will. Most utilities belong to at least one mutual assistance group, an informal network of electricity suppliers that help each other out during a catastrophe. These mutual assistance networks are usually called upon following major storms that threaten prolonged outages. But they could, in principle, be used to help during the coronavirus pandemic too. For example, if a utility finds itself without enough operators to manage a power plant, it could conceivably borrow trained operators from another company to make sure the power plant stays online.

So far, utilities and grid operators have managed to make it work on their own. There have been a handful of coronavirus cases reported at power plants, but they haven’t yet affected these plants’ ability to deliver energy. The challenges of running a power plant with a skeleton crew is partially offset by the reduced power demand as businesses shut down and more people work from home, says Robert Hebner, the director of the Center for Electromechanics at the University of Texas. “The reduced demand for power gives utilities a little breathing room,” says Hebner.

A recent study by the University of Chicago’s Energy Policy Institute found that electricity demand in Italy has plunged by 18 percent following the severe increase in coronavirus cases in the country. Energy demand in China also plummeted as a result of the pandemic. Bryson, at PJM, says the grid operator has seen about a 6 percent decrease in electricity demand in recent weeks, but expects an even greater drop if the pandemic gets worse.

Generally speaking, problems delivering electricity in the US occur when the grid is overloaded or physically damaged, such as during California wildfires or a hurricane.

An open question among coronavirus researchers is whether there will be a second wave of the pandemic later this year. During the Spanish flu pandemic in the early 20th century, the second wave turned out to be deadlier than the first. If the coronavirus remerges later this year, it could be a serious threat to reliable electricity in the US, says John MacWilliams, a former associate deputy secretary of the Department of Energy and a senior fellow at Columbia University’s Center on Global Energy Policy.

“If this crisis extends into the fall, we're going to hit hurricane season along the coasts,” MacWilliams says. “Utilities are doing a very good job right now, but if we get unlucky and have an active hurricane season, they're going to get very stressed because the number of workers that are available to repair damage and restore power will become more limited.”

This was a sentiment echoed by Bryson at PJM. “Any one disaster is manageable, but when you start layering them on top of each other, it gets much more challenging,” he adds. The US electricity grid struggles to handle major storms as it is, and these challenges will be heightened if too many workers are home sick. In this sense, the energy sector’s ability to deliver the electricity needed to keep manufacturing medical supplies or keep ventilators running depends to a large extent on our ability to flatten the curve today. The coronavirus is bad enough without having to worry about the lights going out.

 

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Electric vehicle sales triple in Australia despite lack of government support

Australian Electric Vehicle Sales tripled in 2019 amid expanding charging infrastructure and more models, but market share remains low, constrained by limited government policy, weak incentives, and absent emissions standards despite growing ultra-fast chargers.

 

Key Points

EV units sold in Australia; in 2019 they tripled to 6,718, but market share was just 0.6%.

✅ Sales rose from 2,216 (2018) to 6,718 (2019); ~80% were BEVs.

✅ Public charging sites reached 2,307; fast chargers up 40% year-on-year.

✅ Policy gaps and absent standards limit model supply and EV uptake.

 

Sales of electric vehicles in Australia tripled in 2019 despite a lack of government support, according to the industry’s peak body.

The country’s network of EV charging stations was also growing, the Electric Vehicle Council’s annual report found, including a rise in the number of faster charging stations that let drivers recharge a car in about 15 minutes.

But the report, released on Wednesday, found the market share for electric vehicles was still only 0.6% of new vehicle sales – well behind the 2.5% to 5% in other developed countries.

The chief executive of the council, Behyad Jafari, said the rise in sales was down to more models becoming available. There are now 28 electric models on sale, with eight priced below $65,000.

Six more were due to arrive before the end of 2021, including two priced below $50,000, the council’s report said.

“We have repeatedly heard from car companies that they were planning to bring vehicles here, but Australia doesn’t have that policy support.”

The Morrison government promised a national electric vehicle strategy would be finalised by the middle of this year, but the policy has been delayed. The prime minister, Scott Morrison, last year accused Labor of wanting to “end the weekend” and force people out of four-wheel drives after the opposition set a target of 50% of new car sales being electric by 2030.

