National Grid warns of short supply of electricity over next few days

Ukraine Power Grid Attacks disrupt critical infrastructure as missiles and drones strike power plants, substations, and lines, causing blackouts. Emergency repairs, international aid, generators, and renewables bolster resilience and keep hospitals and water running.

Key Points

Russian strikes on Ukraine's power infrastructure cause blackouts; repairs and aid sustain hospitals and water.

✅ Missile and drone strikes target plants, substations, and lines.

✅ Crews restore power under fire; air defenses protect sites.

✅ Allies supply equipment, generators, and grid repair expertise.

Ukraine is facing an ongoing battle to maintain its electrical grid in the wake of relentless Russian attacks targeting power plants and energy infrastructure. These attacks, which have intensified in the last year, are part of Russia's broader strategy to weaken Ukraine's ability to function amid the ongoing war. Power plants, substations, and energy lines have become prime targets, with Russian forces using missiles and drones to destroy critical infrastructure, as western Ukraine power outages have shown, leaving millions of Ukrainians without electricity and heating during harsh winters.

The Ukrainian government and energy companies are working tirelessly to repair the damage and prevent total blackouts, while also trying to ensure that civilians have access to vital services like hospitals and water supplies. Ukraine has received support from international allies in the form of technical assistance and equipment to help strengthen its power grid, and electricity reserve updates suggest outages can be avoided if no new strikes occur. However, the ongoing nature of the attacks and the complexity of repairing such extensive damage make the situation extraordinarily difficult.

Despite these challenges, Ukraine's resilience is evident, even as winter pressures on the battlefront intensify operations. Energy workers are often working under dangerous conditions, risking their lives to restore power and prevent further devastation. The Ukrainian government has prioritized the protection of energy infrastructure, with military forces being deployed to safeguard workers and critical assets.

Meanwhile, the international community continues to support Ukraine through financial and technical aid, though some U.S. support programs have ended recently, as well as providing temporary power solutions, like generators, to keep essential services running. Some countries have even sent specialized equipment to help repair damaged power lines and energy plants more quickly.

The humanitarian consequences of these attacks are severe, as access to electricity means more than just light—it's crucial for heating, cooking, and powering medical equipment. With winter temperatures often dropping below freezing, plans to keep the lights on are vital to protect vulnerable communities, and the lack of reliable energy has put many lives at risk.

In response to the ongoing crisis, Ukraine has also focused on enhancing its energy independence, seeking alternatives to Russian-supplied energy. This includes exploring renewable energy sources, such as solar and wind power, and new energy solutions adopted by communities to overcome winter blackouts, which could help reduce reliance on traditional energy grids and provide more resilient options in the future.

The battle for energy infrastructure in Ukraine illustrates the broader struggle of the country to maintain its sovereignty and independence in the face of external aggression. The destruction of power plants is not only a military tactic but also a psychological one—meant to instill fear and disrupt daily life. However, the unwavering spirit of the Ukrainian people, alongside international support, including Ukraine's aid to Spain during blackouts as one example, continues to ensure that the fight to "keep the lights on" is far from over.

As Ukraine works tirelessly to repair its energy grid, it also faces the challenge of preparing for the long-term impact of these attacks. The ongoing war has highlighted the importance of securing energy infrastructure in modern conflicts, and the world is watching as Ukraine's resilience in this area could serve as a model for other nations facing similar threats.

Ukraine’s energy struggle is far from over, but its determination to keep the lights on remains a beacon of hope and defiance in the face of ongoing adversity.

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NEIMA advances NRC regulatory modernization, creating a licensing framework for advanced reactors, improving uranium permitting, capping reactor fees, and mandating DOE planning for excess uranium, boosting transparency, accountability, and innovation across the US nuclear sector.

Key Points

NEIMA is a US law modernizing NRC rules and enabling advanced reactor licensing while reforming fees.

✅ Modernizes NRC licensing for advanced reactors

✅ Caps annual reactor fees and boosts transparency

✅ Streamlines uranium permitting; directs DOE plans

Bipartisan legislation modernising US nuclear regulation and supporting the establishment of a licensing framework for next-generation advanced reactors has been signed by US President Donald Trump, whose order boosting U.S. uranium and nuclear energy underscored the administration's focus on the sector.

The Nuclear Energy Innovation and Modernisation Act (NEIMA) became law on 14 January.

