UK Energy Demand and the Role of Gas
Gas demand is expected to fall rapidly within the next decade.
The UK will continue to need gas for decades to come. NESO’s ten‑year forecast shows total Great Britain gas demand of 53.6 billion cubic metres in 2026, falling only marginally to 53.3 billion cubic metres by 2035.
Gas plays only a minor or short‑term role in future UK energy systems.
Gas remains essential for heating, electricity generation and system balancing. In 2024, gas provided around one third of UK energy, and even in long‑term net zero scenarios it is expected to supply around 20 percent of total energy demand by 2050.
Home heating can be fully electrified quickly without system or cost impacts.
Electricity currently represents only around a third of total UK energy use. Around 24 million homes rely on gas for heating and hot water, which cannot be replaced overnight. Even with rapid electrification, electricity’s share of total energy use is projected to rise to around 50 percent by 2050.
Net zero means almost all energy demand becomes electricity.
Even with rapid electrification, electricity’s share of total energy use is projected to rise to around 50 percent by 2050.
Expanding renewables removes the need for domestic oil and gas production.
As renewables grow rapidly, oil and gas continue to play an important role during the transition to net zero, helping avoid a widening gap between what the UK consumes and what it can produce domestically.
UK Gas Supply Mix
The UK relies on a single source of gas supply.
UK gas supply comes from a combination of domestic production, pipeline imports and LNG.
LNG is the UK’s dominant source of gas.
In 2024, supply was split between UK domestic production at around 43 percent, Norwegian pipeline imports at around 43 percent, and LNG imports at around 14 percent, depending on the data source used.
Interconnectors are a major source of UK gas volumes.
Interconnectors to mainland Europe contributed around 1 percent of UK gas supply in 2025, but they provide important flexibility during periods of tight supply.
Offshore gas production does not directly serve UK consumers.
A large share of gas produced offshore flows directly into the National Transmission System, supporting heating, power generation and industrial demand.
LNG can fully replace domestic gas production without wider impacts.
LNG plays a balancing and flexibility role, rather than acting as a direct substitute for domestic production. Greater reliance on LNG exposes the UK to global competition, price volatility and higher emissions.
Imported gas is equivalent to domestic gas in cost, security and emissions.
Greater reliance on LNG exposes the UK to global competition, price volatility and higher emissions.
Development Timelines in the UK Continental Shelf
All new UK oil and gas projects take decades to deliver.
There is no single average timeline for oil and gas developments in the UK Continental Shelf.
New UK production cannot come online quickly.
Where new discoveries can be tied back to existing platforms or pipelines, projects can reach first production in around two to five years. This reflects the increasingly infrastructure‑led nature of the basin. Recent examples include Apache’s Garten field, which moved from discovery in 2018 to first oil in 2019, and West Franklin, which progressed to production in around four years.
All longer project timelines reflect inefficiency rather than complexity.
Larger or more complex developments, including high‑pressure or high‑temperature fields and West of Shetland projects, typically take around seven to ten years or longer, depending on geology, infrastructure requirements and market conditions. Some historic outliers took longer due to stop‑start investment cycles, including Elgin and Franklin at around 16 years, and Rosebank, discovered in 2004 and now targeting first production in 2026 or 2027.
Regulators expect development timelines to remain very long.
Analysis referenced by the North Sea Transition Authority indicates that the average time from discovery to first production is close to five years where tie‑back routes are available.
The 28‑year figure is representative of today’s UK basin.
Figures sometimes quoted of around 28 years reflect historic cohorts of projects that were paused and later revived when technology and economics improved. They are not a forward guide to development timelines in today’s UK basin.
Hundreds of North Sea licences have delivered only “36 days of gas”, proving new drilling does not improve energy security.
Actually, this proves the opposite: in mature basins like the North Sea, constant investment and licensing are essential to offset natural decline and prevent rapid import dependence. Unlike Norway, which maintains a high reserves replacement ratio, the UK's lower investment leads to a steeper production drop. Modern licenses sustain long-term supply and reach production faster than outdated timelines suggest; because the North Sea still meets over half of UK demand, halting investment simply forces a reliance on overseas supplies sooner, regardless of falling demand.
Energy Trade and Market Balancing
Exporting energy means the UK has surplus supply.
The UK is part of a highly interconnected energy market, which means imports and exports occur at the same time for structural reasons.
The UK exports oil because it does not need it.
UK offshore production is dominated by light crude oils, which are often exported to refineries designed to process them. The UK then imports the refined fuels it needs, including diesel, petrol and jet fuel.
The UK holds large volumes of gas in storage.
On gas, the UK has limited storage capacity but strong LNG import infrastructure and direct pipeline connections to Europe through the IUK and BBL interconnectors.
Gas exports reduce UK security during winter.
