Stop the Shock campaign seeks to bring back Canadian coal power


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Alberta Electricity Price Hikes spotlight grid reliability, renewable transition, coal phase-out, and energy poverty, as policy shifts and investor reports warn of rate increases, biomass trade-offs, and sustainability challenges impacting households and businesses.

 

Key Points

Projected power bill hikes from market reforms, renewables, coal phase-out, and reliability costs in Alberta.

✅ Investor report projects 3x-7x bills and $50B market transition costs

✅ Policy missteps cited in Ontario, Germany, Australia price spikes

✅ Debate: retain coal vs. speed renewables, storage, and grid upgrades

 

Since when did electricity become a scarce resource?

I thought all the talk about greening the grid was about having renewable, sustainable, less polluting options to fulfill our growing need for power. Yet, increasingly, we are faced with news stories that indicate using power is bad in and of itself, even as flat electricity demand worries utilities.

The implication, I guess, is that we should be using less of it. But, I don’t want to use less electricity. I want to be able to watch TV, turn my lights on when the sun sets at 4 p.m. in the winter, keep my food cold and power my devices.

We once had a consensus that a reliable supply of power was essential to a growing economy and a high quality of life, a point underscored by brownout risks in U.S. markets.

I’m beginning to wonder if we still have that consensus.

And more importantly, if our decision makers have determined electricity is a vice as opposed to an essential of life – as debates over Alberta electricity policy suggest – you know what is going to happen next. Prices are going to rise, forcing all of us to use less.

How much would it hurt your bottom line if your electricity bill went up three-fold? How about seven-fold? That is the grim picture that Todd Beasley painted for us on Tuesday’s show.

Last week, he launched a campaign on behalf of Albertans for Sustainable Electricity, called Stop the Shock. He shared the results of an internal investor report that concluded Alberta’s power market overhaul would cost an estimated $50 billion to implement and could result in a three to seven-fold increase in electricity bills.

Now, my typical power bill averages $70 a month. That would be like having it grow to $210 a month, or just over $2,500 a year. If it’s a seven-fold increase that would be more like $5,000 a year. That may be manageable for some families, but I can think of a lot of things I’d rather do with $5,000 than pay more to keep my fridge running so my food doesn’t spoil.

For low-income families that would be a real hardship.

Beasley said Ontario’s inept handling of its electricity market and the phase-out of coal power resulted in price spikes that left more than 70,000 individuals facing energy poverty.

Germany and Australia realized they made the same mistake and are returning some electricity to coal.

Beasley shared a long list of Canadian firms – including our own Canadian Pension Plan – that are investing in coal development around the world. Meanwhile, Canadian governments remain in a mad rush to phase it out here. That’s not the only hypocrisy.

Rupert Darwall, author of Green Tyranny: Exposing the Totalitarian Roots of the Climate Industrial Complex, revealed in a recent column what he calls “the scandal at the heart of the EU’s renewable policies.”

Turns out most of their expansion in renewable energy has come from biomass in the form of wood. Not only does burning wood produce more CO2, it also eliminates carbon sinks.

To meet the EU’s 2030 target would require cutting down trees equivalent to the combined harvest in Canada and the United States. As he puts it, “Whichever way you look at it, burning the world’s carbon sinks to meet the EU’s arbitrary renewable energy targets is environmentally insane.”

Beasley’s group is trying to bring some sanity back to the discussion. The goal should be to move to a greener grid while maintaining abundant, reliable and cheap power, and examples like Texas grid improvements show practical steps. He thinks to achieve all these goals, coal should remain part of the mix. What do you think?

 

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Seattle City Light's Initiative Helps Over 93,000 Customers Reduce Electricity Bills

Seattle City Light Energy Efficiency Programs help 93,000 residents cut bills with rebates, home energy audits, weatherization, conservation workshops, and sustainability tools, reducing electricity use and greenhouse gas emissions across Seattle communities.

 

Key Points

They are utility programs that lower electricity use and bills via rebates, energy audits, and weatherization services.

✅ Rebates for ENERGY STAR appliances and efficient HVAC upgrades

✅ Free audits with tailored recommendations and savings roadmaps

✅ Weatherization aid for low-income households and renters

 

In a noteworthy achievement for both residents and the environment, Seattle City Light has successfully helped more than 93,000 customers reduce their electricity bills through various energy efficiency programs. This initiative not only alleviates financial burdens for many households, amid concerns about pandemic-era shut-offs that heightened energy insecurity, but also aligns with the city’s commitment to sustainability and responsible energy use.

