Carbon tax would raise bills – except in Quebec

Ireland 65% Renewable Grid Capability showcases world leading integration of intermittent wind and solar, smart grid flexibility, EU-SysFlex learnings, and the Celtic Interconnector to enhance stability, exports, and energy security across the European grid.

Key Points

Ireland can run its isolated power system with 65% variable wind and solar, informing EU grid integration and scaling.

✅ 65% system non-synchronous penetration on an isolated grid

✅ EU-SysFlex roadmap supports large-scale renewables integration

✅ Celtic Interconnector adds 700MW capacity and stability

Ireland is now able to cope with 65% of its electricity coming from intermittent electricity sources like wind and solar, as highlighted by Ireland's green electricity outlook today – an expertise Energy Minister Denish Naugthen believes can be replicated on a larger scale as Europe moves towards 50% renewable power by 2030.

Denis Naughten is an Irish politician who serves as Minister for Communications, Climate Action and Environment since May 2016.

Naughten spoke to editor Frédéric Simon on the sidelines of a EURACTIV event in the European  Parliament to mark the launch of EU-SysFlex, an EU-funded project, which aims to create a long-term roadmap for the large-scale integration of renewable energy on electricity grids.

What is the reason for your presence in Brussels today and the main message that you came to deliver?

The reason that I’m here today is that we’re going to share the knowledge what we have developed in Ireland, right across Europe. We are now the global leaders in taking variable renewable electricity like wind and solar onto our grid.

We can take a 65% loading on to the grid today – there is no other isolated grid in the world that can do that. We’re going to get up to 75% by 2020. This is a huge technical challenge for any electricity grid and it’s going to be a problem that is going to grow and grow across Europe, even as Europe's electricity demand rises in the coming years, as we move to 50% renewables onto our grid by 2030.

And our knowledge and understanding can be used to help solve the problems right across Europe. And the sharing of technology can mean that we can make our own grid in Ireland far more robust.

What is the contribution of Ireland when it comes to the debate which is currently taking place in Europe about raising the ambition on renewable energy and make the grid fit for that? What are the main milestones that you see looking ahead for Europe and Ireland?

It is a challenge for Europe to do this, but we’ve done it Ireland. We have been able to take a 65% loading of wind power on our grid, with Irish wind generation hitting records recently, so we can replicate that across Europe.

Yes it is about a much larger scale and yes, we need to work collaboratively together, reflecting common goals for electricity networks worldwide – not just in dealing with the technical solutions that we have in Ireland at the fore of this technology, but also replicating them on a larger scale across Europe.

And I believe we can do that, I believe we can use the learnings that we have developed in Ireland and amplify those to deal with far bigger challenges that we have on the European electricity grid.

Trialogue talks have started at European level about the reform of the electricity market. There is talk about decentralised energy generation coming from small-scale producers. Do you see support from all the member states in doing that? And how do you see the challenges ahead on a political level to get everyone on board on such a vision?

I don’t believe there is a political problem here in relation to this. I think there is unanimity across Europe that we need to support consumers in producing electricity for self-consumption and to be able to either store or put that back into the grid.

The issues here are more technical in nature. And how you support a grid to do that. And who actually pays for that. Ireland is very much a microcosm of the pan-European grid and how we can deal with those challenges.

What we’re doing at the moment in Ireland is looking at a pilot scheme to support consumers to generate their own electricity to meet their own needs and to be able to store that on site.

I think in the years to come a lot of that will be actually done with more battery storage in the form of electric vehicles and people would be able to transport that energy from one location to another as and when it’s needed. In the short term, we’re looking at some novel solutions to support consumers producing their own electricity and meeting their own needs.

So I think this is complex from a technical point of view at the moment, I don’t think there is an unwillingness from a political perspective to do it, and I think working with this particular initiative and other initiatives across Europe, we can crack those technical challenges.

To conclude, last year, the European Commission allocated €4 million to a project to link up the Irish electricity grid to France. How is that going to benefit Ireland? And is that related to worries that you may have over Brexit?

The plan, which is called the Celtic Interconnector, is to link France with the Irish electricity grid. It’s going to have a capacity of about 700MW. It allows us to provide additional stability on our grid and enables us to take more renewables onto the grid. It also allows us to export renewable electricity onto the main European grid as well, and provide stability to the French network.