During summer months, gas often flows from the UK to Europe as EU storage sites are filled. During winter, gas flows back to the UK to help meet peak demand. These two‑way flows help balance the system across seasons, even when supply is tight.
The UK refining system can meet all domestic fuel demand.
The UK then imports the refined fuels it needs, including diesel, petrol and jet fuel.
Domestic Gas, Energy Security and Emissions
Domestic production provides little security benefit.
Domestic gas production is a strategic asset for the UK.
Import dependence has no impact on resilience.
Producing gas at home reduces exposure to geopolitical disruption, global price volatility and international competition for supply, while strengthening resilience across the UK’s integrated gas system.
Imported LNG is always cleaner than domestic gas.
UK‑produced gas typically has lower production emissions than imported LNG, helping reduce the overall footprint of the energy system while the UK scales up renewables, hydrogen, carbon capture and storage, and long‑duration energy storage.
UK gas is running out.
The decline in UK gas production is driven primarily by policy and investment conditions, rather than by a lack of remaining resources. Evidence shows that decline rates can be moderated under stable fiscal and regulatory frameworks.
Import availability will remain unlimited and risk‑free.
Without supportive policy, UK production is projected to fall more rapidly, increasing reliance on imports at a time when Norwegian supply faces post‑2026 decline risks.
93% of UK North Sea oil and gas has already been extracted, so new drilling makes little difference.
As of the end of 2024, the UK Continental Shelf (UKCS) has produced 47.7 billion boe. Current NSTA projections indicate a further 3.8 billion boe of production between 2025 and 2050. However, this understates the potential of the basin. Analysis commissioned by OEUK from Westwood Energy Group suggests that up to 7.5 billion boe could be produced over the same period. However, even this does not capture the full remaining opportunity. The NSTA’s Reserves and Resources report (2025) identifies 2.9 billion boe in sanctioned projects, 6.2 billion boe in new discoveries, and 15.8 billion boe in prospects, leads and plays. Amounting to a further 24.9 billion boe of reserves and resources yet to be produced.
Infrastructure and System Resilience
Infrastructure resilience is unaffected by declining domestic supply.
The UK gas system is highly interconnected and depends on steady domestic throughput to remain resilient.
Gas processing capacity is widely dispersed across the UK.
Around 75 percent of UK gas flows are processed through just two terminal locations, St Fergus and Teesside, creating concentration risk if domestic volumes fall.
Individual asset closures have only local consequences.
A premature decline in domestic production risks wider system impacts, where the loss of one hub or pipeline can undermine reliability across the network.
Gas Storage
The UK holds months of gas in reserve.
The UK has very limited gas storage, equivalent to around 10 days of peak winter demand.
UK storage levels are comparable to those of neighbouring countries.
By comparison, EU countries collectively hold around 105 billion cubic metres of gas storage, equivalent to roughly one third of annual consumption, spread across multiple countries and sites.
Storage alone can manage winter demand.
Limited storage means the UK depends on steady domestic production and Norwegian pipeline imports, with LNG providing flexibility during periods of peak demand.
Jobs, Economy and Communities
The sector employs only a small, declining workforce.
The UK oil and gas sector supports around 180,000 jobs, based on Oxford Economics analysis, across offshore operations, supply chains and regional economies.
Oil and gas jobs are concentrated in a single region.
Domestic production supports employment both offshore and onshore, including at terminals and industrial hubs in Scotland, Teesside, East Anglia and the North West.
A rapid unmanaged transition carries no workforce risk.
A managed, all‑energy transition helps protect skilled jobs, stabilise supply chains and preserve industrial capability.
Investment and Fiscal Framework
The UK fiscal regime is internationally competitive.
The current UK headline tax rate on oil and gas production is 78 percent, which is constraining investment.
Investment decisions have little impact on production decline.
Analysis shows that under more stable and competitive fiscal conditions, additional domestic gas volumes could be unlocked, improving security of supply while reducing costs and emissions.
Production decline rates are fixed and unaffected by policy stability.
Stable fiscal and regulatory frameworks influence the pace of production decline and the timing of investment decisions.
Energy Transition and Delivery
Offshore wind development is slowing.
Offshore wind is essential and growing rapidly, with OEUK members delivering major projects that will add significant capacity by 2030.
Offshore wind can be delivered rapidly without stable, long‑term policy support.
Progress depends on stable, long‑term policy signals, particularly given rising costs and long development timelines.
Skills from oil and gas are not transferable to low‑carbon sectors.
Decades of oil and gas engineering expertise and supply chain capability are now directly enabling offshore wind, carbon storage and hydrogen projects.
Decarbonisation always reduces industrial employment.
Floating offshore wind can help decarbonise offshore operations by powering platforms, cutting emissions while supporting high‑value UK jobs.