The Drive for Energy Efficiency

Seattle City Light, the city’s publicly owned electric utility, has been at the forefront of promoting energy efficiency among its customers. Recognizing that energy costs can strain household budgets, the utility has developed a range of programs and tracks emerging utility rate designs to help residents lower their energy consumption and, consequently, their bills.

One of the main aspects of this initiative is the emphasis on education and awareness. By providing customers with tools and resources to understand their energy usage, City Light empowers residents to make informed choices that can lead to substantial savings and prepare for power outage events as well.

Key Programs and Services

Seattle City Light offers a variety of programs aimed at reducing energy consumption. Among the most popular are:

  1. Energy Efficiency Rebates: Customers can receive rebates for purchasing energy-efficient appliances, such as refrigerators, washing machines, and HVAC systems. These appliances are designed to consume less electricity than traditional models, resulting in lower energy bills over time.

  2. Home Energy Audits: Free energy audits are available for residential customers. During these audits, trained professionals assess homes for energy efficiency and provide recommendations on improvements. This personalized service allows homeowners to understand specific changes that can lead to savings.

  3. Weatherization Assistance: This program is particularly beneficial for low-income households. By improving insulation, sealing air leaks, and enhancing overall energy efficiency, residents can maintain comfortable indoor temperatures without over-relying on heating and cooling systems.

  4. Community Workshops: Seattle City Light conducts workshops that educate residents about energy conservation strategies. These sessions cover topics such as smart energy use, seasonal tips for reducing consumption, and the benefits of renewable energy sources, highlighting examples of clean energy engagement in other cities.

The Impact on Households

The impact of these initiatives is profound. By assisting over 93,000 customers in lowering their electricity bills, Seattle City Light not only provides immediate financial relief but also encourages a long-term commitment to energy conservation. This collective effort has resulted in significant reductions in overall energy consumption, contributing to a decrease in greenhouse gas emissions—a critical step in the fight against climate change.

Additionally, the programs have been particularly beneficial for low-income households. By targeting these communities, Seattle City Light ensures that the benefits of energy efficiency reach those who need them the most, promoting equity-focused regulation and access to essential resources.

Looking Ahead: Challenges and Opportunities

While the success of these initiatives is commendable, challenges remain. Fluctuating energy prices can still pose difficulties for many households, especially those on fixed incomes, as some utilities explore minimum charges for low-usage customers in their rate structures. Seattle City Light recognizes the need for ongoing support and resources to help residents navigate these financial challenges.

The utility is committed to expanding its programs to reach even more customers in the future. This includes enhancing outreach efforts to ensure that residents are aware of the available resources, even as debates like utility revenue in a free-electricity future shape planning, and potentially forming partnerships with local organizations to broaden the impact of its initiatives.

 

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Ontario Sets Electricity Rates at Off-Peak Price until February 7

Ontario Off-Peak Electricity Rate offers 8.2 cents per kWh for 24 hours, supporting Time-of-Use and Tiered Regulated Price Plan customers, including residential, small business, and farms, under Ontario Energy Board guidelines during temporary relief.

 

Key Points

A temporary 8.2 cents per kWh all-day price for RPP customers, covering TOU and Tiered users across Ontario.

✅ Applies 24 hours daily at 8.2 cents per kWh for 21 days

✅ Covers residential, small business, and farm RPP customers

✅ Valid for TOU and Tiered plans set by the Ontario Energy Board

 

 The Ontario government has announced electricity relief with electricity prices set at the off-peak price of 8.2 cents per kilowatt-hour, 24 hours per day for 21 days starting January 18, 2022, until the end of day February 7, 2022, for all Regulated Price Plan customers. The off-peak rate will apply automatically to residential, small businesses and farms who pay Time-of-Use or Tiered prices set by the Ontario Energy Board.

This rate relief includes extended off-peak rates to support small businesses, as well as workers and families spending more time at home while the province is in Modified Step Two of the Roadmap to Reopen.

As part of our mandate, we set the rates that your utility charges for the electricity you use in your home or small business. These rates appear on the Electricity line of your bill, and we administer protections such as disconnection moratoriums for residential customers. We also set the Delivery rates that cover the cost to deliver electricity to most residential and small business customers.

 

Types of electricity rates

For residential and small business customers that buy electricity from their utility, there are two different types of rates (also called prices here), and Ontario also provides stable electricity pricing for larger users. The Ontario Energy Board sets both once a year on November 1:

Time-of-Use (TOU)

With TOU prices, the price depends on when you use electricity, including options like ultra-low overnight pricing that encourage off-peak use.

