Doubts hit Ontario's green energy plan

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OntarioÂ’s plan to incite a homegrown green energy industry has stalled, industry experts say, as the plan is plagued by political doubt ahead of this fallÂ’s provincial election.

Several factors are stirring marketplace jitters, including unhappy noises from the opposition Conservative party, international opposition to buy-local provisions in the plan and increasing hostility to wind turbines in rural Ontario.

“There is uncertainty out there,” says Dan Gormley, a Toronto-based lawyer who leads the green energy practice at Goodmans LLP. “And I think a good part of the uncertainty comes from people wondering how much longer the government can spend the sort of money that’s involved in handing out these contracts.”

OntarioÂ’s feed-in tariff FIT program, introduced in 2009 as part of the Green Energy Act, offers heavily subsidized long-term contracts to renewable energy developers who use a portion of domestic materials in their projects.

The program, a first of its kind in North America, was designed to work on two levels. Potential wind and solar developers would be enticed by the generous rates — as high as 30 times the current market price for electricity — offered by the province. Once the generators jumped, manufacturers, buoyed by rules forcing as much as 60 of projects to be made in Ontario, would spring up across the province.

Government promised the policy would create 50,000 new jobs by the end of 2012, filling a void left by an exodus of manufacturers.

While the FIT program has achieved some success 15 projects are now in service, adding 10.6 megawatts of power to the grid it is not nearly the panacea many had believed.

Interest on the part of developers and financers is substantial. Manufacturers, however, have been slower to enter the market.

“I don’t think that has developed as quickly as the government would have liked,” Mr. Gormley says. “And that’s probably because nobody could be certain that five years from now this program is going to be demanding the volume of solar panels, wind turbines, etc., that it is today.”

More than halfway towards its target date, the government claims 13,063 jobs in total 1,244 of them in manufacturing have been “created or supported” by the legislation. Those numbers appear, at turns, both exaggerated and vague.

Four manufacturers contacted by the Citizen for this article, for example, reported employing far fewer people than the government reports.

DMI Industries, a Fort Erie-based turbine tower manufacturer, has 165 employees, 44 fewer than the 238 listed by the government.

SunRise Power Corp. employs 15 people, according to its president, 133 fewer than the 35 listed. Satcon, a Burlington-based manufacturer, was established eight years before the Liberal legislation and estimates it has added 40 jobs to accommodate the additional business in Ontario. The province claims 150 jobs at Satcon flowed from the Green Energy Act.

“Obviously, the numbers are overinflated,” says Sean Moore, CEO of Unconquered Sun Technologies, a Windsor company that employs roughly half the 20 claimed by government. “It’s almost a virtual market. Everyone’s coming out with these announcements. But until you have actual brick and mortar, no one’s actually employed.”

Furthermore, a vast majority of the jobs the government claims it has created — 9,436 categorized as “conservation” jobs — are totally unaccounted for. A ministry spokesman said many are attached to a home retrofit program that predates the Green Energy Act.

The news is not all bad. Both Moore and SunRise president Paul Pauze are prime targets of the strategy — engineers who lost their old world auto and engine manufacturing jobs when plants in Windsor and Peterborough downsized.

Moore estimates demand is outstripping supply for photovoltaic panels by a margin of roughly eight to one and plans to expand his operations in 2011.

Several manufacturers have recently announced their intention to set up shop in the province, including Siemens AG, Celestica and SunEdison Co.

However, Moore says it takes years to go from announcement to production. By then, the generous incentives underpinning the marketplace may have changed drastically.

Tim Hudak, leader of the opposition Conservative party, has called the green energy plan economically unsound. He blames it for soaring electricity bills, which rose 16 in 2010 to an average monthly total of $114.

“The subsidies are too high,” he said in an interview. “They’re driving up hydro rates and killing jobs in the broader economy. Our party supports renewable energy, but it has to be at rates that are affordable for families that pay the bills at the end of the day and in communities where it’s welcomed.”

Mr. Hudak has also criticized the legislation, which centralized approvals processes to prevent NIMBYism, for taking decision-making power away from local municipalities. He says he would reverse current rules by allowing municipalities to have a say in siting decisions — a potentially devastating blow to wind developers in particular.

