Norway Reopens Three North Sea Gas Fields After 30 Years as Britain's Offshore Industry Contracts

Norway Reopens Three North Sea Gas Fields After 30 Years as Britain's Offshore Industry Contracts ConocoPhillips targets Q4 2028 production at 5.7 Mcm/day from fields yielding up to 120 million barrels, while UK's OEUK cuts staff. Norway's energy ministry has approved development plans for three gas fields in the southern North Sea — Albuskjell, Vest Ekofisk, and Tommeliten Gamma — that will reopen in 2028 after three decades of inactivity, Montel reported. The three fields together are expected to yield 90 to 120 million barrels of oil equivalent, mainly gas and condensate, equating to approximately 150 to 211 terawatt-hours. Total investment will be around EUR 1.8 billion.² ConocoPhillips, the operator, told Montel that production should start during the fourth quarter of 2028, with daily output at 5.7 million cubic metres. That equates to about 1.5% of Norway's average daily gas production. The increment is modest in isolation. But it arrives at a moment when every additional molecule of European-sourced pipeline gas carries strategic value that exceeds its commodity price.² Equinor is already locking in long-term gas supply contracts to capitalise on European demand. The Norwegian energy company signed a five-year agreement to supply up to 0.5 billion cubic metres of natural gas annually to Netherlands-based utility Eneco, beginning in February 2026. The deal secures Norwegian pipeline gas for the German market through Eneco's subsidiary LichtBlick, adding to the web of bilateral contracts that are replacing spot market dependence.³ The oil market backdrop is unstable. ICE Brent crude front-month eased on Monday after Trump offered safe passage for ships trapped in the Strait of Hormuz, but talks to end the war remained deadlocked, Montel reported. A previous two-week ceasefire agreement in April had sent Brent plunging around 15% to $93. The market has learned to sell the headline and buy the reality.^1,8 Britain's North Sea industry is moving in the opposite direction. The Economist described the collapse of Britain's oil and gas sector, arguing that Labour's policy is a muddle but critics' talk of a North Sea renaissance is fanciful. The basin is mature. The economics are difficult. The political environment is hostile. More than 50 years of production have depleted the easy reserves, and what remains requires investment that the current regulatory framework discourages.⁶ OEUK, the UK's largest energy trade body, has launched job cuts following a strategic review. Impacted workers are set to be let go within weeks. The cuts at the industry's own lobby group signal the depth of the contraction. When the trade association is shrinking, the sector it represents is in structural decline.⁹ Australia's Santos offers a parallel perspective from the Southern Hemisphere. The company reported a 1.8% drop in first-quarter sales revenue, hit by a temporary outage at the Barossa offshore gas project and a severe tropical cyclone on the west coast. Santos's 2025 revenue was $4.94 billion, down 8.2% year on year, with earnings falling 33.2% to $818 million. The company is proceeding with the Agogo tie-in project in Papua New Guinea, where it holds a 39.9% stake in the PNG LNG venture.⁵ Santos's CEO warned that Australia's reputation as a stable destination for energy investment has been damaged by a proposal to impose a 25% gas-export tax. The warning echoes the UK experience: fiscal regimes that penalise production drive capital elsewhere. Norway's decision to reopen fields rather than tax them into closure is the contrasting approach.⁵ TotalEnergies is leading a different kind of expansion in Africa. The French supermajor's $20 billion Ugandan development, in which it owns a 26.5% stake, will be one of the largest foreign investments ever made on the continent. The company is about to restart a controversial gas project, betting that African hydrocarbons will find buyers in a world where Middle Eastern supply is disrupted and European demand is persistent.⁴ US LNG infrastructure is expanding in parallel. Cheniere's Sabine Pass and Corpus Christi facilities anchor the Gulf Coast export corridor. US power infrastructure earnings are strong, driven by AI-related load growth. The energy landscape is bifurcating: countries that invest in production are gaining market share from those that tax or regulate it away.^3,7 The signal to watch is whether ConocoPhillips hits the Q4 2028 timeline for the three Norwegian fields. If it does, the 5.7 million cubic metres per day arrives just as the global LNG market is expected to loosen. The fields could tip the European gas balance from tight to comfortable in a year when the Hormuz crisis may finally be resolved — or they could prove essential backup if it is not.²