There are three TOU price periods:

  • Off-peak, when demand for electricity is lowest and new offerings like the Ultra-Low Overnight plan can encourage shifting usage. Ontario households use most of their electricity – nearly two thirds of it – during off-peak hours.
  • Mid-peak, when demand for electricity is moderate. These periods are during the daytime, but not the busiest times of day, and utilities like BC Hydro are exploring similar TOU structures as well.
  • On-peak, when demand for electricity is generally higher. These are the busier times of day – generally when people are cooking, starting up their computers and running heaters or air conditioners.

 

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Solar PV and wind power in the US continue to grow amid favourable government plans

US Renewable Power Outlook 2030 projects surging capacity, solar PV and wind growth, grid modernization, and favorable tax credits, detailing market trends, CAGR, transmission expansion, and policy drivers shaping clean energy generation and consumption.

 

Key Points

A forecast of US power capacity, generation, and consumption, highlighting solar, wind, tax credits, and grid modernization.

✅ Targets 48.4% renewable capacity share by 2030

✅ Strong growth in solar PV and onshore wind installations

✅ Investment and tax credits drive grid and transmission upgrades

 

GlobalData’s latest report, ‘United States Power Market Outlook to 2030, Update 2021 – Market Trends, Regulations, and Competitive Landscape’ discusses the power market structure of the United States and provides historical and forecast numbers for capacity, generation and consumption up to 2030. Detailed analysis of the country’s power market regulatory structure, competitive landscape and a list of major power plants are provided. The report also gives a snapshot of the power sector in the country on broad parameters of macroeconomics, supply security, generation infrastructure, transmission and distribution infrastructure, about a quarter of U.S. electricity from renewables in recent years, electricity import and export scenario, degree of competition, regulatory scenario, and future potential. An analysis of the deals in the country’s power sector is also included in the report.

Renewable power held a 19% share of the US’s total power capacity in 2020, and in that year renewables became the second-most prevalent source in the U.S. electricity mix by generation; this share is expected to increase significantly to 48.4% by 2030. Favourable policies introduced by the US Government will continue to drive the country’s renewable sector, particularly solar photovoltaics (PV) and wind power, with wind now the most-used renewable source in the U.S. generation mix. Installed renewable capacity* increased from 16.5GW in 2000 to 239.2GW in 2020, growing at a compound annual growth rate (CAGR) of 14.3%. By 2030, the cumulative renewable capacity is expected to rise to 884.6GW, growing at a CAGR of 14% from 2020 to 2030. Despite increase in prices of renewable equipment, such as solar modules, in 2021, the US renewable sector will show strong growth during the 2021 to 2030 period as this increase in equipment prices are short term due to supply chain disruptions caused by the Covid-19 pandemic.

The expansion of renewable power capacity during the 2000 to 2020 period has been possible due to the introduction of federal schemes, such as Production Tax Credits, Investment Tax Credits and Manufacturing Tax Credits. These have massively aided renewable installations by bringing down the cost of renewable power generation and making it at par with power generated from conventional sources. Over the last few years, the cost of solar PV and wind power installations has declined sharply, and by 2023 wind, solar, and batteries made up most of the utility-scale pipeline across the US, highlighting investor confidence. Since 2010, the cost of utility-scale solar PV projects decreased by around 82% while onshore wind installations decreased by around 39%. This has supported the rapid expansion of the renewable market. However, the price of solar equipment has risen due to an increase in raw material prices and supply shortages. This may slightly delay the financing of some solar projects that are already in the pipeline.

The US will continue to add significant renewable capacity additions during the forecast period as industry outlooks point to record solar and storage installations over the coming years, to meet its target of reaching 80% clean energy by 2030. In November 2021, President Biden signed a $1tr Infrastructure Bill, within which $73bn is designated to renewables. This includes not just renewable capacity building, but also strengthening the country’s power grid and laying new high voltage transmission lines, both of which will be key to driving solar and wind power capacity additions as wind power surges in the U.S. electricity mix nationwide.

The US was one of the worst hit countries in the world due to the Covid-19 pandemic in 2020. With respect to the power sector, the electricity consumption in the country declined by 2.5% in 2020 as compared to 2019, even as renewable electricity surpassed coal in 2022 in the generation mix, highlighting continued structural change. Power plants that were under construction faced delays due to unavailability of components due to supply chain disruptions and unavailability of labour due to travel restrictions.

