India identifies potential sites for nuclear power plants

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Speaking at the "Unleashing the Power of Nuclear Energy" conference organized by the Associated Chambers of Commerce and Industry of India, Prithviraj Chavan, the Minister of State in the Prime Minister's Office, said that India's Department of Atomic Energy's Site Selection Committee has identified five to seven sites to develop large-scale nuclear power plants.

The announcement indicates that India would be able to achieve its target of having an installed nuclear power generation capacity of 20,000 megawatts (MW) by 2020.

Chavan said that the final list of sites would be officially announced after a meeting of the Cabinet for approval of the proposed sites. The sites would be utilized to set up nuclear power parks based on imported light water reactors. Chavan added that the government expected U.S.-based companies to set up nuclear parks at a few of the proposed sites.

The Indian government plans to set up a number of nuclear parks in inland and coastal regions all over the country. Each site will house six to eight reactors. The Koodankulam site in Tamil Nadu is currently being developed in collaboration with Russia, while the Jaitapur site in Maharashtra has been allotted to Areva SA to develop 1,650-MW European pressurized reactors. To ensure a stable fuel supply for the country's reactors, the government is also considering the possibility of acquiring uranium mines overseas.

Chavan added that two joint-venture agreements, one with the U.S. and another with a French firm, have already been signed to produce nuclear power equipment, and several more are likely to be signed in the future. Lars-Olof Lindgren, the Ambassador of Sweden to India, who was present at the conference, said that a high-powered French delegation would visit India shortly and focus on technology transfer related to nuclear energy. Lindgren also offered the services of his country's research scientists and technology, which is rich and has proved to be very safe.

Chavan said that there is no possibility of 100% foreign direct investment in India's nuclear power sector. All private players interested in foraying into the country's nuclear power sector would be permitted to do so only in collaboration with centrally regulated bodies such as Bhabha Atomic Research Centre and Nuclear Power Corporation of India Limited.

Private companies would be permitted to hold only a minority stake in all such ventures. Beginning at 25% to 26%, the private companies' stake could reach a maximum of 49%.

Changes to this rule can be expected only after the government amends the Atomic Energy Act of 1962, which is not likely to happen soon and without any opposition. The act does not permit private-sector participation in the country's nuclear power sector. Almost all of the non-government speakers at the conference demanded modifications to the act to allow greater participation from the private sector.

The draft legislation for amending the act has been drawn up but will be passed only after the Parliament resumes work after the upcoming elections. The Nuclear Draft Liability Bill is also ready and is expected to be passed once the new government comes into office.

At this stage, the central government intends to have a strong regulatory mechanism in place to regulate the country's nuclear power generation. Such measures would be necessary to ensure that the central government has complete control over nuclear power generation processes in the country.

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Spain's power demand in April plummets under COVID-19 lockdown

Spain Electricity Demand April 2020 saw a 17.3% year-on-year drop as COVID-19 lockdown curbed activity; renewables and wind power lifted the emission-free share, while combined cycle plants dominated islands, per REE data.

 

Key Points

A 17.3% y/y decline amid COVID-19 lockdown, with 47.9% renewables and wind at 21.3% of the national power mix.

✅ Mainland demand -17%; Balearic -27.6%; Canary -20.3%.

✅ Emission-free share: 49.7% on the peninsula in April.

✅ Combined cycle led islands; coal absent in Balearics.

 

Demand for electricity in Spain dropped by 17.3% year-on-year to an estimated 17,104 GWh in April, aligning with a 15% global daily demand dip during the pandemic, while the country’s economy slowed down under the national state of emergency and lockdown measures imposed to curb the spread of COVID-19.

According to the latest estimates by Spanish grid operator Red Electrica de Espana (REE), the decline in demand was registered across Spain’s entire national territory, similar to a 10% UK drop during lockdown. On the mainland, it decreased by 17% to 16,191 GWh, while on the Balearic and the Canary Islands it plunged by 27.6% and 20.3%, respectively.