As well as directing the Nuclear Regulatory Commission (NRC) to modify the licensing process for commercial advanced nuclear reactor facilities, the bill establishes new transparency and accountability measures to the regulator's budget and fee programmes, and caps fees for existing reactors. It also directs the NRC to look at ways of improving the efficiency of uranium licensing, including investigating the safety and feasibility of extending uranium recovery licences from ten to 20 years' duration, and directs the Department of Energy, which oversees nuclear cleanup and related projects, to issue at least every ten years a long-term plan detailing the management of its excess uranium inventories.

Maria Korsnick, president and CEO of the US Nuclear Energy Institute, described NEIMA as a "significant, positive step" toward the reform of the NRC's fee collection process. "This legislation establishes a more equitable and transparent funding structure which will benefit all operating reactors and future licensees," she said. "The bill also reaffirms Congress’s support for nuclear innovation by working to establish an efficient and stable regulatory structure that is prepared to license the advanced reactors of the future."

Marilyn Kray, president-elect of the American Nuclear Society, said the passage of the legislation was a "big win" for the nation and its nuclear community. "By reforming outdated laws, NRC will now be able to invest more freely in advanced nuclear R&D and licensing activities. This in turn will accelerate deployment of cutting-edge American nuclear systems and better prepare the next generation of nuclear engineers and technologists," she said.

The bill was introduced in 2017 by Senator John Barrasso of Wyoming. It was approved by Congress on 21 December by 361 votes to 10, having been passed by the Senate the previous day, even as later Biden's climate law developments produced mixed results.

NEIMA is one of several bipartisan bills that support advanced nuclear innovation considered by the 115th US Congress, which ended on 2 January. These are: the Nuclear Energy Innovation Capabilities Act (NEICA); the Nuclear Energy Leadership Act; the Nuclear Utilisation of Keynote Energy Act; the Advanced Nuclear Fuel Availability Act, a focus sharpened by the U.S. ban on Russian uranium in the fuel market; and legislation to expedite so-called part 810 approvals, which are needed for the export of technology, equipment and components. NEICA, which supports the deployment of advanced reactors and also directs the DOE to develop a reactor-based fast neutron source for the testing of advanced reactor fuels and materials, was signed into law in October.

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UK Energy Price Cap drives household electricity bills and gas prices, as Ofgem adjusts unit rates amid natural gas shortages, Russia-Ukraine disruptions, inflation, recession risks, and limited storage; government support offers only short-term relief.

Key Points

The UK Energy Price Cap limits per-unit gas and electricity charges set by suppliers and adjusted by Ofgem.

✅ Reflects wholesale natural gas costs; varies quarterly

✅ Protects consumers from sudden electricity and heating bill spikes

✅ Does not cap total annual spend; usage still determines bills

The government organization that controls the cost of energy in Great Britain recently increased what is known as a price cap on household energy bills. The price cap is the highest amount that gas suppliers can charge for a unit of energy.

The new, higher cost has people concerned that they may not be able to pay for their gas and electricity this winter. Some might pay as much as $4,188 for energy next year. Earlier this year, the price cap was at $2,320, and a 16% decrease in bills is anticipated in April.

Why such a change?

Oil and gas prices around the world have been increasing since 2021 as economies started up again after the coronavirus pandemic. More business activities required more fuel.

Then, Russia invaded Ukraine in late February, creating a new energy crisis. Russia limited the amount of natural gas it sent to European countries that needed it to power factories, produce electricity and keep homes warm.

Some energy companies are charging more because they are worried that Russia might completely stop sending gas to European countries. And in Britain, prices are up because the country does not produce much gas or have a good way to store it. As a result, Britain must purchase gas often in a market where prices are high, and ministers have discussed ending the gas-electricity price link to ease bills.

Citibank, a U.S. financial company, believes the higher energy prices will cause inflation in Britain to reach 18 percent in 2023, while EU energy inflation has also been driven higher by energy costs this year. And the Bank of England says an economic slowdown known as a recession will start later this year.

Public health and private aid organizations worry that high energy prices will cause a “catastrophe” as Britons choose between keeping their homes warm and eating enough food.

What can government do?

As prices rise, the British government plans to give people between $450 and $1,400 to help pay for energy costs, while some British MPs push to further restrict the price charged for gas and electricity. But the help is seen by many as not enough.

If the government approves more money for fuel, it will probably not come until September, as the energy security bill moves toward becoming law. That is the time the Conservative Party will select a new leader to replace Prime Minister Boris Johnson.

The Labour Party says the government should increase the amount it provides for people to pay for fuel by raising taxes on energy companies. However, the two politicians who are trying to become the next Prime Minister do not seem to support that idea.

Giovanna Speciale leads an organization called the Southeast London Community Energy group. It helps people pay their bills. She said the money will help but it is only a short-term solution to a bigger problem with Britain’s energy system. Because the system is privately run, she said, “there’s very little that the government can do to intervene in this.”

