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EU Electricity Market Reform seeks to curb gas-driven volatility by expanding CfDs and PPAs, decoupling power from gas, and aligning consumer bills with low-cost renewables and nuclear, as Brussels advances market redesign.

Key Points

An EU plan to curb price spikes by expanding long-term contracts and tying bills to cheap renewables.

✅ Expands CfDs and PPAs to lock in predictable power prices

✅ Aims to decouple bills from gas-driven wholesale volatility

✅ Seeks investment certainty for renewables, nuclear, and grids

European Union energy ministers meet on Monday to debate upcoming power market reforms. Brussels is set to propose the revamp next month, but already countries are split over how to "fix" the energy system - or whether it needs fixing at all.

Here's what you need to know.

POST-CRISIS CHANGES
The European Commission pledged last year to reform the EU's electricity market rules, after record-high gas prices - caused by cuts to Russian gas flows - sent power prices soaring during an energy crisis for European companies and citizens.

The aim is to reform the electricity market to shield consumer energy bills from short-term swings in fossil fuel prices, and make sure that Europe's growing share of low-cost renewable electricity translates into lower prices, even though rolling back electricity prices poses challenges for policymakers.

Currently, power prices in Europe are set by the running cost of the plant that supplies the final chunk of power needed to meet overall demand. Often, that is a gas plant, so gas price spikes can send electricity prices soaring.

EU countries disagree on how far the reforms should go.

Spain, France and Greece are among those seeking a deep reform.

In a document shared with EU countries, seen by Reuters, Spain said the reforms should help national regulators to sign more long-term contracts with electricity generators to pay a fixed price for their power.

Nuclear and renewable energy producers, for example, would receive a "contract for difference" (CfD) from the government to provide power during their lifespan - potentially decades - at a stable price that reflects their average cost of production.

Similarly, France suggests, as part of a new electricity pricing scheme, requiring energy suppliers to sign long-term, fixed-price contracts with power generators - either through a CfD, or a private Power Purchase Agreement (PPA) between the parties.

French officials say this would give the power plant owner predictable revenue, while enabling consumers to have part of their energy bill comprised of this more stable price.

Germany, Denmark, Latvia and four other countries oppose a deep reform, and, as nine EU countries oppose reforms overall, have warned the EU against a "crisis mode" overhaul of a complex system that has taken decades to develop.

They say Europe's existing power market is functioning well, and has fostered years of lower power prices, supported renewable energy and helped avoid energy shortages.

Those countries support only limited tweaks, such as making it easier for consumers to choose between fluctuating and fixed-price power contracts.

'DECOUPLE' PRICES?
The Commission initially pitched the reform as a chance to "decouple" gas and power prices in Europe, suggesting a redesign of the current system of setting power prices. But EU officials say Brussels now appears to be leaning towards more modest changes.

A public consultation on the reforms last month steered clear of a deep energy market intervention. Rather, it suggested expanding Europe's use of long-term contracts, outlining a plan for more fixed-price contracts that provide power plants with a fixed price for their electricity, like CfDs or PPAs.

The Commission said this could be done by setting EU-wide rules for CfDs and letting countries voluntarily use them, or require new state-funded power plants to sign CfDs. The consultation mooted the idea of forcing existing power plants to sign CfDs, but said this could deter much-needed investments in renewable energy.

RISKS, REWARDS
Pro-reform countries like Spain say a revamped power market will bring down energy prices for consumers, by matching their bills more closely with the true cost of producing lower-carbon electricity.

France says the aim is to secure investment in low-carbon energy including renewables, and nuclear plants like those Paris plans to build. It also says lowering power prices should be part of Europe's response to massive industrial subsidies in the United States and China - by helping European firms keep a competitive edge.

But sceptics warn that drastic changes to the market could knock confidence among investors, putting at risk the hundreds of billions of euros in renewable energy investments the EU says are needed to quit Russian fossil fuels under its plan to dump Russian energy and meet climate goals.

Energy companies including Engie (ENGIE.PA), Orsted (ORSTED.CO) and Iberdrola (IBE.MC) have said making CfDs mandatory or imposing them retroactively on existing power plants could deter investment and trigger litigation from energy companies.