Jafari cited the Kia e-Niro – an award-winning electric SUV that was being prepared for an Australian launch, but is now reportedly on hold because the manufacturer favoured shipping to countries with emissions standards.

The council’s members include BMW, Nissan, Hyundai and Harley Davidson, as well as energy, technology and charging infrastructure companies.

Sales of electric vehicles – which include plug-in hybrids – went from 2,216 in 2018 to 6,718 in 2019, the report said. Jafari said about 80% of those sales were all-electric vehicles.

There have been 3,226 electric vehicles sold in 2020, the report said, despite an overall drop of 20% in vehicle sales due to the Covid-19 pandemic, while U.S. EV sales have surged into 2024.

Jafari said: “Our report is showing that Australian consumers want these cars.

“There is no controversy that the future of the industry is electric, but at the moment the industry is looking at different markets. We want policies that show [Australia] is going on this journey.”

Government agency data has forecast that half the new cars sold will be electric by 2035, underscoring that the age of electric cars is arriving even if there is no policy to support their uptake.

Manufacturers currently selling electric cars in Australia are Nissan, Hyundai, Mitsubishi, Tesla, Volvo, Porsche, Audi, BMW, Mercedes, Jaguar and Renault, the report said.

Jafari said most G20 countries had emissions standards in place for vehicles sold and incentives in place to support electric vehicles, such as rebates or exemptions from charges. This hadn’t happened in Australia, he said.

The report said: “Globally, carmakers are rolling out more electric vehicle models as the electric car market expands, but so far production cannot keep up with demand. This means that without policy signals, Australians will continue to be denied access to the full global range of electric vehicles.”

On Tuesday, one Australian charging provider, Evie Networks, opened an ultra-fast station at a rest stop at Campbell Town in Tasmania – between Launceston and Hobart.

The company said the station would connect EV owners in the state’s north and south and the two 350kW chargers could recharge a vehicle in 15 minutes, highlighting whether grids have the power to charge EVs at scale. Two more sites were planned for Tasmania, the company said.

A Tasmanian government grant to support electric vehicle charging had helped finance the site. Evie was also supported with a $15m grant from the federal government’s Australian Renewable Energy Agency.

According to the council report, Australia now has 2,307 public charging stations, including 357 fast chargers – a rise of 40% in the past year.

A survey of 2,900 people in New South Wales, the ACT, Victoria and South Australia, carried out by NRMA, RACV and RAA on behalf of the council, found the main barriers to buying an electric vehicle were concerns over access to charging points, higher prices and uncertainty over driving range.

Consumers favoured electric vehicles because of their environmental footprint, lower maintenance costs and vehicle performance.

The report said the average battery range of electric vehicles available in Australia was 400km, but almost 80% of people thought the average was less.

According to the survey, 56% of Australians would consider an electric car when they next bought a vehicle, and in the UK, EV inquiries soared during a fuel supply crisis.

“We are far behind, but it is surmountable,” Jafari said.

The council report also rated state and territories on the policies that supported its industry and found the ACT was leading, followed by NSW and Queensland.

A review of commercial electric vehicle use found public electric bus trials were planned or under way in Queensland, NSW, WA, Victoria and ACT. There are now more than 400,000 electric buses in use around the globe.

 

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Ontario Launches Largest Competitive Energy Procurement in Province’s History

Ontario Competitive Energy Procurement accelerates renewables, boosts grid reliability, and invites competitive bids across solar, wind, natural gas, and storage, driving innovation, lower costs, and decarbonization to meet rising electricity demand and ensure power supply.

 

Key Points

Ontario Competitive Energy Procurement is a competitive bidding program to deliver reliable, low-carbon electricity.

✅ Competitive bids from renewables, gas, and storage

✅ Targets grid reliability, affordability, and emissions

✅ Phased evaluations: technical, financial, environmental

 

Ontario has recently marked a significant milestone in its energy sector with the launch of what is being touted as the largest competitive energy procurement process in the province’s history. This ambitious initiative is set to transform the province’s energy landscape through a broader market overhaul that fosters innovation, enhances reliability, and addresses the growing demands of Ontario’s diverse population.