Renewables accounted for 47.9% of the total national electricity production in April, echoing Britain’s cleanest electricity trends during lockdown. Wind power production went down 20% year-on-year to 3,730 GWh, representing a 21.3% share in the total power mix.

During April, electricity generation in the peninsula was mostly based on emission-free technologies, reflecting an accelerated power-system transition across Europe, with renewables accounting for 49.7%. Wind farms produced 3,672 GWh, 20.1% less compared to April 2019, while contributing 22% to the power mix, even as global demand later surpassed pre-pandemic levels in subsequent periods.

In the Balearic Islands, electricity demand of 323,296 MWh was for the most part met by combined cycle power plants, even as some European demand held firm in later lockdowns, which accounted for 78.3% of the generation. Renewables and emission-free technologies had a combined share of 6.4%, while coal was again absent from the local power mix, completing now four consecutive months without contributing a single MWh.

In the Canary Islands system, demand for power decreased to 558,619 MWh, even as surging demand elsewhere strained power systems across the world. Renewables and emission-free technologies made up 14.3% of the mix, while combined cycle power plants led with a 45.3% share.

 

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Barakah Unit 1 reaches 100% power as it steps closer to commercial operations, due to begin early 2021

Barakah Unit 1 100 Percent Power signals the APR-1400 reactor delivering 1400MW of clean baseload electricity to the UAE grid, advancing decarbonisation, reliability, and Power Ascension Testing milestones ahead of commercial operations in early 2021.

 

Key Points

The milestone where Unit 1 reaches full 1400MW output to the UAE grid, providing clean, reliable baseload electricity.

✅ Delivers 1400MW from a single generator to the UAE grid

✅ Enables clean, reliable baseload power with zero operational emissions

✅ Completes key Power Ascension Testing before commercial operations

 

The Emirates Nuclear Energy Corporation, ENEC, has announced that its operating and maintenance subsidiary, Nawah Energy Company, Nawah, has successfully achieved 100% of the rated reactor power capacity for Unit 1 of the Barakah Nuclear Energy Plant. This major milestone, seen as a crucial step in Abu Dhabi towards completion, brings the Barakah plant one step closer to commencing commercial operations, scheduled in early 2021.

100% power means that Unit 1 is generating 1400MW of electricity from a single generator connected to the UAE grid for distribution. This milestone makes the Unit 1 generator the largest single source of electricity in the UAE.

The Barakah Nuclear Energy Plant is the largest source of clean baseload electricity in the country, capable of providing constant and reliable power in a sustainable manner around the clock. This significant achievement accelerates the decarbonisation of the UAE power sector, while also supporting the diversification of the Nation’s energy portfolio as it transitions to cleaner electricity sources, similar to the steady development in China of nuclear energy programs now underway.

The accomplishment follows shortly after the UAE’s celebration of its 49th National Day, providing a strong example of the country’s progress as it continues to advance towards a sustainable, clean, secure and prosperous future, having made the UAE the first Arab nation to open a nuclear plant as it charts this path. As the Nation looks towards the next 50 years of achievements, the Barakah plant will generate up to 25 percent of the country’s electricity, while also acting as a catalyst of the clean carbon future of the Nation.

Mohamed Ibrahim Al Hammadi, Chief Executive Officer of ENEC said: "We are proud to deliver on our commitment to power the growth of the UAE with safe, clean and abundant electricity. Unit 1 marks a new era for the power sector and the future of the clean carbon economy of the Nation, with the largest source of electricity now being generated without any emissions. I am proud of our talented UAE Nationals, working alongside international experts who are working to deliver this clean electricity to the Nation, in line with the highest standards of safety, security and quality." Nawah is responsible for operating Unit 1 and has been responsible for safely and steadily raising the power levels since it commenced the start-up process in July, and connection to the grid in August.

Achieving 100% power is one of the final steps of the Power Ascension Testing (PAT) phase of the start-up process for Unit 1. Nawah’s highly skilled and certified nuclear operators will carry out a series of tests before the reactor is safely shut down in preparation for the Check Outage. During this period, the Unit 1 systems will be carefully examined, and any planned or corrective maintenance will be performed to maintain its safety, reliability and efficiency prior to the commencement of commercial operations.