On the other aspects of the program, the Progressive Conservative party leader is noncommittal.

“We’ll have more to say on this in the time ahead,” he told the Citizen.

Mr. HudakÂ’s position is being taken seriously, especially because he leads the Liberals by a slim margin in the polls.

“If that political uncertainty could be removed, there would be much more investment, no question,” says Mr. Gormley. “I would hope Hudak could declare himself.”

Mr. Pauze estimates there is currently about four years worth of manufacturing work in the green energy pipeline, a fact sustaining companies like his. Beyond that, the future is uncertain.

“We’re certainly watching what’s going on very carefully,” he says.

Other factors are undermining the industry as well.

Japan launched a challenge to the domestic content provisions in the law in September and was quickly joined by the European Union and U.S. And grassroots opposition to wind power is growing. One group recently launched a legal challenge in January that could result in rule changes surrounding siting.

In a candid admission, Brad Duguid, the provinceÂ’s energy minister, acknowledges the pace of investment in the sector is not happening as quickly as he would like.

“I think there’s enough groundwork being done that’s allowed investment to come in, albeit slower than would be if Tim Hudak wasn’t standing there as a threat,” he says. “From my perspective from talking to investors and businesses, I think it’s had an impact.”

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Ontario pitches support for electric bills

Ontario CEAP Program provides one-time electricity bill relief for residential consumers via local utilities, supports low-income households, aligns with COVID-19 recovery rates, and complements time-of-use pricing options and the winter disconnection ban.

 

Key Points

A one-time electricity bill credit for eligible Ontario households affected by COVID-19, available via local utilities.

✅ Apply through your local distribution company or utility

✅ One-time credit for overdue electricity bills from COVID-19

✅ Complements TOU options, OER, and winter disconnection ban

 

Applications for the CEAP program for Ontario residential consumers has opened. Residential customers across the province can now apply for funding through their local distribution company/utility.

On June 1st, our government announced a suite of initiatives to support Ontario’s electricity consumers amid changes for electricity consumers during the pandemic, including a $9 million investment to support low-income Ontarians through the COVID-19 Energy Assistance Program (CEAP). CEAP will provide a one-time payment to Ontarians who are struggling to pay down overdue electricity bills incurred during the COVID-19 outbreak.

These initiatives include:

  • $9 million for the COVID-19 Energy Assistance Program (CEAP) to support consumers struggling to pay their energy bills during the pandemic. CEAP will provide one-time payments to consumers to help pay down any electricity bill debt incurred over the COVID19 period. Applications will be available through local utilities in the upcoming months;
  • $8 million for the COVID-19 Energy Assistance Program for Small Business (CEAP-SB) to provide support to businesses struggling with bill payments as a result of the outbreak; and
  • An extension of the Ontario Energy Board’s winter disconnection ban until July 31, 2020 to ensure no one is disconnected from their natural gas or electricity service during these uncertain times.


More information about applications for the CEAP for Small Business will be coming later this summer, as electricity rates are about to change across Ontario for many customers.

In addition, the government recently announced that it will continue the suspension of time-of-use (TOU) electricity rates and, starting on June 1, 2020, customers will be billed based on a new fixed COVID-19 hydro rate of 12.8 cents per kilowatt hour. The COVID-19 Recovery Rate, which some warned in analysis could lead to higher hydro bills will be in place until October 31, 2020.

Later in the pandemic, Ontario set electricity rates at the off-peak price until February 7 to provide additional relief.

“Starting November 1, 2020, our government has announced Ontario electricity consumers will have the option to choose between time-of-use and tiered electricity pricing plan, following the Ontario Energy Board’s new rate plan prices and support thresholds announcement. We are proud to soon offer Ontarians the ability to choose an electricity plan that best suits for their lifestyle,” said Jim McDonell, MPP for Stormont–Dundas–South Glengarry.

The government will continue to subsidize electricity bills by 31.8 per cent through the Ontario Electricity Rebate.

The government is providing approximately $5.6 billion in 2020-21 as part of its existing electricity cost relief programs and conservation initiatives such as the Peak Perks program to help ensure more affordable electricity bills for eligible residential, farm and small business consumers.