According to the US Energy Information Administration, 61 power projects, having a total capacity of 2.4GWm which were under construction during March and April 2020 were delayed because of the Covid-19 pandemic. Among renewable power technologies, solar PV and wind power projects were the most badly affected due to the pandemic.

In March and April 2020, 53 solar PV projects, having a total capacity of 1.3GW, and wind power projects, having a total capacity of 1.2GW, were delayed due to the Covid-19 pandemic. Moreover, several states suspended renewable energy auctions due to the pandemic.

For instance, New York State Energy Research and Development Authority (NYSERDA) had issued a new offshore wind solicitation for 1GW and up to 2.5GW in April 2020, but this was suspended due to the Covid-19 pandemic. In July 2020, the authority relaunched the tender for 2.5GW of offshore wind capacity, with a submission deadline in October 2020.

To ease the financial burden on consumers during the pandemic, more than 1,000 utilities in the country announced disconnection moratoria and implemented flexible payment plans. Duke Energy, American Electric Power, Dominion Power and Southern California Edison were among the major utilities that voluntarily suspended disconnections.

 

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Energy experts: US electric grid not designed to withstand the impacts of climate change

Summer Power Grid Reliability and Climate Risk drives urgent planning as extreme heat, peak demand, drought, and aging infrastructure strain ERCOT, NERC regions, risking outages without renewables integration and climate-informed grid modeling.

 

Key Points

Assessment of how extreme weather and demand stress the US grid, informing climate-smart planning to reduce outages.

✅ Many operators rely on historical weather, not climate projections

✅ NERC flags elevated blackout risk amid extreme heat and drought

✅ Renewables and storage can boost capacity and cut emissions

 

As heat ramps up ahead of what forecasters say will be a hotter than normal summer, electricity experts and officials are warning that states may not have enough power to meet demand in the coming months. And many of the nation's grid operators are also not taking climate change into account in their planning, despite available grid resilience guidance that could inform upgrades, even as extreme weather becomes more frequent and more severe.

Power operators in the Central US, in their summer readiness report, have already predicted "insufficient firm resources to cover summer peak forecasts." That assessment accounted for historical weather and the latest NOAA outlook that projects for more extreme weather this summer.

But energy experts say that some power grid operators are not considering how the climate crisis is changing our weather — including more frequent extreme events — and that is a problem if the intent is to build a reliable power grid while accelerating investing in carbon-free electricity across markets.

"The reality is the electricity system is old and a lot of the infrastructure was built before we started thinking about climate change," said Romany Webb, a researcher at Columbia University's Sabin Center for Climate Change Law. "It's not designed to withstand the impacts of climate change."

Webb says many power grid operators use historical weather to make investment decisions, rather than the more dire climate projections, simply because they want to avoid the possibility of financial loss, even as climate-related credit risks for nuclear plants are being flagged, for investing in what might happen versus what has already happened. She said it's the wrong approach and it makes the grid vulnerable.

"We have seen a reluctance on the part of many utilities to factor climate change into their planning processes because they say the science around climate change is too uncertain," Webb said. "The reality is we know climate change is happening, we know the impact it has in terms of more severe heatwaves, hurricanes, drought, with recent hydropower constraints in British Columbia illustrating the risks, and we know that all of those things affect the electricity system so ignoring those impacts just makes the problems worse."

An early heatwave knocked six power plants offline in Texas earlier this month. Residents were asked to limit electricity use, keeping thermostats at 78 degrees or higher and, as extreme heat boosts electricity bills for consumers, avoid using large appliances at peak times. The Electric Reliability Council of Texas, or ERCOT, in its seasonal reliability report, said the state's power grid is prepared for the summer and has "sufficient" power for "normal" summer conditions, based on average weather from 2006 to 2020.

But NOAA's recently released summer outlook forecasts above average temperatures for every county in the nation.

"We are continuing to design and site facilities based on historical weather patterns that we know in the age of climate change are not a good proxy for future conditions," Webb said.

When asked if the agency is creating a blind spot for itself by not accounting for extreme weather predictions, an ERCOT spokesperson said the report "uses a scenario approach to illustrate a range of resource adequacy outcomes based on extreme system conditions, including some extreme weather scenarios."

The North American Electric Reliability Corporation, or NERC — a regulating authority that oversees the health of the nation's electrical infrastructure — has a less optimistic projection.

In a recent seasonal reliability report, NERC placed Texas at "elevated risk" for blackouts this summer. It also reported that while much of the nation will have adequate electricity this summer, several markets are at risk of energy emergencies.

