Turbines spinning power, problems

By The Oakland Tribune


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New wind farms could generate up to 7 percent of U.S. electricity in 15 years, but scientists say more attention must be paid to the threat those spinning blades present to birds and bats before the construction boom starts.

Commercial wind-generating capacity already has quadrupled to more than 11,000 megawatts since 2000, enough to power more than 3 million average homes for a year. Yet it remains a marginal part of the nation's energy portfolio, providing about 1 percent of the nation's electricity today.

President Bush and other wind-energy advocates see great potential. But a study released by the National Academies of Science said not enough is known about the threat such an expansion poses to vulnerable species such as night-migrating songbirds, bats, hawks and eagles.

"The report is a step forward. It basically says we can dramatically expand wind power, but there are some issues... we have to address," said Peter Galvin, conservation director at the Center for Biological Diversity, which has fought to reduce bird kills at the Altamont Pass wind farm.

"Provided we can resolve those and put some teeth in the regulations, there's no reason wind power couldn't provide up to a quarter of the nation's power."

The study, ordered by Congress, is "the most complete compilation of environmental impacts, and impacts on humans, positive and negative, from wind energy that's yet been done," said Paul Risser, chairman of the committee that wrote the report and a researcher at the University of Oklahoma at Norman.

"The human impacts of wind farms can be both positive and negative," he said.

Overall, the report noted, wind-energy development benefits wide areas via reduced air pollutants, while the environmental costs, such as ecological effects and bird deaths, occur locally.

But the panel declined to say whether benefits outweigh costs or vice versa, leaving that decision to state and local officials and the public.

The study assumed wind's share of the nation's power supply would hit a maximum of 7 percent by 2020. Such growth requires as many as 36,000 new turbines, each with blades equal to the wingspan of a 747 jet on towers up to 300 feet tall, all on high ground where the wind blows an average of 10 mph or better.

Federal regulation of wind projects on private land is minimal, the report observes. And while some states have developed guidelines, wind energy is such a recent addition to power production in most areas that most states are relatively inexperienced at planning and regulation. The exception is a handful of states such as Texas and California that have large concentrations of wind farms.

The good side of wind energy, of course, is that once in place, turbines don't pollute air or water. The report figures that if wind power does produce 7 percent of the nation's energy by 2020, it would offset as much as 4.5 percent of emissions of greenhouse-gas carbon dioxide produced from electricity generation.

But the downsides can be considerable, and the Altamont Pass wind farm is often cited as an example of the dangers of installing turbines without paying careful attention to environmental costs.

"The Altamont Pass was a bad place to build," said Elizabeth Murdock, executive director of the Golden Gate Audubon Society, which sued Alameda County and the wind farm operators over bird deaths.

"If we knew 20 years ago what we know now, we would probably never build there."

The wind farm boasts more than 5,000 turbines and sits in the midst of a crucial bird migration corridor and the world's largest known Golden Eagle nesting territory.

A 2004 study figured the farm's blades killed 1,300 raptors a year. In January, Golden Gate Audubon Society settled its lawsuit. The companies agreed to halve the number of bird kills by 2009 and find a way to make power generation and birds co-exist.

Lessons learned there will be disseminated nationwide, Murdock added. "We are on the path right now to a sustainable solution to Altamont Pass. Whether we've accomplished it, we can't say now. But we are on the path."

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Affordable, safe' nuclear power is key to reaching Canada's climate goals: federal minister

Canada Nuclear Power Expansion highlights SMRs, clean energy, net-zero targets, and robust regulation to deliver safe, reliable baseload electricity, spur investment, and economically decarbonize remote communities, mines, and grids across provinces securely.

 

Key Points

Canada Nuclear Power Expansion grows SMRs and reactors to meet climate targets with safe, reliable baseload power.

✅ Deploys SMRs for remote communities, mines, and industrial sites

✅ Streamlines regulation to ensure safety, trust, and timely approvals

✅ Provides clean, reliable baseload to hit net-zero electricity goals

 

Canada must expand its nuclear power capacity if it is to reach its climate targets, according to Canadian Minister of Natural Resources Seamus Oregan.

Speaking to the Canadian Nuclear Association’s annual conference, Seamus O’Regan said the industry has to grow.

“As the world tackles a changing climate, nuclear power is poised to provide the next wave of clean, affordable, safe and reliable power,” he told a packed room.