Ali Al Hammadi, Chief Executive Officer of Nawah, said: "This is a key achievement for the UAE, as we safely work through the start-up process for Unit 1 of the Barakah plant. Successfully reaching 100% of the rated power capacity in a safe and controlled manner, undertaken by our highly trained and certified nuclear operators, demonstrates our commitment to safe, secure and sustainable operations as we now advance towards our final maintenance activities and prepare for commercial operations in 2021." The Power Ascension Testing of Unit 1 is overseen by the independent national regulator – the Federal Authority for Nuclear Regulation (FANR), which has conducted 287 inspections since the start of Barakah’s development. These independent reviews have been conducted alongside more than 40 assessments and peer reviews by the International Atomic Energy Agency, IAEA, and World Association of Nuclear Operators, WANO, reflecting milestones at nuclear projects worldwide that benchmark safety and performance.

This is an important milestone for the commercial performance of the Barakah plant. Barakah One Company, ENEC’s subsidiary in charge of the financial and commercial activities of the Barakah project signed a Power Purchase Agreement, PPA, with the Emirates Water and Electricity Company, EWEC, in 2016 to purchase all of the electricity generated at the plant for the next 60 years. Electricity produced at Barakah feeds into the national grid in the same manner as other power plants, flowing to homes and business across the country.

This milestone has been safely achieved despite the challenges of COVID-19. Since the beginning of the global pandemic, ENEC, and subsidiaries Nawah and Barakah One Company, along with companies that form Team Korea, including Korea Hydro & Nuclear Power, with KHNP’s work in Bulgaria illustrating its global role, have worked closely together, in line with all national and local health authority guidelines, to ensure the highest standards for health and safety are maintained for those working on the project. ENEC and Nawah’s robust business continuity plans were activated, alongside comprehensive COVID-19 prevention and management measures, including access control, rigorous testing, and waste water sampling, to support health and wellbeing.

The Barakah Nuclear Energy Plant, located in the Al Dhafra region of the Emirate of Abu Dhabi, is one of the largest nuclear energy new build projects in the world, with four APR-1400 units. Construction of the plant began in 2012 and has progressed steadily ever since. Construction of Units 3 and 4 are in the final stages with 93 percent and 87 percent complete respectively, benefitting from the experience and lessons learned during the construction of Units 1 and 2, while the construction of the Barakah Plant as a whole is now more than 95 percent complete.

Once the four reactors are online, Barakah Plant will deliver clean, efficient and reliable electricity to the UAE grid for decades to come, providing around 25 percent of the country’s electricity and, as other nations like Bangladesh expand with IAEA assistance, reinforcing global decarbonisation efforts, preventing the release of up to 21 million tons of carbon emissions annually – the equivalent of removing 3.2 million cars off the roads each year.

 

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Oil crash only a foretaste of what awaits energy industry

Oil and Gas Profitability Decline reflects shale-driven oversupply, OPEC-Russia dynamics, LNG exports, renewables growth, and weak demand, signaling compressed margins for producers, stressed petrodollar budgets, and shifting energy markets post-Covid.

 

Key Points

A sustained squeeze on hydrocarbon margins from agile shale supply, weaker OPEC leverage, and expanding renewables.

✅ Shale responsiveness caps prices and erodes industry rents

✅ OPEC-Russia cuts face limited impact versus US supply

✅ Renewables and EVs slow long-term oil and gas demand

 

The oil-price crash of March 2020 will probably not last long. As in 2014, when the oil price dropped below $50 from $110 in a few weeks, this one will trigger a temporary collapse of the US shale industry. Unless the coronavirus outbreak causes Armageddon, cheap oil will also support policymakers’ efforts to help the global economy.

But there will be at least one important and lasting difference this time round — and it has major market and geopolitical implications.

The oil price crash is a foretaste of where the whole energy sector was going anyway — and that is down.

