Adura Energy has received North Sea Transition Authority (NSTA) consent to develop Jackdaw natural gas and condensate field, off the coast of northeast Scotland, following consideration of the company’s environmental statement and agreement to the grant of consent.  NSTA originally granted development consent for Jackdaw to Shell UK in June 2022. But this consent was deemed unlawful and overturned by the Scottish courts in January 2025, following findings that initial environmental approvals had failed to account for the impact of secondary emissions. Estimated reserves at Jackdaw are 72-200 MMboe. The new approval clears the way for Jackdaw to start supplying gas to British homes, power stations, and businesses within weeks, according to Adura, substantially all of the project’s physical infrastructure already having been completed. Alongside Jackdaw’s reapproval, the UK government announced it will launch a £2-billion ($2.7-billion) energy wealth fund fueled by North Sea oil and gas tax revenues to reinvest directly into renewable projects. Adura is a joint venture formed when Shell and Equinor ASA merged their UK offshore oil and gas businesses. The associated Rosebank oil field is following Jackdaw in the regulatory process. An NSTA decision on it is anticipated in the coming weeks. A spokesperson for INEOS Group Ltd. said that “Jackdaw approval is welcome, but the government must stop taxing the North Sea into decline. Approving Jackdaw is the right decision, but this does not stop the damage being done to the North Sea. And it appears Rosebank remains stuck in political limbo.”

WASHINGTON— The U.S. Department of Energy today announced a Request for Proposal for an exchange of up to 315,000 barrels of ultra-low sulfur distillate (fuel oil) from the Northeast Home Heating Oil Reserve (NEHHOR). This solicitation is structured to mitigate supply chain challenges disrupting fuel oil supply. The announced exchange underscores the Trump Administration’s commitment to reliable energy access and lowering costs. Under the terms of the exchange, borrowing companies must return the same volume of fuel oil plus a premium, ensuring that NEHHOR is refilled ahead of the 2027–2028 heating season. “The Trump Administration is committed to doing everything in our power to lower energy costs for the American people,” said U.S. Secretary of Energy Chris Wright. “After receiving Senators Collins’ and Kings’ letter and extensive discussions with Senator Collins, I have directed the Department to exchange barrels from our Northeast Home Heating Oil Reserve to mitigate heightened home heating oil costs during the upcoming winter. Of course, this is a temporary measure to solve a temporary supply disruption. I encourage the governors of New York and New England to work with the Trump Administration to build the Constitution Pipeline and replace home heating oil with low-cost natural gas. Doing so would save their residents billions of dollars in home heating and electricity costs.” DOE will exchange up to 315,000 barrels of fuel oil from NEHHOR storage sites in South Portland, Maine; Boston, Massachusetts; and New Haven, Connecticut. Fuel transfers or deliveries are scheduled to be completed by November 13, 2026. The minimum offer quantity is 25,000 barrels, but not to exceed 30,000, and the volume available per site shall not exceed 150,000. Offerors may submit multiple offers. This approach ensures a competitive bidding process in which both fuel retailers and terminal holders can participate and that product can

A/S Norske Shell and its license partners are investing in a new drilling and well intervention campaign at Ormen Lange in the Norwegian Sea. An investment figure was not disclosed. The campaign, which follows the 2025 start of subsea compression to compensate for the natural pressure drop in the reservoir, includes two sidetracks from existing wells to access additional gas volumes, as well as an option for modifications to a third well. First production is expected in 2029, the operator said in an early October release. The campaign is expected to increase recovery by about 3.5 billion cu m of gas over the life of the field. “Ormen Lange has been producing for almost 20 years, but there is still room for further resources. This investment will enable us to produce gas volumes that today’s wells cannot reach efficiently, thereby creating additional value from the field while contributing to reliable gas supplies to Europe,” said Claire Richardson-Dissel, asset manager for Ormen Lange at Norske Shell. Ormen Lange  Norway’s second largest developed gas field, Ormen Lange was Norway’s first deepwater field development. The field is developed without a platform, with all production from subsea installations installed at depths of up to 1,100 m. Gas from sandstone at a depth of almost 3,000 m is piped up the Storeggakanten peninsula to the onshore plant at Nyhamna in Aukra municipality, where it is processed before export to the UK and the EU.  Shell is operator of Ormen Lange with 17.8% interest. License partners are Petoro AS (36.5%), Equinor Energy AS (25.4%), Orlen Upstream Norway AS (14%), and Vår Energi AS (6.3%).