The Ottawa conference was the largest the industry has run with dozens of companies and more than 900 people in attendance. Provincial cabinet ministers from Saskatchewan and Ontario were also there. Those two provinces, along with New Brunswick, signed a memorandum in December as part of a premiers' nuclear initiative to work together on small modular reactor technology.

People need to know that it’s safe

Small modular reactors are units that produce less power than large generating stations, but can be constructed easier and are expected to be safer to operate. Canadian firms have about a dozen of the proposed reactors working their way through the regulatory process, with New Brunswick's SMR plans drawing scrutiny.

The smaller reactors could be used in groups to replace large units, but the industry also hopes to use them in rural or isolated communities, mines or even oilsands projects, potentially replacing the diesel power generators some remote communities use.

The Canadian government issued a road map to support the industry in 2018 and O’Regan committed Thursday to putting some teeth on that proposal later this year, as provinces like Ontario explore new large-scale nuclear plants to meet demand, with specific steps the government will take.

“We have been working so hard to support this industry. We are placing nuclear energy front and centre, something that has never been done before.”

O’Regan said the government’s role is a clear, streamlined regulatory system that will promote the industry, but also help the Canadian public to trust the reactors will be safe.

“People need to know that it’s safe. They need to know that it’s regulated. They need to know that it’s safe for them,” he said.

The Liberals promised during the campaign that they would gradually reduce Canada’s carbon emissions even after hitting the targets in the Paris Agreement by 2030. By 2050, Prime Minister Justin Trudeau said he expects Canada to be carbon neutral, mindful of lessons from Europe's power crisis on reliability.

The government hasn’t outlined how it will achieve that goal. O’Regan said more detail is coming, but it’s clear that nuclear is going to have to play a major part, echoing the UK’s green industrial revolution approach to reactor deployment.

“I have not seen a credible plan for net zero without nuclear as part of the mix. I don’t think we are going to be relying on any one technology. I think it’s going to be a whole host of things.”

O’Regan said large investors are looking for countries that are on the path to net zero.

“Everybody has their shirt sleeves rolled up and we know we need to work on this, not only do we have to work on this for the urgency of the planet, but we have to work on it for Canadian jobs.”

He added, “We must focus on those areas where Canada can and should lead, like nuclear.”

Canadians are ready to take a fresh look at nuclear

John Gorman, president of the Canadian Nuclear Association, said he was thrilled with O’Regan’s comments.

“I took the minister’s remarks this morning as being perhaps the strongest language of support for the nuclear industry in a number of years.”

Gorman said the industry is in strong shape and is working with utility companies such as Ontario Power Generation and regulators to move projects forward.

“It’s this amazing collaboration and coordination that is enabling us to beat others to the roll out of these small modular reactors,” he said.

He said provinces that might not have looked at nuclear before now have an incentive to do it, because of climate change. A former solar industry executive, Gorman said solar and wind power are important, as Ontario plans to seek new wind and solar power to ease supply pressures, but they won’t be able to keep up with rising power demands.

“Globally we are seeing increased recognition that climate change is real and that it’s a crisis, we are also seeing recognition that we are not making as much progress on decarbonizing our electricity system as we thought,” he said. “Canadians are ready to take a fresh look at nuclear and see the real facts.”

 

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US judge orders PG&E to use dividends to pay for efforts to reduce wildfire risks

PG&E dividend halt for wildfire mitigation directs cash from shareholders to tree clearing, wildfire risk reduction, and probation compliance under Judge William Alsup, amid bankruptcy, Camp Fire liabilities, and power line vegetation management mandates.

 

Key Points

A court-ordered dividend halt funding vegetation clearance and wildfire mitigation as PG&E meets probation terms.

✅ Judge Alsup bars dividends until mitigation targets met

✅ 375,000 trees cleared near power lines in high-risk zones

✅ Measures tied to probation amid bankruptcy and liabilities

 

A U.S. judge said on Tuesday that PG&E may not resume paying dividends and must use the money to fund its plan for cutting down trees to reduce the risk of wildfires in California, stopping short of more costly measures he proposed earlier this year.

The new criminal probation terms for PG&E are modest compared with ones the judge had in mind in January and that PG&E said could have cost upwards of $150 billion.

The terms will, however, keep PG&E under the supervision of Judge William Alsup of the U.S. District Court for the Northern District of California and hold the company, which also is in Chapter 11 bankruptcy and whose bankruptcy plan has drawn support from wildfire victims, to its target for clearing areas around its power lines of some 375,000 trees this year.

PG&E's probation stems from its felony conviction after a deadly 2010 natural gas pipeline blast in San Bruno, California, near San Francisco, that killed eight people and injured 58 others.