So it’s a benefit to both individual networks as well as allowing far more renewables onto the grid. We’ve been working quite closely with RTE in France and with both regulators. We’re hoping to get the support of the European Commission to move it now from the design stage onto the construction stage. And I understand discussions are ongoing with the Commission at present with regard to that.

And that is going to diversify potential sources of electricity coming in for Ireland in a situation which is pretty uncertain because of Brexit, correct?

Well, I don’t think there is uncertainty because of Brexit in that we have agreements with the United Kingdom, we’re still going to be part of the broader energy family in relation to back-and-forth supply across the Irish Sea, with grid reinforcements in Scotland underscoring reliability needs.  But I think it is important in terms of meeting the 15% interconnectivity that the EU has set in relation to electricity.

And also in relation of providing us with an alternative support in relation to electricity supply outside of Britain. Because Britain is now leaving the European Union and I think this is important from a political point of view, and from a broader energy security point of view. But we don’t see it in the short term as causing threats in relation to security of supply.

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Advanced Traffic Light System for Geothermal Safety models fracture growth and friction with rock physics, geophones, and supercomputers to predict induced seismicity during hydraulic stimulation, enabling real-time risk control for ETH Zurich and SED.

Key Points

ATLS uses rock physics, geophones, and HPC to forecast induced seismicity in real time during geothermal stimulation.

✅ Real-time seismic risk forecasts during hydraulic stimulation

✅ Uses rock physics, friction, and fracture modeling on HPC

✅ Supports ETH Zurich and SED field tests in Iceland and Bedretto

The Swiss Earthquake Service and ETH Zurich want to make geothermal energy safer, so news piece from Switzerland earlier this month. This is to be made possible by new software, including machine learning, and the computing power of supercomputers. The first geothermal tests have already been carried out in Iceland, and more will follow in the Bedretto laboratory.

In areas with volcanic activity, the conditions for operating geothermal plants are ideal. In Iceland, the Hellisheidi power plant makes an important contribution to sustainable energy use, alongside innovations like electricity from snow in cold regions.

Deep geothermal energy still has potential. This is the basis of the 2050 energy strategy. While the inexhaustible source of energy in volcanically active areas along fault zones of the earth’s crust can be tapped with comparatively little effort and, where viable, HVDC transmission used to move power to demand centers, access on the continents is often much more difficult and risky. Because the geology of Switzerland creates conditions that are more difficult for sustainable energy production.

Improve the water permeability of the rock

On one hand, you have to drill four to five kilometers deep to reach the correspondingly heated layers of earth in Switzerland. It is only at this depth that temperatures between 160 and 180 degrees Celsius can be reached, which is necessary for an economically usable water cycle. On the other hand, the problem of low permeability arises with rock at these depths. “We need a permeability of at least 10 millidarcy, but you can typically only find a thousandth of this value at a depth of four to five kilometers,” says Thomas Driesner, professor at the Institute of Geochemistry and Petrology at ETH Zurich.

In order to improve the permeability, water is pumped into the subsurface using the so-called “fracture”. The water acts against friction, any fracture surfaces shift against each other and tensions are released. This hydraulic stimulation expands fractures in the rock so that the water can circulate in the hot crust. The fractures in the earth’s crust originate from tectonic tensions, caused in Switzerland by the Adriatic plate, which moves northwards and presses against the Eurasian plate.

In addition to geothermal energy, the “Advanced Traffic Light System” could also be used in underground construction or in construction projects for the storage of carbon dioxide.

Quake due to water injection

The disadvantage of such hydraulic stimulations are vibrations, which are often so weak or cannot be perceived without measuring instruments. But that was not the case with the geothermal projects in St. Gallen 2013 and Basel 2016. A total of around 11,000 cubic meters of water were pumped into the borehole in Basel, causing the pressure to rise. Using statistical surveys, the magnitudes 2.4 and 2.9 defined two limit values ??for the maximum permitted magnitude of the earthquakes generated. If these are reached, the water supply is stopped.

In Basel, however, there was a series of vibrations after a loud bang, with a time delay there were stronger earthquakes, which startled the residents. In both cities, earthquakes with a magnitude greater than 3 have been recorded. Since then it has been clear that reaching threshold values ??determines the stop of the water discharge, but this does not guarantee safety during the actual drilling process.

Simulation during stimulation

The Swiss Seismological Service SED and the ETH Zurich are now pursuing a new approach that can be used to predict in real time, building on advances by electricity prediction specialists in Europe, during a hydraulic stimulation whether noticeable earthquakes are expected in the further course. This is to be made possible by the so-called “Advanced Traffic Light System” based on rock physics, a software developed by the SED, which carries out the analysis on a high-performance computer.