A New Era of Energy Procurement

The Ontario government’s move to initiate this massive competitive procurement process underscores a strategic shift towards modernizing and diversifying the province’s energy portfolio. This procurement exercise will invite bids from a broad spectrum of energy suppliers and technologies, ranging from traditional sources like natural gas to renewable energy options such as solar and wind power. The aim is to secure a reliable and cost-effective energy supply that aligns with Ontario’s long-term environmental and economic goals.

This historic procurement process represents a major leap from previous approaches by emphasizing a competitive marketplace where various energy providers can compete on an equal footing through electricity auctions and transparent bidding. By doing so, the government hopes to drive down costs, encourage technological advancements, and ensure that Ontarians benefit from a more dynamic and resilient energy system.

Key Objectives and Benefits

The primary objectives of this procurement initiative are multifaceted. First and foremost, it seeks to enhance the reliability of Ontario’s electricity grid. As the province experiences population growth and increased energy demands, maintaining a stable and dependable supply of electricity is crucial, and interprovincial imports through an electricity deal with Quebec can complement local generation. This procurement process will help identify and integrate new sources of power that can meet these demands effectively.

Another significant goal is to promote environmental sustainability. Ontario has committed to reducing its greenhouse gas emissions through Clean Electricity Regulations and transitioning to a cleaner energy mix. By inviting bids from renewable energy sources and innovative technologies, the government aims to support its climate action plan and contribute to the province’s carbon reduction targets.

Cost-effectiveness is also a central focus of the procurement process. By creating a competitive environment, the government anticipates that energy providers will strive to offer more attractive pricing structures and fair electricity cost allocation practices for ratepayers. This, in turn, could lead to lower energy costs for consumers and businesses, fostering economic growth and improving affordability.

The Competitive Landscape

The competitive energy procurement process will be structured to encourage participation from a wide range of energy providers. This includes not only established companies but also emerging players and startups with innovative technologies. By fostering a diverse pool of bidders, the government aims to ensure that all viable options are considered, ultimately leading to a more robust and adaptable energy system.

Additionally, the process will likely involve various stages of evaluation, including technical assessments, financial analyses, and environmental impact reviews. This thorough evaluation will help ensure that selected projects meet the highest standards of performance and sustainability.

Implications for Stakeholders

The implications of this procurement process extend beyond just energy providers and consumers. Local communities, businesses, and environmental organizations will all play a role in shaping the outcomes. For communities, this initiative could mean new job opportunities and economic development, particularly in regions where new energy projects are developed. For businesses, the potential for lower energy costs and access to innovative energy solutions, including demand-response initiatives like the Peak Perks program, could drive growth and competitiveness.

Environmental organizations will be keenly watching the process to ensure that it aligns with broader sustainability goals. The inclusion of renewable energy sources and advanced technologies will be a critical factor in evaluating the success of the initiative in meeting Ontario’s climate objectives.

Looking Ahead

As Ontario embarks on this unprecedented energy procurement journey, the outcomes will be closely watched by various stakeholders. The success of this initiative will depend on the quality and diversity of the bids received, the efficiency of the evaluation process, and the ability to integrate new energy sources into the existing grid, while advancing energy independence where feasible.

In conclusion, Ontario’s launch of the largest competitive energy procurement process in its history is a landmark event that holds promise for a more reliable, sustainable, and cost-effective energy future. By embracing competition and innovation, the province is setting a new standard for energy procurement that could serve as a model for other regions seeking to modernize their energy systems. The coming months will be crucial in determining how this bold initiative will shape Ontario’s energy landscape for years to come.

 

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CALIFORNIA: Why your electricity prices are soaring

California Electricity Prices are surging across PG&E, SCE, and SDG&E territories, driven by fixed grid costs, wildfire mitigation, CARE subsidies, and Net Energy Metering, burdening low-income renters and increasing statewide utility debt, CPUC reports show.

 

Key Points

High rates driven by fixed grid costs and policies, burdening low-income customers across PG&E, SCE, and SDG&E.

✅ Fixed costs: transmission, distribution, wildfire mitigation

✅ Solar NEM shifts grid costs onto remaining ratepayers

✅ CPUC, CARE, LIHEAP aim to relieve rising utility debt

 

California's electricity prices are among the highest in the country, new research says, and those costs are falling disproportionately on a customer base that's already struggling to pay their bills.