Saturn Oil & Gas Inc., Calgary, has agreed to acquire privately held Corex Resources Ltd. for $302 million (Can.) through a plan of arrangement, expanding its light oil position from southeast Saskatchewan into southwest Manitoba. The acquisition adds about 7,000 b/d of 100% light oil-weighted production and increases Saturn’s forecast 2026 exit production rate to 54,000-56,000 boe/d from its previous outlook, the company said Oct. 19. Corex’s assets lie adjacent to Saturn’s existing southeast Saskatchewan operations. The company said the transaction adds 323 gross (279 net) identified drilling locations, including booked and unbooked development opportunities, as well as potential open-hole multilateral targets. The acquired asset base is characterized by an average working interest of about 96% and includes operated production infrastructure, pipelines, and other infrastructure. Saturn said it has identified about $6 million/year in operating and efficiency synergies. The addition of Corex’s production is not expected to affect Saturn’s full-year 2026 average production guidance of 43,000-44,000 boe/d, but, Saturn said, the deal, along with Saturn’s expanded 2026 capital program, positions the company to exit 2026 with production of 54,000-56,000 boe/d, establishing a base for 2027. The transaction is expected to close in December 2026, subject to customary conditions.

WASHINGTON— The U.S. Department of Energy (DOE) today announced approximately $967 million in additional funding through its Grid Resilience State and Tribal Formula Grant program to modernize critical energy infrastructure, lower electricity costs and strengthen America’s power grid. The funding will support locally driven projects across states, territories, and tribes to upgrade critical infrastructure, prevent power disruptions, and meet growing electricity demand while helping lower costs for American families and businesses. The investment advances President Trump’s American energy dominance agenda. Projects funded through the program will help states, territories, and tribes invest in infrastructure improvements that protect against disruptive events, improve system performance, and ensure communities and businesses have dependable power when they need it most. “Lowering costs and unleashing prosperity are top priorities for President Trump,” said U.S. Secretary of Energy Chris Wright. “These commonsense investments provide resources directly to states, territories, and tribes to lower electricity costs and strengthen grid reliability for American businesses and families.” “A strong and dependable grid is the backbone of American economic prosperity,” said Office of Electricity Assistant Secretary Katie Jereza. “This funding will help Americans across the country, including our tribal partners, optimize their electricity systems and prepare for future growth while strengthening energy security and deploying technologies that can lower the long-term cost of delivering reliable power.” States, tribes, and U.S. territories can view their funding allocations and application instructions here.

Agiba Petroleum Co.—a 50-50 joint venture of Eni SPA subsidiary IEOC Production BV and Egyptian General Petroleum Corp. (EGPC)—has initiated startup activities for its Meleiha Phase 2 project in Egypt’s Western Desert, advancing development of a gas hub in the Merged Meleiha concession. Part of the operator’s development of a new gas hub within the Merged Meleiha concession and designed to increase processing capacity for from the area’s natural gas fields to support growth of Egypt’s domestic output, the planned installation will be equipped to process up to 100 MMcfd of gas production, Eni said in a release Oct. 20. Planned infrastructure at the site includes development wells, gathering systems, trunklines, and a dedicated gas-export pipeline connecting new production to Egypt’s existing gas network. Eni did not reveal a schedule for completing full startup and commissioning activities for Meleiha Phase 2, but—once completed—the company said the project will help enable the rapid monetization of Egypt’s natural resources and enhanced operational efficiency. Western Desert development Meleiha Phase 2 builds on Agiba’s ongoing exploration and development in the Western Desert concession. In April 2022, Eni reported that three discoveries in the Meleiha concessions had been tied into production, adding an estimated 8,500 boe/d. The Nada E Deep 1X well encountered 60 m of net hydrocarbon pay in the Alam El Bueib and Khatatba formations. Meleiha SE Deep 1X found 30 m in the Matruh and Khatatba formations, while Emry Deep 21 encountered 35 m in Alam El Bueib. Including discoveries made in 2021, Eni said the results brought the exploration total to eight wells, with a 75% success rate. Agiba operates the Meleiha concession, in which it holds a 76% interest alongside partner Lukoil PJSC (24%), according to Eni’s website.