POLITICAL DEBATE
EU countries' energy ministers discuss the reforms on Monday, before formal negotiations begin.

The Commission, which drafts EU laws, plans to propose the reforms on Mar. 14. After that, EU countries and lawmakers negotiate the final law, which must win majority support from European Parliament lawmakers and a reinforced majority of at least 15 countries.

Negotiations on major EU legislation often take more than a year, but some countries are pushing for a fast-tracked deal. France wants the law to be finished this year.

That has already hit resistance from countries like Germany, highlighting a France-Germany tussle over the scope of reform as they say deeper changes cannot be rushed through, and they would need an "in-depth impact assessment" - something the Commission's upcoming proposal is not expected to include, because it has been drafted so quickly.

The timeline is further complicated by European Parliament elections in 2024. That has raised concerns in reform-hungry states that failure to strike a deal before the election could significantly delay the reforms, if negotiations have to pause until a new EU parliament is elected.

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Methane Hydrate CO2 Sequestration uses carbon capture and nitrogen injection to swap gases in seafloor hydrates along the Gulf of Mexico, releasing methane for electricity while storing CO2, according to new simulation research.

Key Points

A method injecting CO2 and nitrogen into hydrates to store CO2 while releasing methane for power.

✅ Nitrogen aids CO2-methane swap in hydrate cages, speeding sequestration

✅ Gulf Coast proximity to emitters lowers transport and power costs

✅ Revenue from methane electricity could offset carbon capture

The world is quickly realizing it may need to actively pull carbon dioxide out of the atmosphere to stave off the ill effects of climate change. Scientists and engineers have proposed various carbon capture techniques, but most would be extremely expensive—without generating any revenue. No one wants to foot the bill.

One method explored in the past decade might now be a step closer to becoming practical, as a result of a new computer simulation study. The process would involve pumping airborne CO2 down into methane hydrates—large deposits of icy water and methane right under the seafloor, beneath water 500 to 1,000 feet deep—where the gas would be permanently stored, or sequestered. The incoming CO2 would push out the methane, which would be piped to the surface and burned to generate electricity, whether sold locally or via exporters like Hydro-Que9bec to help defray costs, to power the sequestration operation or to bring in revenue to pay for it.

Many methane hydrate deposits exist along the Gulf of Mexico shore and other coastlines. Large power plants and industrial facilities that emit CO2 also line the Gulf Coast, where EPA power plant rules could shape deployment, so one option would be to capture the gas directly from nearby smokestacks, keeping it out of the atmosphere to begin with. And the plants and industries themselves could provide a ready market for the electricity generated.

A methane hydrate is a deposit of frozen, latticelike water molecules. The loose network has many empty, molecular-size pores, or “cages,” that can trap methane molecules rising through cracks in the rock below. The computer simulation shows that pushing out the methane with CO2 is greatly enhanced if a high concentration of nitrogen is also injected, and that the gas swap is a two-step process. (Nitrogen is readily available anywhere, because it makes up 78 percent of the earth’s atmosphere.) In one step the nitrogen enters the cages; this destabilizes the trapped methane, which escapes the cages. In a separate step, the nitrogen helps CO2 crystallize in the emptied cages. The disturbed system “tries to reach a new equilibrium; the balance goes to more CO2 and less methane,” says Kris Darnell, who led the study, published June 27 in the journal Water Resources Research. Darnell recently joined the petroleum engineering software company Novi Labs as a data scientist, after receiving his Ph.D. in geoscience from the University of Texas, where the study was done.

A group of labs, universities and companies had tested the technique in a limited feasibility trial in 2012 on Alaska’s North Slope, where methane hydrates form in sandstone under deep permafrost. They sent CO2 and nitrogen down a pipe into the hydrate. Some CO2 ended up being stored, and some methane was released up the same pipe. That is as far as the experiment was intended to go. “It’s good that Kris [Darnell] could make headway” from that experience, says Ray Boswell at the U.S. Department of Energy’s National Energy Technology Laboratory, who was one of the Alaska experiment leaders but was not involved in the new study. The new simulation also showed that the swap of CO2 for methane is likely to be much more extensive—and to happen quicker—if CO2 enters at one end of a hydrate deposit and methane is collected at a distant end.