PG&E customers pay about 80 percent more per kilowatt-hour than the national average, according to a study by the energy institute at UC Berkeley's Haas Business School with the nonprofit think tank Next 10. The study analyzed the rates of the state's three largest investor-owned utilities and found that Southern California Edison charged 45 percent more than the national average, while San Diego Gas & Electric charged double. Even low-income residents enrolled in the California Alternate Rates for Energy program paid more than the average American.

"California's retail prices are out of line with utilities across the country," said UC Berkeley assistant professor and study co-author Meredith Fowlie, citing Hawaii and some New England states among the outliers with even higher rates. "And they're increasing, as regulators face calls for action across the state."


So why are prices so high?
One reason is that California's size and geography inflate the "fixed" costs of operating its electric system, even as the state considers revamping electricity rates to clean the grid in parallel, which include maintenance, generation, transmission, and distribution as well as public programs like CARE and wildfire mitigation, according to the study. Those costs don't change based on how much electricity residents consume, yet between 66 and 77 percent of Californians' electricity bills are used to offset the costs of those programs, the study found.

These are legitimate expenses, Fowlie said. However, because lower-income residents use only moderately less electricity than higher income households, they end up with a disproportionate share of the burden, according to the study. And while the bills of older, wealthier Californians continue to decrease as they adopt cost-efficient alternatives like the state's Net Energy Metering solar program and the resulting solar power cost shift dynamic, costs will keep rising for a shrinking customer base composed mostly of low- and middle-income renters who still use electricity as their main energy source.

"When households adopt solar, they're not paying their fair share," Fowlie said. While solar users generate power that decreases their bills, they still rely on the state's electric grid for much of their power consumption - without paying for its fixed costs like others do.

"As this continues it's going to make electricity even more unaffordable," said F. Noel Perry, founder of Next 10, which funds nonpartisan research on the economy and environment.

PG&E this month raised its electricity rates 3.7 percent, amounting to a $5.01 a month increase for the average residential customer, who now pays $138.85 a month for electricity. It was the second increase this year, as regulators consider major changes to electric bills statewide, said Mark Toney, executive director of The Utility Reform Network, who noted that higher rates are particularly difficult for those who have lost their jobs in the pandemic. The California Public Utilities Commission last year approved a PG&E plan for more incremental increases through Dec. 31, 2022.

PG&E spokesperson Kristi Jourdan said in an email statement that the company was committed to keeping prices as low as possible as the state weighs income-based flat-fee utility bills proposals, and that although some programs are meant to be subsidized through rates, "in other cases, given that some customers have greater access to energy alternatives, the remaining customers - often those with limited means - are left paying unintended subsidies."

The costs quickly became overwhelming for Fretea Sylver, who rents a small house in Castro Valley and lost much of her work as the owner of a small woodwork business early in the pandemic. "They're little tiny changes but they accumulate. You turn around and you're like wait a second, why is my bill $20 more?," Sylver said. "And you have to pay it, no matter what."

Many more are unable to pay. Between February and December of last year, Californians accumulated more than $650 million in late payments from their utility providers, according to an analysis by the CPUC. In 2019, utility debt fell $71,646,869 from the prior year.

Sylver, who was on unemployment for 10 months last year, accumulated over $600 in unpaid PG&E bills. "We sort of went into a bit of debt, having to use credit cards and loans to sustain what we had to pay for. We're trying to catch up," Sylver said. The family received some help from the federal Low-Income Home Energy Assistance Program, which provides up to $1,000 to those who are late on their utility bills.

The study identified improvements to make California's power grid more equitable, such as income-based fixed electricity charges for the grid's cost that are based on income. Republican state senators this week called on the state to use federal relief money to forgive the billions Californians owe in utility debt, even as some lawmakers move to overturn income-based utility charges amid ongoing debate. Californians are currently protected by a statewide moratorium on disconnection for nonpayment of electricity bills through June 30. The CPUC this month began taking public input on the issue of how to grant some relief to those who have fallen behind on their utility bills.