Geophones measure the ground vibrations around the borehole, which serve as indicators for the probability of noticeable earthquakes. The supercomputer then runs through millions of possible scenarios, similar to algorithms to prevent power blackouts during ransomware attacks, based on the number and type of fractures to be expected, the friction and tensions in the rock. Finally, you can filter out the scenario that best reflects the underground.

Further tests in the mountain

However, research is currently still lacking any real test facility for the system, because incorrect measurements must be eliminated and a certain data format adhered to before the calculations on the supercomputer. The first tests were carried out in Iceland last year, with more to follow in the Bedretto geothermal laboratory in late summer, where reliable backup power from fuel cell solutions can keep instrumentation running. An optimum can now be found between increasing the permeability of rock layers and an adequate water supply.

The new approach could make geothermal energy safer and ultimately help this energy source to become more accepted, while grid upgrades like superconducting cables improve efficiency. Research also sees areas of application wherever artificially caused earthquakes can occur, such as in underground mining or in the storage of carbon dioxide underground.

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BPA Privatization would sell the Bonneville Power Administration's transmission lines, raising FERC-regulated grid rates for ratepayers, impacting hydropower and the California-Oregon Intertie under the Trump 2018 budget proposal in the Pacific Northwest region.

Key Points

Selling Bonneville's transmission grid to private owners, raising rates and returns, shifting costs to ratepayers.

✅ Trump 2018 budget targets BPA transmission assets for sale.

✅ Higher capital costs, taxes, and profit would raise transmission rates.

✅ California-Oregon Intertie and hydropower flows face price impacts.

President Trump's 2018 budget proposal is so chock-full of noxious elements — replacing food stamps with "food boxes," drastically cutting Medicaid and Medicare, for a start — that it's unsurprising that one of its most misguided pieces has slipped under the radar.

That's the proposal to privatize the government-owned Bonneville Power Administration, which owns about three-quarters of the high-voltage electric transmission lines in a region that includes California, Washington state and Oregon, serving more than 13.5 million customers. By one authoritative estimate, any such sale would drive up the cost of transmission by 26%-44%.

The $5.2-billon price cited by the Trump administration, moreover, is nearly 20% below the actual value of the Bonneville grid — meaning that a private buyer would pocket an immediate windfall of $1.2 billion, at the expense of federal taxpayers and Bonneville customers.

Trump's plan for Portland, Ore.-based Bonneville is part of a larger proposal to sell off other government-owned electricity bodies, including the Colorado-based Western Area Power Administration and the Oklahoma-based Southwestern Power Administration. But Bonneville is by far the largest of the three, accounting for nearly 90% of the total $5.8 billion the budget anticipates collecting from the sales. The proposal is also part of the administration's

Both plans are said to be politically dead-on-arrival in Washington. But they offer a window into the thinking in the Trump White House.

"The word 'muddle' comes to mind," says Robert McCullough, a respected Portland energy consultant, referring to the justification for the privatization sale included in the Trump budget.

The White House suggests that selling the Bonneville grid would result in lower costs. But that narrative, McCullough wrote in a blistering assessment of the proposal, "displays a severe lack of understanding about the process of setting transmission rates."

McCullough's assessment is an update of a similar analysis he performed when the privatization scheme was first raised by the Trump administration last year. In that analysis issued in June, McCullough said the proposal "raises the question of why these valuable assets would be sold at a discount — and who would get the benefit of the discounted price."

The implications of a sale could be dire for Californians. Bonneville is the majority owner of the California-Oregon Intertie, an electrical transmission system that carries power, including Columbia River-generated hydropower and other clean-energy generation in British Columbia that supports the regional exchange, south to California in the summer and excess California generation to the Pacific Northwest in the winter.

But the idea has drawn fire throughout the region. When it was first broached last year, the Public Power Council, an association of utilities in the Northwest, assailed it as an apparent "transfer of value from the people of the Northwest to the U.S. Treasury," drawing parallels to Manitoba Hydro governance issues elsewhere.

The region's political leaders had especially harsh words for the idea this time around. "Oregonians raised hell last year when Trump tried to raise power bills for Pacific Northwesterners by selling off Bonneville Power, and yet his administration is back at it again," Sen. Ron Wyden (D-Ore.) said after the idea reappeared. "Our investment shouldn't be put up for sale to free up money for runaway military spending or tax cuts for billionaires." Sen. Maria Cantwell (D-Wash.) promised in a statement to work to "stop this bad idea in its tracks."