The technique is somewhat similar in concept to one investigated in the early 2010s by Steven Bryant and others at the University of Texas. In addition to numerous methane hydrate deposits, the Gulf Coast has large pools of hot, salty brine in sedimentary rock under the coastline. In this system, pumps would send CO2 down into one end of a deposit, which would force brine into a pipe that is placed at the other end and leads back to the surface. There the hot brine would flow through a heat exchanger, where heat could be extracted and used for industrial processes or to generate electricity, supporting projects such as electrified LNG in some markets. The upwelling brine also contains some methane that could be siphoned off and burned. The CO2 dissolves into the underground brine, becomes dense and sinks further belowground, where it theoretically remains.

Either system faces big practical challenges, and building shared CO2 storage hubs to aggregate captured gas is still evolving. One is creating a concentrated flow of CO2; the gas makes up only .04 percent of air, and roughly 10 percent of the smokestack emission from a typical power plant or industrial facility. If an efficient methane hydrate or brine system requires an input that is 90 percent CO2, for example, concentrating the gas will require an enormous amount of energy—making the process very expensive. “But if you only need a 50 percent concentration, that could be more attractive,” says Bryant, who is now a professor of chemical and petroleum engineering at the University of Calgary. “You have to reduce the [CO2] capture cost.”

Another major challenge for the methane hydrate approach is how to collect the freed methane, which could simply seep out of the deposit through numerous cracks and in all directions. “What kind of well [and pipe] structure would you use to grab it?” Bryant asks.

Given these realities, there is little economic incentive today to use methane hydrates for sequestering CO2. But as concentrations rise in the atmosphere and the planet warms further, and as calls for an electric planet intensify, systems that could capture the gas and also provide energy or revenue to run the process might become more viable than techniques that simply pull CO2 from the air and lock it away, offering nothing in return.

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Energy Poverty in Extreme Heat exposes vulnerable households to heatwaves, utility shutoffs, and unreliable grid infrastructure, straining public health. Community nonprofits, cooling centers, and policy reform aim to improve electricity access, resilience, and affordable energy.

Key Points

Without reliable, affordable power in heatwaves, health risks rise and cooling, food storage, and daily needs suffer.

✅ Risks: heat illness, dehydration, and indoor temperatures above 90F

✅ Causes: utility shutoffs, aging grid, unpaid bills, remote areas

✅ Relief: cooling centers, aid programs, weatherization, bill credits

In a particular pocket of America, approximately 13,000 families endure the dual challenges of sweltering heat and living without electricity, and the broader risk of summer shut-offs highlights how widespread these pressures have become across the country. This article examines the factors contributing to their plight, the impact of living without electricity during hot weather, and efforts to alleviate these hardships.

Challenges Faced by Families

For these 13,000 families, daily life is significantly impacted by the absence of electricity, especially during the scorching summer months. Without access to cooling systems such as air conditioners or fans, residents are exposed to dangerously high temperatures, which can lead to heat-related illnesses and discomfort, particularly among vulnerable populations such as children, the elderly, and individuals with health conditions, where electricity's role in public health became especially evident.

Causes of Electricity Shortages

The reasons behind the electricity shortages vary. In some cases, it may be due to economic challenges that prevent families from paying utility bills, resulting in disconnections. Other factors include outdated or unreliable electrical infrastructure in underserved communities, as reflected in a recent grid vulnerability report that underscores systemic risks, where maintenance and upgrades are often insufficient to meet growing demand.

Impact of Extreme Heat

During heatwaves, the lack of electricity exacerbates health risks and quality of life issues for affected families, aligning with reports of more frequent outages across the U.S. Furthermore, the absence of refrigeration and cooking facilities can compromise food safety and nutritional intake, further impacting household well-being.

Community Support and Resilience

Despite these challenges, communities and organizations often rally to support families living without electricity. Local nonprofits, community centers, and government agencies provide assistance such as distributing fans, organizing cooling centers, and delivering essentials like bottled water and non-perishable food items during heatwaves to alleviate immediate hardships and improve summer blackout preparedness in vulnerable neighborhoods.