 

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Senate Committee Advised by WIRES Counsel That Electric Transmission Still Faces Barriers to Development

U.S. Transmission Grid Modernization underscores FERC policy certainty, high-voltage infrastructure upgrades, renewables integration, electrification, and grid resilience to cut congestion and enable distributed energy resources, safeguarding against extreme weather, cyber threats, and market volatility.

 

Key Points

A plan to expand, upgrade, and secure high-voltage networks for renewables integration, electrification, reliability.

✅ Replace aging lines to cut congestion and customer costs

✅ Integrate renewables and distributed energy resources at scale

✅ Enhance resilience to weather, cyber, and physical threats

 

Today, in a high-visibility hearing on U.S. energy delivery infrastructure before the United States Senate Committee on Energy and Natural Resources, WIRES Executive Director and Former FERC Chairman Jim Hoecker addressed the challenges and opportunities that confront the modern high-voltage grid as the industry strives to upgrade and expand it to meet the demands of consumers and the economy.

In prepared testimony and responses to Senators' questions, Hoecker urged the Committee to support industry efforts to expand and upgrade the transmission network and to help regulators, especially the Federal Energy Regulatory Commission (FERC action on aggregated DERs), promote certainty and predictability in energy policy and regulation. 

 

His testimony stressed these points:

Significant transmission investment is needed now to replace aging infrastructure like the aging grid risks to clean energy, reduce congestion costs, and deliver widespread benefits to customers.

Increasingly, the role of the transmission grid is to integrate new distributed resources and renewable energy into the electric system and make them available to the market.

The changing electric generation mix, including needed nuclear innovation, and the coming electrification of transportation, heating, and other segments of the American economy in the next quarter century will depend on a strong and adaptable electric system. A robust transmission grid will be the linchpin that will enable us to meet those demands.

"Transmission is the common element that will support all future electricity needs and provide a hedge against uncertainties and potential costly outcomes. The time is now to be proactive in encouraging additional investments in our nation's most crucial infrastructure: the electric transmission system," Hoecker said. 

Hoecker's testimony also emphasized that transmission investment will contribute to the overall resilience of the electric system by bringing multiple resources and technologies to bear on threats to the power system, including extreme weather and proposals like a wildfire-resilient grid bill, cyber or physical attacks, or other events. Visit WIRES website for recently filed comments on the subject (supported by a Brattle Group study). 

"Transmission gives us the optionality to adapt to whatever the future holds, and a modern and resilient transmission system, informed by Texas reliability improvements, will be the most valuable energy asset we have," says Nina Plaushin, president of WIRES and vice president of federal affairs, regulatory and communications for ITC Holdings Corp. 

Hoecker closed his testimony by emphasizing that the "electrification" scenario that is being discussed across multiple industries demands action now in order to ensure policy and regulatory certainty that will support needed transmission investment. More studies need to be conducted to better understand and define how this delivery network must be configured and planned in anticipation of this potential transformation in how we use electrical energy. A full copy of the WIRES testimony can be found here.

 

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Coal demand dropped in Europe over winter despite energy crisis

EU Winter Energy Mix 2022-2023 shows renewables, wind, solar, and hydro overtaking coal and gas, as demand fell amid high prices; Ember and IEA confirm lower emissions across Europe during the energy crisis.

 

Key Points

It describes Europe's winter power mix: reduced coal and gas, and record wind, solar, and hydro output.

✅ Coal generation fell 11% YoY; gas output declined even more.

✅ Renewables supplied 40%: wind, solar, and hydro outpaced fossil fuels.

✅ Ember and IEA confirm trends; mild winter tempered demand.

 

The EU burned less coal this winter during the energy crisis than in previous years, according to an analysis, quashing fears that consumption of the most polluting fossil fuel would soar as countries scrambled to find substitutes for lost supplies of Russian gas.

The study from energy think-tank Ember shows that between October 2022 and March 2023 coal generation fell 27 terawatt hours, or almost 11 per cent year on year, while gas generation fell 38 terawatt hours, as renewables crowded out gas and consumers cut electricity consumption in response to soaring prices.