It may not look that way at first. Saudi Arabia will soon realise, as it did in 2015, that its lethal decision to pump more oil is not only killing US shale but its public finances as well. Riyadh will soon knock on Moscow’s door again. Once American shale supplies collapse, Russia will resume co-operation with Saudi Arabia.

With the world economy recovering from the Covid-19 crisis by then, and with electricity demand during COVID-19 shifting, moderate supply cuts by both countries will accelerate oil market recovery. In time, US shale producers will return too.

Yet this inevitable bounceback should not distract from two fundamental factors that were already remaking oil and gas markets. First, the shale revolution has fundamentally eroded industry profitability. Second, the renewables’ revolution will continue to depress growth in demand.

The combined result has put the profitability of the entire global hydrocarbon industry under pressure. That means fewer petrodollars to support oil-producing countries’ national budgets, including Canada's oil sector exposures. It also means less profitable oil companies, which traditionally make up a large segment of stock markets, an important component of so many western pension funds.

Start with the first factor to see why this is so. Historically, the geological advantages that made oil from countries such as Saudi Arabia so cheap to produce were unique. Because oil and gas were produced at costs far below the market price, the excess profits, or “rent”, enjoyed by the industry were very large.

Furthermore, collusion among low-cost producers has been a winning strategy. The loss of market share through output cuts was more than compensated by immediately higher prices. It was the raison d’être of Opec.

The US shale revolution changed all this, exposing the limits of U.S. energy dominance narratives. A large oil-producing region emerged with a remarkable ability to respond quickly to price changes and shrink its costs over time. Cutting back cheap Opec oil now only increases US supplies, with little effect on world prices.

That is why Russia refused to cut production this month. Even if its cuts did boost world prices — doubtful given the coronavirus outbreak’s huge shock to demand — that would slow the shrinkage of US shale that Moscow wants.

Shale has affected the natural gas industry even more. Exports of US liquefied natural gas now put an effective ceiling on global prices, and debates over a clean electricity push have intensified when gas prices spike.

On top of all this, there is also the renewables’ revolution, though a green revolution has not been guaranteed in the near term. Around the world, wind and solar have become ever-cheaper options to generate electricity. Storage costs have also dropped and network management improved. Even in the US, renewables are displacing coal and gas. Electrification of vehicle fleets will damp demand further, as U.S. electricity, gas, and EVs face evolving pressures.

Eliminating fossil fuel consumption completely would require sustained and costly government intervention, and reliability challenges such as coal and nuclear disruptions add to the complexity. That is far from certain. Meanwhile, though, market forces are depressing the sector’s usual profitability.

The end of oil and gas is not immediately around the corner. Still, the end of hydrocarbons as a lucrative industry is a distinct possibility. We are seeing that in dramatic form in the current oil price crash. But this collapse is merely a message from the future.

 

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Southern California Edison Faces Lawsuits Over Role in California Wildfires

SCE Wildfire Lawsuits allege utility equipment and power lines sparked deadly Los Angeles blazes; investigations, inverse condemnation, and stricter utility regulations focus on liability, vegetation management, and wildfire safety amid Santa Ana winds.

 

Key Points

Residents sue SCE, alleging power lines ignited LA wildfires; seeking compensation under inverse condemnation.

✅ Videos cited show sparking lines near alleged ignition points.

✅ SCE denies wrongdoing; probes and inspections ongoing.

✅ Inverse condemnation may apply regardless of negligence.

 

In the aftermath of devastating wildfires in Los Angeles, residents have initiated legal action, similar to other mega-fire lawsuits underway in California, against Southern California Edison (SCE), alleging that the utility's equipment was responsible for sparking one of the most destructive fires. The fires have resulted in significant loss of life and property, prompting investigations into the causes and accountability of the involved parties.

The Fires and Their Impact

In early January 2025, Los Angeles experienced severe wildfires that ravaged neighborhoods, leading to the loss of at least 29 lives and the destruction of approximately 155 square kilometers of land. Areas such as Pacific Palisades and Altadena were among the hardest hit. The fires were exacerbated by arid conditions and strong Santa Ana winds, which contributed to their rapid spread and intensity.