Long-term Solutions

Addressing electricity access issues requires comprehensive, long-term solutions. These may include policy reforms to ensure equitable access to affordable energy, investments in upgrading infrastructure in underserved areas, and expanding financial assistance programs to help families maintain uninterrupted electricity service, in recognition that climate change risks increasingly stress the grid.

Advocacy and Awareness

Advocacy efforts play a crucial role in raising awareness about the challenges faced by families living without electricity and advocating for sustainable solutions. By highlighting these issues, community leaders, activists, and policymakers can work together to drive policy changes, secure funding for infrastructure improvements, and promote energy efficiency initiatives, drawing lessons from Canada's harsh-weather grid exposures that illustrate regional vulnerabilities.

Building Resilience

Building resilience in vulnerable communities involves not only improving access to reliable electricity but also enhancing preparedness for extreme weather events. This includes developing emergency response plans, educating residents about heat safety measures, and fostering community partnerships to support those in need during crises.

Conclusion

As temperatures rise and climate impacts intensify, addressing the plight of families living without electricity becomes increasingly urgent. By prioritizing equitable access to energy, investing in resilient infrastructure, and fostering community resilience, stakeholders can work towards ensuring that all families have access to essential services, even during the hottest months of the year. Collaborative efforts between government, nonprofit organizations, and community members are essential in creating sustainable solutions that improve quality of life and promote health and well-being for all residents.

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Massachusetts Energy Code Updates align DOER regulations with BBRS standards, advancing Stretch Code and Specialized Code beyond the Base Energy Code to accelerate net-zero construction, electrification, and high-efficiency building performance across municipal opt-in communities.

Key Points

They are DOER-led changes to Base, Stretch, and Specialized Codes to drive net-zero, electrified, efficient buildings.

✅ Updates apply Base, Stretch, or opt-in Specialized Code.

✅ Targets net-zero by 2050 with electrification-first design.

✅ Municipalities choose code path via City Council or Town Meeting.

Massachusetts will soon see significant updates to the energy codes that govern the construction and alteration of buildings throughout the Commonwealth.

As required by the 2021 climate bill, the Massachusetts Department of Energy Resources (DOER) has recently finalized regulations updating the current Stretch Energy Code, previously promulgated by the state's Board of Building Regulations and Standards (BBRS), and establishing a new Specialized Code geared toward achieving net-zero building energy performance.

The final code has been submitted to the Joint Committee on Telecommunications, Utilities, and Energy for review as required under state law, amid ongoing Connecticut market overhaul discussions that could influence regional dynamics.

Under the new regulations, each municipality must apply one of the following:

Base Energy Code - The current Base Energy Code is being updated by the BBRS as part of its routine updates to the full set of building codes. This base code is the default if a municipality has not opted in to an alternative energy code.

Stretch Code - The updated Stretch Code creates stricter guidelines on energy-efficiency for almost all new constructions and alterations in municipalities that have adopted the previous Stretch Code, paralleling 100% carbon-free target in Minnesota and elsewhere to support building decarbonization. The updated Stretch Code will automatically become the applicable code in any municipality that previously opted-in to the Stretch Code.

Specialized Code - The newly created Specialized Code includes additional requirements above and beyond the Stretch Code, designed to get to ensure that new construction is consistent with a net-zero economy by 2050, similar to Canada's clean electricity regulations that set a 2050 decarbonization pathway. Municipalities must opt-in to adopt the Specialized Code by vote of City Council or Town Meeting.

The new codes are much too detailed to summarize in a blog post. You can read more here. Without going into those details here, it is worth noting a few significant policy implications of the new regulations:

With roughly 90% of Massachusetts municipalities having already adopted the prior version of the Stretch Code, the Commonwealth will effectively soon have a new base code that, even if it does not mandate zero-energy buildings, is nonetheless very aggressive in pushing new construction to be as energy-efficient as possible, as jurisdictions such as Ontario clean electricity regulations continue to reshape the power mix.

Although some concerns have been raised about the cost of compliance, particularly in a period of high inflation, and amid solar demand charge debates in Massachusetts, our understanding is that many developers have indicated that they can work with the new regulations without significant adverse impacts.