Renewable energy supplies also rose, with combined wind and solar power and hydroelectric output outstripping fossil fuel generation for the first time, providing 40 per cent of all electricity supplies. The Financial Times checked Ember’s findings with the International Energy Agency, which said they broadly matched its own preliminary analysis of Europe’s electricity generation over the winter.

The study demonstrates that fears of a steep rebound in coal usage in Europe’s power mix were overstated, despite the continent’s worst energy crisis in 40 years following Russia’s full-scale invasion of Ukraine, even as stunted hydro and nuclear output in parts of Europe posed challenges.

While Russia slashed gas supplies to Europe and succeeded in boosting energy prices for consumers to record levels, the push by governments to rejuvenate old coal plants, including Germany's coal generation, to ensure the lights stayed on ultimately did not lead to increased consumption.

“With Europe successfully on the other side of this winter and major supply disruptions avoided, it is clear the threatened coal comeback did not materialise,” analysts at Ember said in the report.

“With fossil fuel generation down, EU power sector emissions during winter were the lowest they have ever been.”

Ember cautioned, however, that Europe had been assisted by a mild winter that helped cut electricity demand for heating and there was no guarantee of such weather next winter. Companies and households had also endured a lot of pain as a result of the higher prices that had led them to cut consumption, even though in some periods, such as the latest lockdown, power demand held firm in parts of Europe.

Total electricity consumption between October and March declined 94 terawatt hours, or 7 per cent, compared with the same period in winter 2021/22, continuing post-Covid transition dynamics across Europe.

“For a lot of people this winter was really hard with electricity prices that were extraordinarily high and we shouldn’t lose sight of that,” said Ember analyst Harriet Fox.

 

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The Impact of AI on Corporate Electricity Bills

AI Energy Consumption strains corporate electricity bills as data centers and HPC workloads run nonstop, driving carbon emissions. Efficiency upgrades, renewable energy, and algorithm optimization help control costs and enhance sustainability across industries.

 

Key Points

AI Energy Consumption is the power used by AI compute and data centers, impacting costs and sustainability.

✅ Optimize cooling, hardware, and workloads to cut kWh per inference

✅ Integrate on-site solar, wind, or PPAs to offset data center power

✅ Tune models and algorithms to reduce compute and latency

 

Artificial Intelligence (AI) is revolutionizing industries with its promise of increased efficiency and productivity. However, as businesses integrate AI technologies into their operations, there's a significant and often overlooked impact: the strain on corporate electricity bills.

AI's Growing Energy Demand

The adoption of AI entails the deployment of high-performance computing systems, data centers, and sophisticated algorithms that require substantial energy consumption. These systems operate around the clock, processing massive amounts of data and performing complex computations, and, much like the impact on utilities seen with major EV rollouts, contributing to a notable increase in electricity usage for businesses.

Industries Affected

Various sectors, including finance, healthcare, manufacturing, and technology, rely on AI-driven applications for tasks ranging from data analysis and predictive modeling to customer service automation and supply chain optimization, while manufacturing is influenced by ongoing electric motor market growth that increases electrified processes.

Cost Implications

The rise in electricity consumption due to AI deployments translates into higher operational costs for businesses. Corporate entities must budget accordingly for increased electricity bills, which can impact profit margins and financial planning, especially in regions experiencing electricity price volatility in Europe amid market reforms. Managing these costs effectively becomes crucial to maintaining competitiveness and sustainability in the marketplace.

Sustainability Challenges

The environmental impact of heightened electricity consumption cannot be overlooked. Increased energy demand from AI technologies contributes to carbon emissions and environmental footprints, alongside rising e-mobility demand forecasts that pressure grids, posing challenges for businesses striving to meet sustainability goals and regulatory requirements.

Mitigation Strategies

To address the escalating electricity bills associated with AI, businesses are exploring various mitigation strategies:

  1. Energy Efficiency Measures: Implementing energy-efficient practices, such as optimizing data center cooling systems, upgrading to energy-efficient hardware, and adopting smart energy management solutions, can help reduce electricity consumption.

  2. Renewable Energy Integration: Investing in renewable energy sources like solar or wind power and energy storage solutions to enhance flexibility can offset electricity costs and align with corporate sustainability initiatives.

  3. Algorithm Optimization: Fine-tuning AI algorithms to improve computational efficiency and reduce processing times can lower energy demands without compromising performance.