The notion of privatizing Bonneville predates the Trump administration; it was raised by Bill Clinton and again by George W. Bush, who thought the public would gain if the administration could sell its power at market rates. Both initiatives failed.

The same free-enterprise ideology underlies the Trump proposal. Privatizing the transmission lines "encourages a more efficient allocation of economic resources and mitigates unnecessary risk to taxpayers," the budget asserts. "Ownership of transmission assets is best carried out by the private sector where there are appropriate market and regulatory incentives."

But that's based on a misunderstanding of how transmission rates are set, McCullough says. Transmission is essentially a monopoly enterprise, with rates overseen by the Federal Energy Regulatory Commission based on the grid's costs, and with federal scrutiny of public utilities such as the TVA underscoring that oversight. There's very little in the way of market "incentives" involved in transmission, since no one has come forward to build a competing grid.

Those include the owners' cost of capital — which would be much higher for a private owner than a government agency, McCullough observes, as Hydro One investor uncertainty demonstrates in practice. A private owner, unlike the government-owned Bonneville, also would owe federal income taxes, which would be passed on to consumers.

Then there's the profit motive. Bonneville "currently sells and delivers its power at cost," McCullough wrote last year. "Under a private regime, an investor-owned utility would likely charge a higher rate of return, a pattern seen when UK network profits drew regulatory rebukes."

None of these considerations appears to have been factored into the White House budget proposal. "Either there's an unsophisticated person at the Office of Management and Budget thinking up these numbers himself," McCullough told me, "or there would seem to be ongoing negotiations with an unidentified third party." No such buyer has emerged in the past, however.

What's left is a blind faith in the magic of the market, compounded by ignorance about how the transmission market operates. Put it together, and there's reason to wonder if Trump is even serious about this plan.

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Uranium Critical Mineral Reclassification signals a US executive order directing USGS to restore critical status, boosting nuclear energy, domestic uranium mining, streamlined permitting, federal support, and energy security amid import reliance and supply chain risks.

Key Points

A policy relisting uranium as a critical mineral to unlock funding, speed permits, and strengthen U.S. nuclear security.

✅ Directs Interior to have USGS reconsider uranium classification

✅ Speeds permits for domestic uranium mining projects

✅ Targets import dependence and strengthens energy security

In a strategic move to bolster the United States' nuclear energy sector, former President Donald Trump issued an executive order on January 20, 2025, directing the Secretary of the Interior to instruct the U.S. Geological Survey (USGS) to reconsider classifying uranium as a critical mineral. This directive aims to enhance federal support and streamline permitting processes for domestic uranium projects, thereby strengthening U.S. energy security objectives.

Reclassification of Uranium as a Critical Mineral

The USGS had previously removed uranium from its critical minerals list in 2022, categorizing it as a "fuel mineral" that did not qualify for such designation. The recent executive order seeks to reverse this decision, recognizing uranium's strategic importance in the context of the nation's energy infrastructure and geopolitical considerations.

Implications for Domestic Uranium Production

Reclassifying uranium as a critical mineral is expected to unlock federal funding and expedite the permitting process for uranium mining projects within the United States. This initiative is particularly pertinent given the significant decline in domestic uranium production over the past two decades. According to the U.S. Energy Information Administration, domestic production has decreased by 96%, from 4.8 million pounds in 2014 to approximately 121,296 pounds in the third quarter of 2024.

Current Uranium Supply Dynamics

Despite the push for increased domestic production, the U.S. remains heavily reliant on uranium imports. In 2022, 27% of U.S. uranium purchases were sourced from Canada, with an additional 57% imported from countries including Kazakhstan, Uzbekistan, Australia, and Russia; a recent ban on Russian uranium could further disrupt these supply patterns and heighten risks. This reliance on foreign sources has raised concerns about energy security, especially in light of recent geopolitical tensions.

Challenges and Considerations

While the executive order represents a significant step toward revitalizing the U.S. nuclear energy sector, several challenges persist, and energy dominance faces constraints that will shape implementation:

• Regulatory Hurdles: Accelerating the permitting process for uranium mining projects involves navigating complex environmental and regulatory frameworks, though recent permitting reforms for geothermal hint at potential pathways, which can be time-consuming and contentious.