PG&E filed for bankruptcy protection on Jan. 29 in anticipation of liabilities from wildfires, including a catastrophic 2018 blaze, the Camp Fire, for which PG&E later pleaded guilty to 85 counts in state court. It killed 86 people in the deadliest and most destructive wildfire in California history.

At a January hearing, Alsup, who is overseeing PG&E's probation, said he felt compelled to propose additional probation terms in the aftermath of Camp Fire. San Francisco-based PG&E expects its equipment will be found to have caused the blaze.

The probation process is separate from San Francisco-based PG&E's bankruptcy filing and from operational measures such as its pandemic response and shutoff moratorium implemented to protect customers.

As the company faces $30 billion in wildfire liabilities and bankruptcy proceedings and has opened a wildfire assistance program for affected residents, the energy company is expected to name as its new chief executive Bill Johnson, a source said on Tuesday. Johnson has been the CEO of the Tennessee Valley Authority since 2013 and is retiring on Friday.

Additional probation terms imposed by Alsup on Tuesday will require PG&E to meet goals in a wildfire mitigation plan it unveiled in February.

The goals include removing 375,000 dead, dying or hazardous trees from areas at high risk of wildfires in 2019, compared with 160,000 last year.

The judge said PG&E will not be able to pay shareholders until it complies with his new probation terms.

Shares fell 2% on Tuesday to close at $17.66 on the New York Stock Exchange and are down 63% since November 2018 due to concerns about the company's bankruptcy and wildfire liabilities, though the utility has said rates are set to stabilize in 2025 as part of its long-term plan. The shares traded as low as $5.07 in January.

PG&E in December 2017 suspended its quarterly cash dividend, while continuing to pay significant property taxes to California counties, citing uncertainty about liabilities from wildfires in October of that year that struck Northern California.

PG&E paid $798 million in dividends in 2017 and $925 million in 2016, a period in which the company did a poor job of clearing areas around its power lines of hazardous trees, according to Alsup.

Money meant for shareholders should have been spent on efforts to reduce wildfire risks in recent years, Alsup said at Tuesday's hearing.

"PG&E has started way more than its share of these fires," Alsup said.

"I want to see the people of California safe," the judge added.

Lawyers for PG&E did not contest the new terms, which the company considers more feasible than terms Alsup proposed in January.

To comply with the terms Alsup proposed in January, PG&E said it would have to remove 100 million trees. The company added that shutting power lines during high winds as Alsup proposed would not be feasible because the lines traverse rural areas to service cities and suburbs.

Idling lines could also affect the power grid in other states, PG&E said.

Alsup on Tuesday said he was still considering his proposal to require PG&E to shut down power lines during windy weather to prevent tree branches from making contact and sparking wildfires linked to power lines in the region.

 

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OPINION Rewiring Indian electricity

India Power Sector Crisis: a tangled market of underused plants, coal shortages, cross-subsidies, high transmission losses, and weak PPAs, requiring deregulation, power exchanges, and cost-reflective tariffs to fix insolvency and outages.

 

Key Points

India power market failure from subsidies, coal shortages, and losses, needing deregulation and reflective pricing.

✅ Deregulate to enable spot trading on power exchanges

✅ End cross-subsidies; charge cost-reflective tariffs

✅ Secure coal supply; cut T&D losses and theft

 

India's electricity industry is in a financial and political tangle.

Power producers sit on thousands of megawatts of underutilized plant, while consumers face frequent power cuts, both planned and unplanned.

Financially troubled generators struggle to escape insolvency proceedings. The state-owned banks that have mostly financed power utilities fear that debts of troubled utilities totaling 1.74 trillion rupees will soon go bad.

Aggressive bidding for supply contracts and slower-than-expected demand growth, including a recent demand slump in electricity use, is the root cause. The problems are compounded by difficulties in securing coal and other fuels, high transmission losses, electricity theft and cash-starved distribution companies.

But India's 36 state and union territory governments are contributing mightily to this financial and economic mess. They persist with populist cross-subsidies -- reducing charges for farmers and households at the cost of nonagricultural businesses, especially energy-intensive manufacturing sectors such as steel.

The states refuse to let go of their control over how electricity is produced, distributed and consumed. And they are adamant that true markets, with freedom for large industrial users to buy power at market-determined rates from whichever utility they want at power exchanges -- will not become a reality in India.

State politicians are driven mainly by the electoral need to appease farmers, India's most important vote bank, who have grown used to decades of nearly-free power.