Other European countries are seeing higher energy costs, but not as high, and at the EU level, gas price cap strategies have been outlined to tackle volatility. In France, gas prices are capped at 2021 levels. In Germany, prices are up by 38 percent since last year. However, the government is reducing some taxes, which will make it easier for the average person to buy gas. In Italy, prices are going up, but the government recently approved over $8 billion to help people pay their energy bills.
 

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Calgary Winter Energy Usage Surge highlights soaring electricity demand, added megawatt-hours, and grid reliability challenges driven by extreme cold, heating loads, and climate change, with summer air conditioning also shifting seasonal peaks.

Key Points

A spike in Calgary's power use from extreme cold, adding 22k MWh and testing reliability as heating demand rises.

✅ +22,000 MWh vs Feb 2018 amid fourth-coldest February

✅ Heating loads spike; summer A/C now drives peak demand

✅ Grid reliability monitored; more solar and green resources ahead

February was so cold in Calgary that the city used enough extra energy to power 3,400 homes for a whole year, echoing record-breaking demand in B.C. in 2021 during severe cold.

Enmax Power Corporation, the primary electricity utility in the city, says the city 's energy consumption was up 22,000 megawatt hours last month compared with Februray 2018.

"We've seen through this cold period our system has held up very well. It's been very reliable," Enmax vice-president Andre van Dijk told the Calgary Eyeopener on Friday. "You know, in the absence of a windstorm combined with cold temperatures and that sort of thing, the system has actually held up pretty well."

The past month was the fourth coldest in Calgary's history, and similar conditions have pushed all-time high demand in B.C. in recent years across the West. The average temperature for last month was –18.1 C. The long-term average for February is –5.4 C.

Watching use, predicting issues

The electricity company monitors demand and load on a daily basis, always trying to predict issues before they happen, van Dijk said, and utilities have introduced winter payment plans to help customers manage bills during prolonged cold.

One of the issues they're watching is climate change, and how extreme temperatures and weather affect both the grid's reliability, as seen when Quebec shattered consumption records during cold snaps, and the public's energy use.

The colder it gets, the higher you turn up the heat. The hotter it is, the more you use air conditioning.

He also noted that using fuels then contributes to climate change, creating a cycle.

​"We are seeing variations in temperature and we've seen large weather events across the continent, across the world, in fact, that impact electrical systems, whether that's flooding, as we've experienced here, or high winds, tornadoes," van Dijk said.

"Climate change and changing weather patterns have definitely had had an impact on us as an electrical industry."

In 2012, he said, Calgary switched from using the most power during winter to using the most during summer, in large part due to air conditioning, he said.

"Temperature is a strong influencer of energy consumption and of our demand," van Dijk said.

Christmas tree lights have also become primarily LED, van Dijk said, which cuts down on a big energy draw in the winter.

He said he expects more solar and other green resources will be added into the electrical system in the future to mitigate how much the increasingly levels of energy use impact climate change, and to help moderate electricity costs in Alberta over time.

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eRex Biomass Power Plant will deliver 300 MW in Japan, offering stable baseload renewable energy, coal-cost parity, and feed-in tariff independence through economies of scale, efficient fuel procurement, and utility-scale operations supporting RE100 demand.

Key Points

A 300 MW Japan biomass project targeting coal-cost parity and FIT-free, stable baseload renewable power.

✅ 300 MW capacity; enough for about 700,000 households

✅ Aims to skip feed-in tariff via economies of scale

✅ Targets coal-cost parity with stable, dispatchable output

Power supplier eRex will build its largest biomass power plant to date in Japan, hoping the facility's scale will provide healthy margins, a strategy increasingly seen among renewable developers pursuing diverse energy sources, and a means of skipping the government's feed-in tariff program.

The Tokyo-based electric company is in the process of selecting a location, most likely in eastern Japan. It aims to open the plant around 2024 or 2025 following a feasibility study. The facility will cost an estimated 90 billion yen ($812 million) or so, and have an output of 300 megawatts -- enough to supply about 700,000 households. ERex may work with a regional utility or other partner

The biggest biomass power plant operating in Japan currently has an output of 100 MW. With roughly triple that output, the new facility will rank among the world's largest, reflecting momentum toward 100% renewable energy globally that is shaping investment decisions.

Nearly all biomass power facilities in Japan sell their output through the government-mediated feed-in tariff program, which requires utilities to buy renewable energy at a fixed price. For large biomass plants that burn wood or agricultural waste, the rate is set at 21 yen per kilowatt-hour. But the program costs the Japanese public more than 2 trillion yen a year, and is said to hamper price competition.