• Market Dynamics: The uranium market is subject to global supply and demand fluctuations, and domestic producers may face competition from established international suppliers.

• Infrastructure Development: Expanding domestic uranium production necessitates substantial investment in mining infrastructure and workforce development, areas that have been underfunded in recent years.

Broader Implications for Nuclear Energy Policy

The executive order aligns with a broader strategy to revitalize the U.S. nuclear energy industry, where ongoing nuclear innovation is critical to delivering stable, low-emission power. The increasing demand for nuclear energy is driven by the global push for zero-emissions energy sources and the need to support power-intensive technologies, such as artificial intelligence servers.

Former President Trump's executive order to reclassify uranium as a critical mineral, aligning with his broader energy agenda and a prior pledge to end the 'war on coal', signifies a pivotal moment for the U.S. nuclear energy sector. By potentially unlocking federal support, including programs advanced by the Nuclear Innovation Act, and streamlining permitting processes, this initiative aims to reduce dependence on foreign uranium sources and enhance national energy security. However, realizing these objectives will require addressing regulatory challenges, market dynamics, and infrastructure needs to ensure the successful revitalization of the domestic uranium industry.

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UK Wind and Tidal Power Auction signals strong CfD support for offshore wind, tidal stream projects, investor certainty, and clean electricity, accelerating the net-zero transition, boosting jobs, and strengthening UK energy security and grid integration.

Key Points

A CfD auction awarding contracts for wind and tidal projects to scale clean power and advance UK net-zero.

✅ Offshore wind dominates CfD awards

✅ Tidal stream gains predictable, reliable capacity

✅ Jobs, investment, and grid integration accelerate

In a significant development for the UK’s renewable energy sector, the latest auction for renewable energy contracts has underscored a transformative shift towards wind and tidal power. As reported by The Guardian, the auction results reveal a strong commitment to expanding these technologies, with new contracts adding 10 GW to the UK grid, marking a pivotal moment in the UK’s transition to cleaner energy sources.

The Auction’s Impact

The renewable energy auction, which took place recently, has allocated contracts for a substantial increase in wind and tidal power projects. This auction, part of the UK’s Contracts for Difference (CfD) scheme, is designed to support the development of low-carbon energy technologies by providing financial certainty to investors. By offering fixed prices for the electricity generated by these projects, the CfD scheme aims to stimulate investment and accelerate the deployment of renewable energy sources.

The latest results are particularly notable for the significant share of contracts awarded to offshore wind farms and tidal power projects, highlighting how offshore wind is powering up the UK as policy and investment priorities continue to shift. This marks a shift from previous auctions, where solar power and onshore wind were the dominant technologies. The move towards supporting offshore wind and tidal power reflects the UK’s strategic focus on harnessing its abundant natural resources to drive the transition to a low-carbon energy system.

Offshore Wind Power: A Major Contributor

Offshore wind power has emerged as a major player in the UK’s renewable energy landscape, within a global market projected to become a $1 trillion business over the coming decades. The recent auction results highlight the continued growth and investment in this sector.

The UK has been a global leader in offshore wind development, with several large-scale projects already operational and more in the pipeline. The auction has further cemented this position, underscoring what the U.S. can learn from the U.K. in scaling offshore wind capacity, with new projects set to contribute significantly to the country’s renewable energy capacity. These projects are expected to deliver substantial amounts of clean electricity, supporting the UK’s goal of achieving net-zero emissions by 2050.

Tidal Power: An Emerging Frontier

Tidal power, although less developed compared to wind and solar, is gaining momentum as a promising renewable energy source, with companies harnessing oceans and rivers to demonstrate practical potential. The auction results have allocated contracts to several tidal power projects, signaling growing recognition of the potential of this technology.

Tidal power harnesses the energy from tidal movements and currents, which are highly predictable and consistent, and a market outlook for wave and tidal energy points to emerging growth drivers and investment. This makes it a reliable complement to intermittent sources like wind and solar power. The inclusion of tidal power projects in the auction reflects the UK’s commitment to diversifying its renewable energy portfolio and exploring all available options for achieving energy security and sustainability.

Economic and Environmental Benefits

The expansion of wind and tidal power projects through the recent auction offers numerous economic and environmental benefits. From an economic perspective, these projects are expected to create thousands of jobs in construction, maintenance, and manufacturing. They also stimulate investment in local economies and support the growth of the green technology sector.