New Delhi is therefore relying on short-term fixes instead of attempting to overhaul a defunct system. Users must pay the real cost of their electricity, as determined by a properly integrated national market free of state-level interference if India's power mess is to be really addressed.

As of Aug. 31, the country's total installed production capacity was 344,689 MW, underscoring its status as the third-largest electricity producer globally by output. Out of that, thermal power comprising coal, gas and diesel accounted for 64%, hydropower 13% and renewables accounted for 20%. Commercial and industrial users accounted for 55% of consumption followed by households on 25% and the remaining 20% by agriculture.

Coal-fired power generation, which contributes roughly 90% of thermal output and the bulk of the financially distressed generators, is the most troubled segment as it faces a secular decline in tariffs due to increasing competition from highly subsidized renewables (which also benefit from falling solar panel costs), coal shortages and weak demand.

The Central Electricity Act (CEA) 2003 opened the gates of the country's power sector for private players, who now account for 45% of generating capacity.

But easy credit, combined with an overconfident estimation of the risks involved, emboldened too many investors to pile in, without securing power purchase agreements (PPAs) with distribution companies.

As a result, power capacity grew at an annual compound rate of 11% compared to demand at 6% in the last decade leading to oversupply.

This does not mean that the electricity market is saturated. Merely that there are not enough paying customers. Distributors have plenty of consumers who will not or cannot pay, even though they have connections. There is huge unmet demand for power. There are 32 million Indian homes -- roughly 13% of the total -- mostly rural and poor with no access to electricity.

Moreover, consumption by those big commercial and industrial users which do not enjoy privileged rates is curbed by high prices, driven up by the cost of subsidizing others, extra charges on exchange-traded power and transmission and distribution losses (including theft) of 20-30%.

With renewables increasingly becoming cheaper, financially stressed distributors are avoiding long-term power purchase agreements, preferring spot markets. Meanwhile, coal shortages force generators to buy expensive imported coal supplies or cut output. The operating load for most private generators, which suffer particularly acute coal shortages in compared to state-owned utilities, has fallen from 84% in 2009-2010 to 55% now.

Smoothing coal supplies should be the top priority. Often coal is denied to power generators without long-term purchase contracts. Such discrimination in coal allocation prevails -- because the seller (state-run Coal India and its numerous subsidiaries) is an inefficient monopolist which cannot produce enough and rations coal supplies, favoring state-run generators over private.

To help power producers, New Delhi plans measures including auctioning power sales contracts with assured access to coal. However, even though coal and electricity shortages eased recently, such short-term fixes won't solve the problem. With electricity prices in secular decline, distributors are not seeking long-term supply contracts -- rather they are often looking for excuses to get out of existing agreements.

India needs a fundamental two-step reform. First, the market must be deregulated to allow most bulk suppliers and users to move to power trading exchanges, which currently account for just 10% of the market.

This would lead to genuine price discovery in a spot market and, in time, lead to the trading of electricity futures contracts. That would help in consumers and producers hedge their respective costs and revenues and safeguard their economic positions without any need for government intervention.

The second step to a healthy electricity industry is for consumers to pay the real cost of power. Cross-subsidization must end. That would promote optimal electricity use, innovation and environmental protection. Farmers enjoying nearly-free power create ecological problems by investing in water-guzzling crops such as rice and sugar cane.

Most industrial consumers, who do not have power supply privileges, have their businesses distorted and delayed by high prices. Lowering their costs would encourage power-intensive manufacturing to expand, and in the process, boost electricity demand and improve capacity utilization.

Of course, cutting theft is central to making consumers pay their way. Government officials must stop turning a blind eye to theft, especially when such transmission and distribution losses average 20%.

Politicians who want to continue subsidizing farmers or assist the poor can do so by paying cash out directly to their bank accounts, instead of wrongly relying on the power sector.

Such market-oriented reforms have long been blocked by state-level politicians, who now enjoy the influence born of operating subsidies and interfering in the sector. New Delhi must address this opposition. Narendra Modi, as a self-styled reforming prime minister, should have the courage to bite this bullet and convince state governments (starting with those ruled by his Bharatiya Janata Party) to reform. To encourage cooperation, he could offer states securing real improvements an increased share of centrally collected taxes.

Ritesh Kumar Singh is to be the chief economist of the new policy research and advocacy company Indonomics Consulting. He is former assistant director of the Finance Commission of India.