  4. Cost-Benefit Analysis: Conducting thorough cost-benefit analyses of AI deployments to assess energy consumption against operational benefits and potential rate impacts, informed by cases where EV adoption can benefit customers in broader electricity markets, helps businesses make informed decisions and prioritize energy-saving initiatives.

Future Outlook

As AI continues to evolve and permeate more aspects of business operations, the demand for electricity will likely intensify and may coincide with broader EV demand projections that increase grid loads. Balancing the benefits of AI-driven innovation with the challenges of increased energy consumption requires proactive energy management strategies and investments in sustainable technologies.

Conclusion

The integration of AI technologies presents significant opportunities for businesses to enhance productivity and competitiveness. However, the corresponding surge in electricity bills underscores the importance of proactive energy management and sustainability practices. By adopting energy-efficient measures, leveraging renewable energy sources, and optimizing AI deployments, businesses can mitigate cost impacts, reduce environmental footprints, and foster long-term operational resilience in an increasingly AI-driven economy.

 

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'Pakistan benefits from nuclear technology'

Pakistan Nuclear Energy advances clean power with IAEA guidance, supporting SDGs via electricity generation, nuclear security, and applications in healthcare, agriculture, and COVID-19 testing, as new 1,100 MW reactors near grid connection.

 

Key Points

Pakistan Nuclear Energy is the nation's atomic program delivering clean electricity, SDGs gains, and IAEA-guided safety.

✅ Two 1,100 MW reactors nearing grid connection

✅ IAEA-aligned safety and nuclear security regime

✅ Nuclear tech supports healthcare, agriculture, COVID-19 tests

 

Pakistan is utilising its nuclear technology to achieve its full potential by generating electricity, aligning with China's steady nuclear development trends, and attaining socio-economic development goals outlined by the United Nations Sustainable Development Goals.

This was stated by Pakistan Atomic Energy Commission (PAEC) Chairperson Muhammad Naeem on Tuesday while addressing the 64th International Atomic Energy Agency (IAEA) General Conference (GC) which is being held in Vienna from September 21, a forum taking place amid regional milestones like the UAE's first Arab nuclear plant startup as well.

Regarding nuclear security, the PAEC chief stated that Pakistan considered it as a national responsibility and that it has developed a comprehensive and stringent safety and security regime, echoing IAEA praise for China's nuclear security in the region, which is regularly reviewed and upgraded in accordance with IAEA's guidelines.

Many delegates are attending the event through video link due to the novel coronavirus (Covid-19) pandemic.

On the first day of the conference, IAEA Director General Rafael Mariano Grossi highlighted the role of the nuclear watchdog in the monitoring and verification of nuclear activities across the globe, as seen in Barakah Unit 1 at 100% power milestones reported worldwide.

He also talked about the various steps taken by the IAEA to help member states contain the spread of coronavirus such as providing testing kits etc.

In a recorded video statement, the PAEC chairperson said that Pakistan has a mutually beneficial relationship with IAEA, similar to IAEA assistance to Bangladesh on nuclear power development efforts. He also congratulated Ambassador Azzeddine Farhane on his election to become the President of the 64th GC and assured him of Pakistan's full support and cooperation.

Naeem stated that as a clean, affordable and reliable source, nuclear energy can play a key role, with India's nuclear program moving back on track, in fighting climate change and achieving the Sustainable Development Goals (SDGs).

The PAEC chief informed the audience that two 1,100-megawatt (MW) nuclear power plants are near completion and, like the UAE grid connection milestone, are expected to be connected to the national grid next year.

He also highlighted the role of PAEC in generating electricity through nuclear power plants, while also helping the country achieve the socio-economic development goals outlined under the United Nations SDGs through the application of nuclear technology in diverse fields like agriculture, healthcare, engineering and manufacturing, human resource development and other sectors.

 

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Atlantica - Regulatory Reform To Bring Greener Power To Atlantic Canada

Atlantic Canada Energy Regulatory Reform accelerates smart grids, renewables, hydrogen, and small modular reactors to meet climate targets, enabling interprovincial transmission, EV charging, and decarbonization toward a net-zero grid by 2035 with agile, collaborative policies.