California grid operators, who recently avoided widespread rolling blackouts as heat strained the grid, in its summer reliability report also based its readiness analysis on "the most recent 20 years of historical weather data." The report also notes the assessment "does not fully reflect more extreme climate induced load and supply uncertainties."

Compounding the US power grid's supply and demand problem is drought: NERC says there's been a 2% loss of reliable hydropower from the nation's power-producing dams. Add to that the rapid retirement of many coal power plants — all while nearly everything from toothbrushes to cars are now electrified. Energy experts say adding more renewables into the mix will have the dual impact of cutting climate change inducing greenhouse gas emissions but also increasing the nation's power supply, aligning with efforts such as California's 100% carbon-free mandate that aim to speed the transition.
 

 

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Electric vehicles to transform the aftermarket … eventually

Heavy-Duty Truck Electrification is disrupting the aftermarket as diesel declines: fewer parts, regenerative braking, emissions rules, e-drives, gearboxes, and software engineering needs reshape service demand, while ICE fleets persist for years.

 

Key Points

Transition of heavy trucks to EV systems, reducing parts and emissions while reshaping aftermarket service and skills.

✅ 33% fewer parts; regenerative braking slashes brake wear

✅ Diesel share declines; EVs and natural gas slowly gain

✅ Aftermarket shifts to e-drives, gearboxes, software and service

 

Those who sell parts and repair trucks might feel uneasy when reports emerge about a coming generation of electric trucks.

There are reportedly about 33% fewer parts to consider when internal combustion engines and transmissions are replaced by electric motors. Features such as regenerative braking are expected to dramatically reduce brake wear. As for many of the fluids needed to keep components moving? They can remain in their tanks and drums.

Think of them as disruptors. But presenters during the annual Heavy Duty Aftermarket Dialogue are stressing that the changes are not coming overnight. Chris Patterson, a consultant and former Daimler Trucks North America CEO, noted that the Daimler electrification plan underscores the shift as he counts just 50 electrified heavy trucks in North America.

About 88% of today’s trucks run on diesel, with the remaining 12% mostly powered by gasoline, said John Blodgett, MacKay and Company’s vice-president of sales and marketing. Five years out, even amid talk of an EV inflection point, he expects 1% to be electric, 2% to be natural gas, 12% to be gasoline, and 84% on diesel.

But a decade from now, forecasts suggest a split of 76% diesel, 11% gasoline, 7% electric, and 5% natural gas, with a fraction of a percent relying on hydrogen-electric power. Existing internal combustion engines will still be in service, and need to be serviced, but aftermarket suppliers are now preparing for their roles in the mix, especially as Canada’s EV opportunity comes into focus for North American players.

“This is real, for sure,” said Delphi Technologies CEO Rick Dauch.

Aftermarket support is needed
“As programs are launched five to six years from now, what are the parts coming back?” he asked the crowd. “Braking and steering. The fuel injection business will go down, but not for 20-25 years.” The electric vehicles will also require a gear box and motor.

“You still have a business model,” he assured the crowd of aftermarket professionals.

Shifting emissions standards are largely responsible for the transformation that is occurring. In Europe, Volkswagen’s diesel emissions scandal and future emissions rules of Euro 7 will essentially sideline diesel-powered cars, even as electric buses have yet to take over transit systems. Delphi’s light-duty diesel business has dropped 70% in just five years, leading to plant closures in Spain, France and England.

“We’ve got a billion-dollar business in electrification, last year down $200 million because of the downturn in light-duty diesel controllers,” Dauch said. “We think we’re going to double our electrification business in five years.”

That has meant opening five new plants in Eastern European markets like Turkey, Romania and Poland alone.

Deciding when the market will emerge is no small task, however. One new plant in China offered manufacturing capacity in July 2019, but it has yet to make any electric vehicle parts, highlighting mainstream EV challenges tied to policy shifts, because the Chinese government changed the incentive plans for electric vehicles.

‘All in’ on electric vehicles
Dana has also gone “all in” on electrification, said chairman and CEO Jim Kamsickas, referring to Dana’s work on e-drives with Kenworth and Peterbilt. Its gasket business is focusing on the needs of battery cooling systems and enclosures.

But he also puts the demand for new electric vehicle systems in perspective. “The mechanical piece is still going to be there.”

The demand for the new components and systems, however, has both companies challenged to find enough capable software engineers. Delphi has 1,600 of them now, and it needs more.

“Just being a motor supplier, just being an inverter supplier, just being a gearbox supplier itself, yes you’ll get value out of that. But in the longhaul you’re going to need to have engineers,” Kamsickas said of the work to develop systems.