ERex aims to forgo the feed-in tariff with its new plant by reaping economies of scale in operation and fuel procurement. The goal is to make the undertaking as economical as coal energy, which costs around 12 yen per kilowatt-hour, even as solar's rise in the U.S. underscores evolving benchmarks for competitive renewables.

Much of the renewable energy available in Japan is solar power, which fluctuates widely according to weather conditions, though power prediction accuracy has improved at Japanese PV projects. Biomass plants, which use such materials as wood chips and palm kernel shells as fuel, offer a more stable alternative.

Demand for reliable sources of renewable energy is on the rise in the business world, as shown by the RE100 initiative, in which 100 of the world's biggest companies, such as Olympus, have announced their commitment to get 100% of their power from renewable sources. ERex's new facility may spur competition.

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Canada 2035 Clean Electricity Target faces a 48.4GW shortfall as renewable capacity lags; accelerating wind, solar PV, grid upgrades, and coherent federal-provincial policy is vital to reach zero-emissions power and strengthen transmission and distribution.

Key Points

Canada's plan to supply nearly 100% of electricity from zero-emitting sources by 2035, requiring renewable buildout.

✅ Average adds 2.6GW; shortfall totals 48.4GW by 2035

✅ Expand wind, solar PV, storage, and grid modernization

✅ Align federal-province policy; retire or convert thermal plants

GlobalData’s latest report, ‘Canada Power Market Size and Trends by Installed Capacity, Generation, Transmission, Distribution and Technology, Regulations, Key Players and Forecast, 2022-2035’, discusses the power market structure of Canada and, amid looming power challenges, provides historical and forecast numbers for capacity, generation and consumption up to 2035. Detailed analysis of the country’s power market regulatory structure, competitive landscape and a list of major power plants are provided. The report also gives a snapshot of the power sector in the country on broad parameters of macroeconomics, supply security, generation infrastructure, transmission and distribution infrastructure, electricity import and export scenario, degree of competition, regulatory scenario, and future potential. An analysis of the deals in the country’s power sector is also included in the report.

Canada is expected to fall short of its 2035 clean electricity target after reviewing the country’s current renewable capacity activity. The country has targeted to produce nearly 100% of its electricity from zero-emitting sources by 2035, while electricity associations' net-zero goals extend to 2050; however, the country is adding only 2.6GW of annual renewable capacity additions on average every year, which would mean a cumulative shortfall of 48.4GW.

Canada has good governmental support, but it is not doing enough to ensure its targets are met. If the country is to meet its target to produce nearly 100% of electricity from zero-emitting sources by 2035, the country should both increase the capacity and efficiency of renewable power plants, as well as provide comprehensive end-to-end policies at both the federal and provincial levels, as debates over whether Ontario is embracing clean power continue across provinces. It should also involve communities and businesses in raising awareness of the benefits of adopting renewable energy.

The country has a large amount of proven natural gas and oil reserves that are proving too tempting an opportunity, and the Canadian Government is planning to increase the capacity of its gas-based plants under net-zero regulations permit some gas in the power mix, to secure real-time demand and supply. However, the country’s dependency on gas-based plants creates a major challenge to achieve its 2035 clean electricity target.

If the Canadian Government is to meet its 2035 targets, it should draw on examples from its European counterparts and add renewable capacity at a rapid pace, while balancing demand and emissions in key provinces. One advantage for Canada here is that it does not have land constraints, which is common in other major renewable power-generating countries. This could give the country an estimated 6.1GW of renewable capacity every year on average during the 2021-2035 period: enough capacity to meet its target. Most of these installations are expected to be for wind and solar PV.

Changing provincial governments are not helpful when it comes to implementing long-term projects, especially as Ontario faces looming electricity shortfalls that heighten planning risks, and continued stopping and starting of projects like this will only be damaging to renewable goals. Another way the country can achieve its target is by converting thermal power plants into clean energy plants and providing a roadmap or timeline for provinces to retire thermal power plants completely, even as scrapping coal can be costly for some systems.

Canada’s GDP (at constant prices) increased from $1,617.3bn in 2010 to $1,924.5bn in 2021, at a CAGR of 1.6%. The GDP (at constant prices) of the country declined sharply from $1,943.8bn in 2019 to $1,840.5bn in 2020 because of Covid-19 pandemic. After the recommencement of regular industrial and trade activities, the GDP grew by 4.6% in 2021 from 2020. The GDP is expected to cross pre-pandemic levels by the end of 2022.

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