 

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BC Hydro says province sleeping in, showering less in pandemic

BC Hydro pandemic electricity trends reveal weekend-like energy consumption patterns: later morning demand, earlier evenings, more cooking, streaming on smart TVs, and work-from-home routines, with tips to conserve using laptops and small appliances.

 

Key Points

Weekend-like shifts in power demand from work-from-home routines: later mornings, earlier evenings, and more streaming.

✅ Later morning electricity demand; earlier evening peaks

✅ More cooking and baking; increased streaming after dinner

✅ Conservation tips: laptops, small appliances, smart TVs

 

The latest report on electricity usage in British Columbia reveals the COVID-19 pandemic has created an atmosphere where every day feels like a Saturday, a pattern also reflected in BC electricity demand during peak seasons.

BC Hydro says overall power usage hasn't changed much, but similar Ontario electricity demand shifts suggest regional differences, while Manitoba demand fell more noticeably, and a survey of 500 people shows daily routines have shifted dramatically since mid-March when pandemic-related closures began.

The hydro report says, with nearly 40 per cent of B.C. residents working from home, trends in residential electricity use confirm almost half are sleeping in and eating breakfast later, while about a quarter say they are showering less.

Those patterns more closely resemble what hydro says is typical weekend power consumption, and could influence time-of-use rates as electricity demand occurs later in the morning and earlier in the evening.

The report also finds many people are cooking and baking more than before the pandemic, preparing the evening meal earlier, streaming or viewing more television after dinner even as Ottawa's electricity consumption dipped earlier in the pandemic, and 80 per cent are going to bed later.

Although electricity use is normal for this time of year, hydro says homebound residents can conserve by using laptops instead of desktops, small appliances such as Instant Pots instead of ovens, and streaming movies or TV shows on a smart televisions instead of game consoles, even as Hydro One peak rates continue to shape consumption patterns elsewhere.

 

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Hydro One and Alectra announce major investments to strengthen electricity infrastructure and improve local reliability in the Hamilton area

Hydro One and Alectra Hamilton Grid Upgrades will modernize electricity infrastructure with new transformers, protection devices, transmission and distribution improvements, tree trimming, pole replacements, and line refurbishments to boost reliability and reduce outages across region.

 

Key Points

A $250M plan to modernize Hamilton transmission and distribution, reducing outages and improving reliability by 2022.

✅ New transformers and protection devices to cut outages

✅ Refurbished 1915 line powering Hamilton West Mountain

✅ Tree trimming and pole replacements across 1,260 km

 

Hydro One Networks Inc. (Hydro One), Ontario's largest electricity transmission and distribution company whose delivery rates recently increased, and Alectra Utilities have announced they expect to complete approximately $250 million of work in the Hamilton area by 2022 to upgrade local electricity infrastructure and improve service reliability.

As part of these plans to strengthen the electricity grid in the Hamilton region, where utilities must adapt to climate change pressures, investments are expected to include:

installing quieter, more efficient transformers in four stations across Hamilton to assist in reducing the number of outages;
replacing protection and switching devices across the city to shorten outage restoration times, reflecting how transmission line work underpins reliability;
refurbishing a power line originally installed in 1915 that is critical to powering the Hamilton West Mountain area; and,
trimming hazardous trees across more than 1,260 km of overhead powerlines and replacing more than 270 poles.
Hydro One will be working with Alectra Utilities to replace aging infrastructure at Elgin transmission station.

"A loss of power grinds life to a halt, impacting businesses, families and productivity. That's why Hydro One is partnering with Alectra Utilities to support a growing local economy in Hamilton, while improving power reliability for its residents," said Jason Fitzsimmons, Chief Corporate Affairs and Customer Care Officer. "Replacing aging infrastructure and modernizing equipment is part of our plan to build a stronger, safer and more reliable electricity system for Ontario now and into the future." 

"Partnering with Hydro One to invest in our local community will create a safer, more resilient and reliable system for the future," said Max Cananzi, President, Alectra Utilities.  "In addition to investments in the transmission system, Alectra Utilities also plans to invest $235 million over the next five years to renew, upgrade and connect customers to the electrical distribution and supporting systems in Hamilton. Investments in the transmission and distribution systems in Hamilton will contribute to the long-term sustainability of our communities."

"I am pleased to see Hydro One and Alectra investing in modernizing local electricity infrastructure and improving reliability," said Member of Provincial Parliament, Donna Skelly.  "Safe and reliable power is essential to supporting local families, businesses and our community."

Across Ontario, First Nations call for action on urgently needed transmission lines highlight the importance of timely grid investments.