Dauch noted that Delphi will leave the capital-intensive work of producing batteries to other companies in markets like China and Korea. “We’re going to make the systems that are in between – inverters, chargers, battery management systems,” he said.

Difficult change
But people working for European companies that have been built around diesel components are facing difficult days. Dauch refers to one German village with a population of 1,200, about 800 of whom build diesel engine parts. That business is working furiously to shift to producing gasoline parts.

Electrification will face hurdles of its own, of course. Major cities around the world are looking to ban diesel-powered vehicles by 2050, but they still lack the infrastructure needed to charge all the cars and truck fleet charging at scale, he added.

Kamsickas welcomes the disruptive forces.

“This is great,” he said. “It’s making us all think a little differently. It’s just that business models have had to pivot – for you, for us, for everybody.”

They need to be balanced against other business demands, including evolving cross-border EV collaboration dynamics, too.

Said Kamsickas: “Working through the disruption of electrification, it’s how do you financially manage that? Oh, by the way, the last time I checked there are [company] shareholders and stakeholders you need to take care of.”

“It’s going to be tough,” Dauch agreed, referring to the changes for suppliers. “The next three to four years are really going to be game changes. “There’ll be some survivors and some losers, that’s for sure.”

 

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N.S. abandons Atlantic Loop, will increase wind and solar energy projects

Nova Scotia Clean Power Plan 2030 pivots from the Atlantic Loop, scaling wind and solar, leveraging Muskrat Falls via the Maritime Link, adding battery storage and transmission upgrades to decarbonize grid and retire coal.

 

Key Points

Nova Scotia's 2030 roadmap to replace coal with wind, solar, hydro imports, storage, and grid upgrades.

✅ 1,000 MW onshore wind to supply 50% by 2030

✅ Battery storage sites and New Brunswick transmission upgrades

✅ Continued Muskrat Falls imports via Maritime Link

 

Nova Scotia is abandoning the proposed Atlantic Loop in its plan to decarbonize its electrical grid by 2030 amid broader discussions about independent grid planning nationwide, Natural Resources and Renewables Minister Tory Rushton has announced.

The province unveiled its clean power plan calling for 30 per cent more wind power and five per cent more solar energy in the Nova Scotia power grid over the coming years. Nova Scotia's plan relies on continued imports of hydroelectricity from the Muskrat Falls project in Labrador via the Emera-owned Maritime Link.

Right now Nova Scotia generates 60 per cent of its electricity by burning fossil fuels, mostly coal, and some increased use of biomass has also factored into the mix. Nova Scotia Power must close its coal plants by 2030 when 80 per cent of electricity must come from renewable sources in order reduce greenhouse gas emissions causing climate changes.

Critics have urged reducing biomass use in electricity generation across the province.

The clean power plan calls for an additional 1,000 megawatts of onshore wind by 2030 which would then generate 50 per cent of the the province's electricity, while also advancing tidal energy in the Bay of Fundy as a complementary source.    

"We're taking the things already know and can capitalize on while we build them here in Nova Scotia," said Rushton, "More importantly, we're doing it at a lower rate so the ratepayers of Nova Scotia aren't going to bear the brunt of a piece of equipment that's designed and built and staying in Quebec."

The province says it can meet its green energy targets without importing Quebec hydro through the Atlantic loop. It would have brought hydroelectric power from Quebec into New Brunswick and Nova Scotia via upgraded transmission links. But the government said the cost is prohibitive, jumping to $9 billion from nearly $3 billion three years ago with no guarantee of a secure supply of power from Quebec.

"The loop is not viable for 2030. It is not necessary to achieve our goal," said David Miller, the provincial clean energy director. 

Miller said the cost of $250 to $300 per megawatt hour was five times higher than domestic wind supply.

Some of the provincial plan includes three new battery storage sites and expanding the transmission link with New Brunswick. Both were Nova Scotia Power projects paused by the company after the Houston government imposed a cap on the utility's rate increased in the fall of 2022.

The province said building the 345-kilovolt transmission line between Truro, N.S., and Salisbury, N.B., and an extension to the Point Lepreau Nuclear Generating Station, as well as aligning with NB Power deals for Quebec electricity underway, would enable greater access to energy markets.

Miller says Nova Scotia Power has revived both.

Nova Scotia Power did not comment on the new plan, but Rushton spoke for the company.

"All indications I've had is Nova Scotia Power is on board for what is taking place here today," he said.

 

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