This article is part of the California Divide, a collaboration among newsrooms examining income inequality and economic survival in California.

 

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BC residents split on going nuclear for electricity generation: survey

BC Energy Debate: Nuclear Power and LNG divides British Columbia, as a new survey weighs zero-emission clean energy, hydroelectric capacity, the Site C dam, EV mandates, energy security, rising costs, and blackout risks.

 

Key Points

A BC-wide debate on power choices balancing nuclear, LNG, hydro, costs, climate goals, EVs, and grid reliability.

✅ Survey: 43% support nuclear, 40% oppose in BC

✅ 55% back LNG expansion, led by Southern BC

✅ Hydro at 90%; Site C adds 1,100 MW by 2025

 

There is a long-term need to produce more electricity to meet population and economic growth needs and, in particular, create new clean energy sources, with two new BC generating stations recently commissioned contributing to capacity.

Increasingly, in the worldwide discourse on climate change, nuclear power plants are being touted as a zero-emission clean energy source, with Ontario exploring large-scale nuclear to expand capacity, and a key solution towards meeting reduced emissions goals. New technological advancements could make nuclear power far safer than existing plant designs.

When queried on whether British Columbia should support nuclear power for electricity generation, respondents in a new province-wide survey by Research Co. were split, with 43% in favour and 40% against.

Levels of support reached 46% in Metro Vancouver, 41% in the Fraser Valley, 44% in Southern BC, 39% in Northern BC, and 36% on Vancouver Island.

The closest nuclear power plant to BC is the Columbia Generating Station, located in southern Washington State.

The safe use of nuclear power came to the forefront following the 2011 Fukushima nuclear disaster when the most powerful earthquake ever recorded in Japan triggered a large tsunami that damaged the plant’s emergency generators. Japan subsequently shut off many of its nuclear power plants and increased its reliance on fossil fuel imports, but in recent years there has been a policy reversal to restart shuttered nuclear plants to provide the nation with improved energy security.

Over the past decade, Germany has also been undergoing a transition away from nuclear power. But in an effort to replace Russian natural gas, Germany is now using more coal for power generation than ever before in decades, while Ontario’s electricity outlook suggests a shift to a dirtier mix, and it is looking to expand its use of liquefied natural gas (LNG).

Last summer, German chancellor Olaf Scholz told the CBC he wants Canada to increase its shipments of LNG gas to Europe. LNG, which is greener compared to coal and oil, is generally seen as a transitionary fuel source for parts of the world that currently depend on heavy polluting fuels for power generation.

When the Research Co. survey asked BC residents whether they support the further development of the province’s LNG industry, including LNG electricity demand that BC Hydro says justifies Site C, 55% of respondents were supportive, while 29% were opposed and 17% undecided.

Support for the expansion of the LNG is highest in Southern BC (67%), followed by the Fraser Valley (56%), Metro Vancouver (also 56%), Northern BC (55%), and Vancouver Island (41%).

A larger proportion of BC residents are against any idea of the provincial government moving to ban the use of natural gas for stoves and heating in new buildings, with 45% opposed and 39% in support.

Significant majorities of BC residents are concerned that energy costs could become too expensive, and a report on coal phase-outs underscores potential cost and effectiveness concerns, with 84% expressing concern for residents and 66% for businesses. As well, 70% are concerned that energy shortages could lead to measures such as rationing and rolling blackouts.

Currently, about 90% of BC’s electricity is produced by hydroelectric dams, but this fluctuates throughout the year — at times, BC imports coal- and gas-generated power from the United States when hydro output is low.

According to BC Hydro’s five-year electrification plan released in September 2021, it is estimated BC has a sufficient supply of clean electricity only by 2030, including the capacity of the Site C dam, which is slated to open in 2025. The $16 billion dam will have an output capacity of 1,100 megawatts or enough power for the equivalent of 450,000 homes.

The provincial government’s strategy for pushing vehicles towards becoming dependent on the electrical grid also necessitates a reliable supply of power, prompting BC Hydro’s first call for power in 15 years to prepare for electrification. Most BC residents support the provincial government’s requirement for all new car and passenger truck sales to be zero-emission by 2035, with 75% supporting the goal and 21% opposed.
 

 

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