Hydro One's investments included in this announcement are captured in its previously disclosed future capital expenditures, amid proposed projects like the Meaford hydro project across Ontario.

Much of Hydro One's electricity system was built in the 1950s, and replacing aging assets is critical as delays affecting a cross-border transmission line elsewhere have shown. Its three-year, $5 billion investment plan supports safe and reliable power to communities across Ontario, and strong regulatory oversight illustrated by the ATCO Electric penalty helps maintain public trust.


 

 

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Alberta Ends Moratorium on Renewable Energy Projects

Alberta Ends Renewable Energy Moratorium, accelerating wind and solar deployment while prioritizing grid stability, reliability, and infrastructure upgrades to attract investment, cut emissions, meet climate targets, and integrate renewables into the provincial power system.

 

Key Points

It is Alberta's decision to lift a pause on new wind and solar projects while enhancing grid reliability.

✅ Resumes wind and solar development across Alberta.

✅ Focuses on grid stability and infrastructure upgrades.

✅ Aims to attract investment and meet climate targets.

 

The Alberta government has announced the end of a temporary suspension on the development of new renewable energy projects, as the power grid operator prepares to accept green energy bids across the market. This pause, which had been in place since May 2023, was initially implemented to evaluate the effects of rapid growth in renewable energy installations on the province's power grid and overall energy system. However, the decision to lift the moratorium reflects a shift in the government’s approach to balancing energy needs and environmental goals.

The suspension was introduced amid concerns that the swift expansion of wind and solar energy projects, including documented challenges with solar energy expansion in the province, could place undue stress on Alberta's electrical grid and infrastructure. Officials expressed worries about the ability of the grid to handle the increased load and the potential need for upgrades to accommodate new renewable energy sources. The government aimed to assess the implications of this growth and determine appropriate measures to ensure that the energy system could support both existing and future demands.

The moratorium drew significant criticism from various sectors, including renewable energy companies, environmental advocates, and local communities. Critics argued that the pause was detrimental to Alberta's efforts to transition to cleaner energy sources and meet climate targets, citing cases like TransAlta scrapping a wind farm amid policy uncertainty. They pointed out that halting projects could delay investments and job creation associated with the renewable energy sector, potentially impeding progress towards a more sustainable energy future.

In response to these concerns, the Alberta government conducted further reviews and consultations. The decision to cancel the pause reflects the government’s recognition of the importance of advancing renewable energy initiatives while also addressing the need for grid stability and infrastructure development. By ending the moratorium, the government aims to support the continued growth of renewable energy projects and maintain momentum in the shift towards greener energy solutions.

The lifting of the moratorium is expected to have a positive impact on the renewable energy industry in Alberta. Several planned projects that were put on hold can now proceed, leading to renewed investment and economic benefits, including a renewable energy surge that could power 4,500 jobs across the province. The government’s decision signals a commitment to integrating renewable energy sources into the provincial grid in a way that ensures both reliability and sustainability.

Going forward, the Alberta government plans to implement measures to better manage the integration of renewable energy into the existing power infrastructure. This includes addressing any potential challenges related to grid capacity and ensuring that the growth of renewable energy projects aligns with the province's overall energy strategy, as recent federal procurement such as a $500M green electricity contract with an Edmonton company underscores demand that integration efforts must accommodate. The goal is to create a balanced approach that supports the development of clean energy while maintaining the stability and efficiency of the energy system.

The end of the moratorium aligns with Alberta’s broader objectives to reduce greenhouse gas emissions and promote environmental sustainability within a province recognized as a powerhouse for both green energy and fossil fuels in Canada. The government’s approach reflects a willingness to adapt policies and strategies in response to evolving industry needs and environmental priorities. By removing the pause, Alberta demonstrates its commitment to fostering a diverse and resilient energy sector that can meet both current and future demands.

The decision to cancel the moratorium is also seen as a move to reinforce Alberta’s position as a leader in renewable energy development. With the lifting of restrictions, the province can continue to attract investment in clean energy projects, as neighboring jurisdictions such as B.C. streamline clean energy approvals to accelerate deployment, enhance its reputation as a progressive energy market, and contribute to global efforts to address climate change.

In summary, the Alberta government’s decision to lift the pause on renewable energy projects represents a significant shift in its approach to energy policy. The move reflects an acknowledgment of the importance of advancing renewable energy while addressing the practical challenges associated with grid management and infrastructure development. By ending the moratorium, Alberta aims to support the growth of clean energy initiatives and maintain its commitment to sustainability and environmental responsibility.

 

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