Allegations Against Southern California Edison

Residents have filed lawsuits against SCE, asserting that the utility's equipment, particularly power lines, ignited the fires. Some plaintiffs have presented videos they claim show sparking power lines in the vicinity of the fire's origin. These legal actions seek to hold SCE accountable for the damages incurred, including property loss, personal injury, and emotional distress.

SCE's Response and Legal Context

Southern California Edison has denied any wrongdoing, stating that it has not detected any anomalies in its equipment that could have led to the fires. The utility has pledged to cooperate fully with investigations to determine the causes of the fires. California's legal framework, particularly the doctrine of "inverse condemnation," allows property owners to seek compensation from utilities for damages caused by public services, even without proof of negligence. This legal principle has been central in previous cases involving utility companies and wildfire damages, and similar allegations have arisen in other jurisdictions, such as an alleged faulty transformer case, highlighting shared risks.

Historical Context and Precedents

This situation is not unprecedented. In 2018, Pacific Gas and Electric (PG&E) faced similar allegations when its equipment was implicated in the Camp Fire, the deadliest wildfire in California's history. PG&E's equipment was found to have ignited the fire, and the company later pleaded guilty in the Camp Fire, leading to extensive litigation and financial repercussions for the company, while its bankruptcy plan won support from wildfire victims during restructuring. The case highlighted the significant risks utilities face regarding wildfire safety and the importance of maintaining infrastructure to prevent such disasters.

Implications for California's Utility Regulations

The current lawsuits against SCE underscore the ongoing challenges California faces in balancing utility operations with wildfire prevention, as regulators face calls for action amid rising electricity bills. The state has implemented stricter regulations and oversight, and lawmakers have moved to crack down on utility spending to mitigate wildfire risks associated with utility infrastructure. Utilities are now required to invest in enhanced safety measures, including equipment inspections, vegetation management, and the implementation of advanced technologies to detect and prevent potential fire hazards. These regulatory changes aim to reduce the incidence of utility-related wildfires and protect communities from future disasters.

The legal actions against Southern California Edison reflect the complex interplay between utility operations, public safety, and environmental stewardship. As investigations continue, the outcomes of these lawsuits may influence future policies and practices concerning utility infrastructure and wildfire prevention in California. The state remains committed to enhancing safety measures to protect its residents and natural resources from the devastating effects of wildfires.

 

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EU Plans To Double Electricity Use By 2050

European Green Deal Electrification accelerates decarbonization via renewables, electric vehicles, heat pumps, and clean industry, backed by sustainable finance, EIB green lending, just transition funds, and energy taxation reform to phase out fossil fuels.

 

Key Points

An EU plan to replace fossil fuels with renewable electricity in transport, buildings, and industry, supported by green finance.

✅ Doubles electricity's share to cut CO2 and phase out fossil fuels.

✅ Drives EVs, heat pumps, and electrified industry via renewables.

✅ Funded by EIB lending, EU budget, and just transition support.

 

The European Union is preparing an ambitious plan to completely decarbonize by 2050. Increasing the share of electricity in Europe’s energy system – electricity that will increasingly come from renewable sources - will be at the center of this strategy, aligning with the broader global energy transition under way, the new head of the European Commission’s energy department said yesterday.

This will mean more electric cars, electric heating and electric industry. The idea is that fossil fuels should no longer be a primary energy source, heating homes, warming food or powering cars. In the medium term they should only be used to generate electricity, a shift mirrored by New Zealand's electricity shift efforts, which then powers these things, resulting in less CO2 emissions.

“First assessments show we need to double the share of electricity in energy consumption by 2050,” Ditte Juul-Jørgensen said at an event in Brussels this week, a goal echoed by recent calls to double investment in power systems from world leaders. “We’ve already seen an increase in the last decade, but we need to go further”.

