Rough, the depleted gas field off the East Yorkshire coast that Centrica runs as a storage site, accounts for around half of Britain's gas storage capacity. Centrica has warned that it could close by April 2027 without a new support framework, and ministers have so far called it a commercial decision. The site is empty this winter, and National Gas has left it out of its supply figures. Here is what Rough does, why its future is uncertain and what losing it would change for the gas network.
Where the dispute stands in November 2026
Centrica says it is ready to invest £2 billion of its own money in Rough if government agrees a cap-and-floor arrangement, a regulated model that guarantees a minimum revenue in exchange for capping returns above a set level. On 14 October 2026, energy-pedia reported that a government minister had rejected calls for state support, saying Centrica could choose its own investments. Centrica's chief executive responded that Rough's future was too important to be treated as simply a commercial decision.
A day later, a further energy-pedia report said the UK had around 12 days of gas supply in storage, the lowest level in recent history, and that Unite had called for all options to be considered, including public ownership. The same report put the jobs at risk at about 100 at Rough itself and 350 in the supply chain, and gave the site's location as 18 miles offshore.
No deal had been announced at the time of writing. The position could change quickly, so check Centrica's and the Department for Energy Security and Net Zero's statements for the latest.
How a depleted field becomes a gas store
Rough was a producing gas field before it was converted. The engineering principle is simple: a porous sandstone reservoir that once held gas under a sealing cap rock can hold it again. In summer, when gas is cheap and demand is low, compressors inject gas from the onshore terminal through a subsea pipeline and wells into the reservoir. In winter the flow reverses and the gas is produced back to shore.
The detail is less simple. Injection and withdrawal rates depend on reservoir pressure, well performance and compression. The older a store, the more its wells, platforms and pipelines need inspection and repair. Centrica's £2 billion figure gives a sense of the investment it believes is needed to keep Rough running safely for the long term. That argument sits behind its request for a regulated return.
Long-range and medium-range storage
Britain's other stores are mostly salt caverns onshore, known as medium-range storage. Caverns can switch between injection and withdrawal quickly and deliver high flow rates for days or weeks, but they hold relatively little gas. A depleted field like Rough holds much more and can supply steadily over a long cold spell. The two types play different roles: caverns handle short peaks, while a large field store helps a country get through a long, cold winter or a prolonged supply outage.
What the winter numbers say without Rough
National Gas's Gas Winter Outlook 2026 confirms that its GB storage withdrawal figure of 113 mcm/d does not include Rough, because no gas was injected over the summer. Even so, it expects supply capability of 592 mcm/d against a 1-in-20 peak demand of 493 mcm/d, so peak day security is not at immediate risk this winter. We cover those figures in detail in our guide to the Gas Winter Outlook 2026/27.
Peak day capability is not the whole story, though. Storage matters for duration as well as rate. A system that can meet one very cold day comfortably may still come under pressure after several weeks of high demand, particularly if LNG cargoes are diverted to other markets or continental storage runs low. That is the scenario a large field store protects against, and it is the scenario most often raised by those arguing for Rough's retention.
Engineering questions if Rough closes
If Centrica does close the site, several technical issues follow:
- Decommissioning or mothballing. Plugging and abandoning wells, removing topsides and dealing with the export pipeline would follow the offshore decommissioning process under the Petroleum Act 1998. Our article on North Sea decommissioning in 2026 explains how pipelines are assessed for removal or leaving in place. Mothballing instead would keep options open but still carries inspection and maintenance costs.
- Cushion gas. Any storage reservoir holds a volume of gas that is never withdrawn, to maintain pressure. What happens to that gas on closure is a commercial and technical question.
- Network flows. Rough's winter flows enter the NTS on the east coast. Without them, other entry points and compressors carry more of the winter load.
- Future reuse. Unite has suggested Rough could later store hydrogen. Converting a natural gas store raises the same materials and integrity questions as repurposing gas pipelines for hydrogen, plus reservoir questions about mixing, microbial activity and gas purity. Once wells are abandoned, that option becomes much harder to recover.
The wider storage debate
Britain's storage is small relative to its demand, which is why 12 days of supply in store drew so much attention. The traditional argument has been that the UK relies on domestic production, Norwegian pipeline gas and LNG flexibility rather than large seasonal stocks. As UK Continental Shelf output declines, that argument is under strain, and the Rough dispute has become the focus of a broader question about who should pay for resilience.
For engineers, the useful takeaway is that security of supply depends on assets with long lives and specific technical limits. A store that closes and has its wells abandoned cannot simply be reopened when prices spike. Decisions taken in the next few months will shape the network's flexibility for decades.