Of course, the success of the new codes depends on the success of the Commonwealth's efforts to transition quickly to a zero-carbon electrical grid, supported by initiatives like the state's energy storage solicitation to bolster reliability. If the cost of doing so is higher than expected, there could well be public resistance. If new transmission doesn't get built out sufficiently quickly or other problems occur, such that the power is not available to electrify all new construction, that would be a much more significant problem - for many reasons!

In short, the new regulations unquestionably set the Commonwealth on a course to electrify new construction and squeeze carbon emissions out of new buildings. However, as with the rest of our climate goals, there are a lot of moving pieces, including proposals for a clean electricity standard shaping the power sector that are going to have to come together to make the zero-carbon economy a reality.

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Global Coal Power Decline 2019 signals a record fall in coal-fired electricity as China plateaus, India dips, and the EU and US accelerate renewables, curbing carbon emissions and advancing the global energy transition.

Key Points

A record 2019 drop in global coal power as renewables rise and demand slows across China, India, the EU, and the US.

✅ 3% global fall in coal-fired electricity in 2019.

✅ China plateaus; India declines for first time in decades.

✅ EU and US shift to renewables and gas, cutting emissions.

The world’s use of coal-fired electricity is on track for its biggest annual fall on record this year after more than four decades of near-uninterrupted growth that has stoked the global climate crisis.

Data shows that coal-fired electricity is expected to fall by 3% in 2019, or more than the combined coal generation in Germany, Spain and the UK last year and could help stall the world’s rising carbon emissions this year.

The steepest global slump on record is likely to emerge in 2019 as India’s reliance on coal power falls for the first time in at least three decades this year, and China’s coal power demand plateaus, reflecting the broader global energy transition underway.

Both developing nations are using less coal-fired electricity due to slowing economic growth in Asia as well as the rise of cleaner energy alternatives. There is also expected to be unprecedented coal declines across the EU and the US as developed economies turn to clean forms of energy such as low-cost solar power to replace ageing coal plants.

In almost 40 years the world’s annual coal generation has fallen only twice before: in 2009, in the wake of the global financial crisis, and in 2015, following a slowdown in China’s coal plants amid rising levels of deadly air pollution.

The research was undertaken by the Centre for Research on Energy and Clean Air , the Institute for Energy Economics and Financial Analysis and the UK climate thinktank Sandbag.

The researchers found that China’s coal-fired power generation was flatlining, despite an increase in the number of coal plants being built, because they were running at record low rates. China builds the equivalent of one large new coal plant every two weeks, according to the report, but its coal plants run for only 48.6% of the time, compared with a global utilisation rate of 54% on average.

The findings come after a report from Global Energy Monitor found that the number of coal-fired power plants in the world is growing, because China is building new coal plants five times faster than the rest of the world is reducing their coal-fired power capacity.

The report found that in other countries coal-fired power capacity fell by 8GW in the 18 months to June but over the same period China increased its capacity by 42.9GW.

In a paper for the industry journal Carbon Brief, the researchers said: “A 3% reduction in power sector coal use could imply zero growth in global CO2 emissions, if emissions changes in other sectors mirror those during 2018.”

However, the authors of the report have warned that despite the record coal power slump the world’s use of coal remained far too high to meet the climate goals of the Paris agreement, and some countries are still seeing increases, such as Australia’s emissions rise amid increased pollution from electricity and transport.

The US – which is backing out of the Paris agreement – has made the deepest cuts to coal power of any developed country this year by shutting coal plants down in favour of gas power and renewable energy, with utilities such as Duke Energy facing investor pressure to disclose climate plans. By the end of August the US had reduced coal by almost 14% over the year compared with the same months in 2018.

The EU reported a record slump in coal-fired electricity use in the first half of the year of almost a fifth compared with the same months last year. This trend is expected to accelerate over the second half of the year to average a 23% fall over 2019 as a whole. The EU is using less coal power in favour of gas-fired electricity – which can have roughly half the carbon footprint of coal – and renewable energy, helped by policies such as the UK carbon tax that have slashed coal-fired generation.

