From 1 January 2027 the EU Methane Regulation requires importers of oil and gas into the EU to show that new supply contracts are covered by methane monitoring, reporting and verification (MRV) equivalent to EU rules. The European Commission proposed on 14 October 2026 to push several importer deadlines back, but that change has to be formally adopted before 1 January to take effect. UK producers and pipeline operators are not EU importers, yet many sell gas into Europe, so the rules reach the UK Continental Shelf through contracts.
What applies from January 2027
Under the regulation as it stands, importers must show that contracts concluded or renewed after 4 August 2024 are subject to MRV measures equivalent to those that apply to EU producers. For older contracts, importers must make all reasonable efforts to secure equivalent MRV and report each year on the results. That requirement lands on the EU importer, but the evidence has to come from the producer, which is why UK operators who sell gas or oil into the EU are already being asked for methane data.
The CSIS analysis of the agreed text sets out two routes to equivalence. At producer level, MRV can be accepted as equivalent if the producer meets EU methane quantification standards or the Oil and Gas Methane Partnership (OGMP 2.0) Level 5 standard, with independent third-party verification. At country level, the Commission can recognise a producing country's rules as equivalent, but only if that country asks and provides evidence.
Later stages follow. Importers were due to start reporting methane intensity in 2028, and maximum methane intensity values for imported oil, gas and coal were due to apply from 2030.
The October 2026 postponement proposal
On 14 October 2026 the Commission proposed postponing Articles 28 and 29 of the regulation by one year. A summary by Global Environmental Law Review sets out the proposed dates:
- Importer MRV evidence: by 31 May 2029, covering 2028 supplies, instead of applying from 1 January 2027.
- Methane intensity reporting for importers and EU producers: 5 August 2029.
- Compliance with maximum methane intensity values: 5 August 2031.
The European Parliament adopted its position on 22 October 2026, with some later dates than the Commission. The postponement only works if the co-legislators agree and complete adoption before 1 January 2027, a compressed timetable. Until then, 1 January 2027 remains the date in law. Anyone with contracts that depend on this should check the final text rather than rely on the proposal.
Why this reaches British gas
Great Britain is physically linked to the continent by two gas pipelines. National Gas's Gas Winter Outlook 2026 gives their import capacity for this winter as 61 mcm/d through Interconnector and 22 mcm/d through BBL. In winter Britain tends to import through them, but flows reverse when British demand is low and continental buyers want gas. Any EU company importing that gas, or buying gas from the UK Continental Shelf under a contract signed after August 2024, needs to show equivalent MRV.
In practice, that means EU counterparties may ask UK producers and shippers for:
- A description of their methane measurement and reporting approach, and whether it meets OGMP 2.0 Level 5.
- Evidence of independent verification of reported emissions.
- Information about leak detection and repair surveys and the handling of venting and flaring.
- Contract clauses allocating responsibility if evidence is missing.
Commercial pressure from buyers can move faster than regulation. Even if the formal deadline slips, contracts signed now may carry methane data clauses that apply from 2027.
What OGMP 2.0 Level 5 means for pipeline and facility engineers
The Oil and Gas Methane Partnership describes OGMP 2.0 as a comprehensive, measurement-based reporting framework, and says that 69% of the emissions its member companies report are now based on measurement-based data. Level 5 is the top of its reporting scale. The precise requirements sit in the framework documents, which any operator aiming for equivalence should read in full, but the direction is clear: less reliance on generic estimates, more reliance on measured emissions that an independent verifier can check.
Measurement, not only calculation
Many inventories still rely on emission factors applied to equipment counts. Moving towards measurement means surveys with aircraft or drones, vehicle-mounted sensors or fixed site monitors, and a process for comparing those results with the bottom-up inventory. Where the two disagree, someone has to investigate and correct the records.
Leak detection and repair
Leak detection and repair programmes become central. On pipelines that means attention to valves, flanges, compressor seals, pig traps and above-ground installations. Pressure relief and blowdown events during maintenance are a known source of methane, so planning to recompress gas rather than vent it during pigging or isolations can make a measurable difference.
Data that stands up to verification
Independent verification needs traceable data. Operators already running integrity data platforms are better placed, because the same asset registers, inspection records and sensor data can support emissions reporting. Our article on digital twins and in-line inspection covers how that data is being brought together.
Links with other changes in 2027
Methane rules are one of several carbon measures arriving around the same time. The UK's own carbon border mechanism starts on 1 January 2027 for hydrogen, iron and steel and other sectors, which we explain in our guide to UK CBAM and line pipe imports. Developers of new hydrogen and CO2 networks, such as those described in our article on repurposing gas pipelines for hydrogen, will also be designing assets whose leakage performance is under closer scrutiny than ever.
A sensible approach for UK operators
Until the EU finalises the postponement, the cautious course is to assume buyers will ask for evidence from early 2027 and that methane intensity will matter commercially before it matters legally. Mapping which sales contracts involve EU importers, checking the current OGMP reporting level, and scheduling measurement campaigns for the main sites are all low-regret steps. Regulatory and legal advisers should be consulted on any specific contract, as the final rules and dates may change.