 

Key Points

A policy shift enabling smart grids, clean energy, and transmission upgrades to decarbonize Atlantic Canada by 2035.

✅ Agile rules for smart grids, EV load, and peak demand balancing

✅ Interprovincial transmission: Maritime Link, NB-PEI, Atlantic Loop

✅ Supports hydrogen, SMRs, and renewables to cut GHG emissions

 

Atlantica Centre for Energy Senior Policy Consultant Neil Jacobsen says the future of Atlantic Canada’s electricity grid depends on agile regulations, supported by targeted research such as the $2M Atlantic grid study, that match the pace at which renewable technologies are being developed in the race to meet Canada’s climate goals.

In an interview, Jacobsen stressed the need for a more modernized energy regulatory framework, so the Atlantic Provinces can collaborate to quickly develop and adopt cleaner energy.

To this end, Atlantica released a paper that makes the case for responsive smart grid technology, the adaptation of alternative forms of clean energy, the adaptation of hydrogen as an energy source, petroleum price regulation in Atlantic Canada and small modular reactors.

Jacobsen said regulations need to match Canada’s urgency around reducing greenhouse gas emissions by 40 to 45 percent by 2030, achieving a net-neutral national power grid by 2035 and ultimately a net-zero grid by 2050 in Canada – and the goal that 50 percent of Canadian vehicle sales being electric by 2030.

“It’s an evolution of policy and regulations to adapt to a very aggressive timeline of aggressive climate change and decarbonization targets,” said Jacobsen.

“These are transformational energy and environmental commitments, so the path forward really requires the ability to introduce and adapt and move forward with new clean renewable energy technologies.”

Jacobsen said Atlantica’s recommendations are not a criticism of existing regulations– but an acknowledgment that they need to evolve.

He noted newer, clearer regulations will make way for new energy sources – particularly a region that has the countries highest rates of dependency on fossil fuels and growing climate risks, with Atlantic grids under threat from more intense storms.

“We have a long way to go, but at the same time, we have a lot to celebrate. Atlantic Canada is leading the country in reducing greenhouse gas emissions,” said Jacobsen.

“There are new ways of producing energy that requires us to be able to be much more responsive and this is an opportunity to create a higher level of alignment here, in Atlantic Canada.”

Jacobsen said Atlantica is looking to aid interprovincial cooperation in providing power, echoing calls for a western Canadian grid elsewhere, through projects like the 500-megawatt, 170-kilometre Maritime Link that transports power from the Muskrat Falls hydroelectric dam in Labrador, through Newfoundland and across the Cabot Strait, to Nova Scotia – or NB Power’s export of electricity to P.E.I., via sub-sea cables crossing the Northumberland Strait.

He noted streamlined regulations may allow for more potential wider-scale partnerships, like the proposed Atlantic Loop project, aligning with macrogrid investments that would involve upgrading transmission capacity on the East Coast to allow hydroelectric power from Labrador and Quebec to displace coal use in the region.

Atlantic Canada has led the way with adaption new renewable technologies, noted Jacobsen, referring to nuclear startups Moltex Energy and ARC Nuclear Canada’s efforts to develop small modular nuclear reactor technology in New Brunswick, as well as the potential of adopting hydrogen fuel technology and Nova Scotia’s strides in developing offshore renewable energy.

“I don’t think we have any choice other than to be forceful and aggressive in driving forward a renewable energy agenda.”

Jacobsen said cooperation between the Atlantic provinces is crucial because of how challenging it is to meet energy demand with heavy seasonal and daily variations in energy demand in the region – something smart grid technology could address.

Smart Grid Atlantic is a four-year research and demonstration program testing technologies that provide cleaner local power, support a smarter electricity infrastructure across the region, more renewable power, more information and control over power use and more reliable electricity.

“It can be challenging for utilities to meet those cyclical demands, especially as grids are increasingly exposed to harsh weather across Canada. Smart girds add knowledge of the flow of electrons in a way that can help even out those electricity demands – and quite frankly, those demands will only increase when you look at the electrification of the transportation sector,” he said.

Jacobsen said Atlantica’s paper and call for modernized regulations are only the beginning of a conversation.

 

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