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Ontario Global Adjustment Appeal spotlights Ontario's electricity fee, regulatory charge vs tax debate, FIT contracts, green energy policy, and constitutional challenge as National Steel Car contests soaring power costs before the Ontario Superior Court.

Key Points

Court challenge over Ontario's global adjustment fee, disputing its status as a regulatory charge instead of a tax.

✅ Challenges classification of global adjustment as tax vs regulatory charge.

✅ Focuses on FIT contracts, renewable energy payments, power cost impacts.

✅ Appeals Ontario ruling; implications for ratepayers and policy.

A manufacturer of steel rail cars is pursuing an appeal after its lawsuit challenging the constitutionality of a major Ontario electricity fee was struck down earlier this year.

Lawyers for Hamilton, Ont.-based National Steel Car Ltd. filed a notice of appeal in July after Ontario Superior Court Justice Wendy Matheson ruled in June that an electricity fee known as the global adjustment charge was a regulatory charge, and not an unconstitutional tax used to finance policy goals, as National Steel Car alleges.

The company, the decision noted, began its legal crusade last year after seeing its electricity bills had “increased dramatically” since the Ontario government passed green energy legislation nearly a decade ago, and amid concerns that high electricity rates are hurting Ontario manufacturers.

Under that legislation, the judge wrote, “private suppliers of renewable energy were paid to ’feed in’ energy into Ontario’s electricity grid.” The contracts for these so-called “feed-in tariff” contracts, or FIT contracts, were the “primary focus” of the lawsuit.

“The applicant seeks a declaration that part of the amount it has paid for electricity is an unconstitutional tax rather than a valid regulatory charge,” the judge added. “More specifically, it challenges part of the Global Adjustment, which is a component of electricity pricing and incorporates obligations under FIT contracts.”

Chiefly representing the difference between Ontario’s market price for power and the guaranteed price owed to generators, global adjustment now makes up the bulk of the commodity cost of electricity in the province. The fee has risen over the past decade, amid calls to reject steep Nova Scotia rate hikes as well — costing electricity customers $37 billion in global adjustment from 2006 to 2014, according to the province’s auditor general — because of investments in the electricity grid and green-energy contracts, among other reasons.

National Steel Car argued the global adjustment is a tax, and an unconstitutional one at that because it violated a section of the Constitution Act requiring taxes to be authorized by the legislature. The company also said the imposition of the global adjustment broke an Ontario law requiring a referendum to be held for new taxes.

The province, Justice Matheson wrote, had argued “that it is plain and obvious that these applications will fail.” In a decision released in June, the judge granted motions to strike out National Steel Car’s applications.

“The Global Adjustment,” she added, “is not a tax because its purpose, in pith and substance, is not to tax, and it is a regulatory charge and therefore, again, not a tax.”

Now, National Steel Car is arguing that the judge erred in several ways, including in fact, “by finding that the FIT contracts must be paid, when they can be cancelled.”

There has been a change in government at Queen’s Park since National Steel Car first filed its lawsuit last year, and that change has put green energy contracts under fire. The Progressive Conservative government of new Premier Doug Ford has already made a number of decisions on the electricity file, such as moving to cancel and wind down more than 750 renewable energy contracts, as well as repealing the province’s Green Energy Act.

The Tories also struck a commission of inquiry into the province’s finances that warned the global adjustment “may be struck down as unconstitutional,” a warning delivered amid cases where Nova Scotia's regulator approved a 14% rate hike in a high-profile decision.

“There is a risk that a court may find the global adjustment is not a valid regulatory charge if shifting costs over a longer period of time inadvertently results in future ratepayers cross-subsidizing today’s ratepayers,” the commission’s report said.

A spokesperson for Ontario’s Ministry of Energy, Northern Development and Mines said in an email that it would be “inappropriate to comment about the specifics of any case before the courts or currently under arbitration.”

National Steel Car is also prepared to fight its case all the way up to the Supreme Court of Canada, according to its lawyer.

“What is clear from our proceeding with the appeal is National Steel Car has every intention of seeing that lawsuit through to its conclusion if this government isn’t interested or prepared to reasonably settle it,” Jerome Morse said.

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