Environmentally, the increased deployment of wind and tidal power contributes to significant reductions in greenhouse gas emissions. Offshore wind farms and tidal power projects produce clean electricity with minimal environmental impact, helping to mitigate the effects of climate change and improve air quality.

Challenges and Future Outlook

Despite the positive outcomes of the auction, there are challenges to address. Offshore wind farms and tidal power projects require substantial upfront investment and face technical and logistical challenges. Issues such as grid integration, environmental impact assessments, and supply chain constraints need to be carefully managed to ensure the successful deployment of these projects.

Looking ahead, the UK’s renewable energy strategy will continue to evolve as new technologies and innovations emerge, and growth despite Covid-19 underscores sector resilience. The success of the latest auction demonstrates the growing confidence in wind and tidal power and sets the stage for further advancements in renewable energy.

The UK government’s commitment to supporting these technologies through initiatives like the CfD scheme is crucial for achieving long-term energy and climate goals. As the country progresses towards its net-zero target, the continued expansion of wind and tidal power will play a key role in shaping a sustainable and resilient energy future.

Conclusion

The latest renewable energy auction represents a significant milestone in the UK’s transition to a low-carbon energy system. By awarding contracts to wind and tidal power projects, the auction underscores the country’s commitment to harnessing diverse and reliable sources of renewable energy. The expansion of offshore wind and the emerging role of tidal power highlight the UK’s strategic approach to achieving energy security, reducing emissions, and driving economic growth. As the renewable energy sector continues to evolve, the UK remains at the forefront of global efforts to build a sustainable and clean energy future.

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Smart Renewables and Electrification Pathways Program enables clean energy and grid modernization across Canada, funding wind, solar, hydro, geothermal, tidal, and storage to cut GHG emissions and accelerate electrification toward a net-zero economy.

Key Points

A $964M Canadian program funding clean power and grid upgrades to cut emissions and build net-zero electrified economy.

✅ Funds wind, solar, hydro, geothermal, tidal, and storage projects

✅ Modernizes grids for reliability, digitalization, and resilience

✅ Supports net-zero by 2050 with Indigenous and utility partners

Harnessing Canada's immense clean energy resources requires transformational investments to modernize our electricity grid. The Government of Canada is investing in renewable energy and upgrading the electricity grid, moving toward an electric, connected and clean economy, to make clean, affordable electricity options more accessible in communities across Canada.

The Honourable Seamus O'Regan Jr., Minister of Natural Resources, today launched a $964-million program, alongside a recent federal green electricity contract in Alberta that underscores momentum, to support smart renewable energy and grid modernization projects that will lower emissions by investing in clean energy technologies, like wind, solar, storage, hydro, geothermal and tidal energy across Atlantic Canada.

The Smart Renewables and Electrification Pathways Program (SREPs) supports building Canada's low-emissions energy future and a renewable, electrified economy through projects that focus on non-emitting, cleaner energy technologies, such as storage, and modernizing electricity system operations.

Investing in these technologies reduces greenhouse gas emissions by creating a cleaner, more connected electrical system, supporting progress toward zero-emissions electricity by 2035 goals, while helping Canada reach net-zero emissions by 2050.

Minister O'Regan launched the program during the Canadian Electricity Association's (CEA) virtual regulatory forum on Electricity Regulation & the Four Disruptors – Decarbonization, Decentralization, Digitalization and Democratization, highlighting evolving regulatory approaches as B.C. streamlines clean energy approvals to support deployment nationwide. The launch also coincides with Canadian Environment Week, which celebrates Canada's environmental accomplishments and encourages Canadians to contribute to conserving and protecting the environment.

Through SREPs and other programming, the government is working with provinces and territories, with the Prairie Provinces leading renewable growth in the years ahead, utilities, Indigenous partners and others, including diverse businesses and communities, to deliver these clean and reliable energy initiatives. With Canadian innovation, technology and skilled energy workers, we can provide more communities, households and businesses with an increased supply of clean electricity and a cleaner electrical grid.

To help interested stakeholders find information on SREPs, a new webpage has been launched, which includes a comprehensive guide for eligible projects.

This supports Canada's strengthened climate plan, A Healthy Environment and a Healthy Economy. Canada is advancing projects that support the clean grid of the future and seize opportunities in the global electricity market to boost competitiveness. Collectively with investments from the Fall Economic Statement 2020 and Budget 2021, Canada will achieve our climate change commitments and ensure a healthier environment and more prosperous economy for future generations.

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