Juul-Jørgensen, who started in her job as director-general of the commission’s energy department in August, has come to the role at a pivotal time for energy. The 2050 decarbonization proposal from the Commission, the EU’s executive branch, is expected to be approved next month by EU national leaders. A veto from Poland that has blocked adoption until now is likely to be overcome if Poland and other Eastern European countries are offered financial assistance from a “just transition fund”, according to EU sources.

Ursula von der Leyen, the incoming President of the Commission, has promised to unveil a “European Green Deal” in her first 100 days in office designed to get the EU to its 2050 goal. Juul-Jørgensen will be working with the incoming EU Energy Commissioner, Kadri Simson, on designing this complex strategy. The overall aim will be to phase out fossil fuels, and increase the use of electricity from green sources, amid trends like oil majors pivoting to electric across Europe today.

“This will be about how do we best make use of electricity to feed into other sectors,” Juul-Jørgensen said. “We need to think about transforming it into other sources, and how to best transport it.”

“But the biggest challenge from what I see today is that of investment and finance - the changes we have to make are very significant.”

 

Financing problems

The Commission is going to try to tackle the challenges of financing the energy transition with two tools: dedicated climate funding in the EU budget, and dedicated climate lending from the European Investment Bank.

“The EIB will play an increasing role in future. We hope to see agreement [with the EIB board] on that in the coming months so there’s a clear operator in the EIB to support the green transition. We’re looking at something around €400 billion a year.”

The Commission’s proposed dedicated climate spending in the next seven-year budget must still be approved by the 28 EU national governments. Juul-Jørgensen said there is unanimous agreement on the amount: 25% of the budget. But there is disagreement about how to determine what is green spending.

“A lot of work has been ongoing to ensure that when it comes to counting it reflects the reality of the investments,” she said. “We’re working on the taxonomy on sustainable finance - internally identifying sectors contributing to overall climate objectives.”

 

Electricity pact

Juul-Jørgensen was speaking at an event organized by the the Electrification Alliance, a pact between nine industry organizations to lobby for electricity to be put at the heart of the European green deal. They signed a declaration at the event calling for a variety of measures to be included in the green deal, reflecting debates over a fully renewable grid by 2030 in other jurisdictions, including a change to the EU’s energy taxation regime which incentivizes a switch from fossil fuel to electricity consumption.

“Electrification is the most important solution to turn the vision of a fossil-free Europe into reality,” said Laurence Tubiana, CEO of the European Climate Foundation, one of the signatories, and co-architect of the Paris Agreement.

“We are determined to deliver, but we must be mindful of the different starting points and secure sufficient financing to ensure a fair transition”, said Magnus Hall, President of electricity industry association Eurelectric, another signatory.

The energy taxation issue has been particularly tricky for the EU, since any change in taxation rules requires the unanimous consent of all 28 EU countries. But experts say that current taxation structures are subsidizing fossil fuels and punishing electricity, as recent UK net zero policy changes illustrate, and unless this is changed the European Green Deal can have little effect.

“Yes this issue will be addressed in the incoming commission once it takes up its function,” Juul-Jørgensen said in response to an audience question. “We all know the challenge - the unanimity requirement in the Council - and so I hope that member states will agree to the direction of work and the need to address energy taxation systems to make sure they’re consistent with the targets we’ve set ourselves.”

But some are concerned that the transformation envisioned by the green deal will have negative impacts on some of the most vulnerable members of society, including those who work in the fossil fuel sector.

This week the Centre on Regulation in Europe sent an open letter to Frans Timmermans, the Commission Vice President in charge of climate, warning that they need to be mindful of distributional effects. These worries have been heightened by the yellow vest protests in France, which were sparked by French President Emmanuel Macron’s attempt to increase fuel taxes for non-electric cars.

“The effectiveness of climate action and sustainability policies will be challenged by increasing social and political pressures,” wrote Máximo Miccinilli, the center’s director for energy. “If not properly addressed, those will enhance further populist movements that undermine trust in governance and in the public institutions.”

Miccinilli suggests that more research be done into identifying, quantifying and addressing distributional effects before new policies are put in place to phase out fossil fuels. He proposes launching a new European Observatory for Distributional Effects of the Energy Transition to deal with this.

EU national leaders are expected to vote on the 2050 decarbonization target, building on member-state plans such as Spain's 100% renewable electricity goal by mid-century, at a summit in Brussels on December 12, and Von der Leyen will likely unveil her European Green Deal in March.

 

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ABL Secures Contract for UK Subsea Power

ABL has secured a contract for the UK Subsea Power Link, highlighting ABL Group’s marine warranty role in Eastern Green Link 2, a 2 GW offshore electricity superhighway connecting Scotland and England to enhance grid reliability and renewable energy transmission.

 

Key Points: ABL Group’s contract for the UK Subsea Power Link

ABL Group has been appointed to provide marine warranty survey services for the 2 GW Eastern Green Link 2 subsea interconnector between Scotland and England.

✅ Manages vessel suitability checks, installation oversight, and DP assurance

✅ Strengthens UK grid reliability and advances the clean energy transition

✅ Sizeable contract valued between USD 1 million and 3 million

 

Energy and marine consultancy ABL, a subsidiary of ABL Group, has been awarded a contract by Eastern Green Link 2 (EGL2) to provide marine warranty survey (MWS) services for the installation of a new 2 GW subsea power connection between Scotland and England.

EGL2 is one of the United Kingdom’s most significant energy-infrastructure projects, involving the creation of a 505-kilometre “electricity superhighway” that will enable simultaneous power transfer between Peterhead in Aberdeenshire and Drax in North Yorkshire, mirroring a renewable power link announced for the same corridor recently. The project is designed to strengthen grid resilience, integrate renewable energy from Scotland’s offshore resources, and advance the UK’s broader energy transition goals.

Under the terms of the contract, ABL will be responsible for the technical review and approval of the project and procedural documentation, as well as conducting suitability surveys of the proposed fleet for marine transportation and installation operations. The company will also provide dynamic positioning (DP) assurance where required and will review and approve all warranted operations through on-site attendances, reflecting practices used on projects like the Great Northern Transmission Line in North America.

Cable-laying operations for the link are scheduled to take place between January and September 2028, amid wider efforts to fast-track grid connections across the UK. According to ABL, the engagement represents a “sizeable” contract, valued between USD 1 million and 3 million.

“This appointment reflects ABL's reputation as a trusted MWS partner for major power transmission infrastructure development and reinforces our position at the forefront of supporting the UK's energy transition,” said Hege Norheim, CEO of ABL Group. “We look forward to contributing to this strategic initiative.”

The subsea interconnector, known as Eastern Green Link 2, will transmit up to 2 gigawatts of electricity—enough to power approximately 2 million homes. It forms part of the Great Grid Upgrade, National Grid’s nationwide program to modernize and expand the transmission network in preparation for a low-carbon future, alongside a recent 2 GW substation milestone.

By linking renewable-rich northern Scotland with high-demand regions in England, EGL2 is expected to reduce congestion on the existing grid by leveraging HVDC technology to improve transfer efficiency, enhance security of supply, and facilitate the more efficient flow of surplus renewable energy south. The connection will also support the UK government’s target of decarbonizing the electricity system by 2035.

ABL’s appointment follows a period of intensive marine and geotechnical surveys along the proposed cable route to assess seabed conditions and environmental sensitivities. The company’s marine warranty oversight will ensure that transportation and installation operations meet strict safety, technical, and environmental standards demanded by insurers and project partners, as seen in a recent cross-border transmission approval in North America.

For ABL Group, which provides engineering and risk services to the offshore energy and marine industries worldwide, the contract marks another milestone in its expanding portfolio of subsea power and transmission projects across Europe. With operations set to begin in 2028, the Eastern Green Link 2 initiative represents both a major engineering challenge and a key enabler of the UK’s offshore energy ambitions, echoing a recent offshore wind power milestone in the U.S.

 

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