What Is the EU Methane Regulation, and Who Does It Affect?

The EU Methane Regulation, which entered into force in 2024, sets out binding obligations for how operators must detect, measure, and report methane emissions from their networks. Whether you manage a transmission pipeline, a compressor station, or a distribution network, understanding what the regulation requires and when it applies is essential to staying compliant and avoiding operational risk.

What is the EU Methane Regulation and who does it apply to?

The EU Methane Regulation (EU) 2024/1787 is a binding piece of European legislation designed to reduce methane emissions across the energy sector. It applies to operators of oil, gas, and coal infrastructure within the European Union, as well as to importers who bring fossil energy into the EU market. For the gas sector specifically, the regulation targets Transmission System Operators (TSOs), distribution network operators, storage facility operators, and LNG terminal operators.

The regulation requires operators to move away from estimated emission factors and toward direct, source-level measurement of methane emissions. This is a fundamental shift in how methane accounting works. Rather than applying generic industry averages across a network, operators must identify and measure emissions at the level of individual components and assets. Importers face additional obligations: from January 2027, they must demonstrate that contracts concluded or renewed after 4 August 2024 cover only crude oil or natural gas subject to monitoring, reporting, and verification (MRV) mechanisms equivalent to EU standards.

What are the LDAR obligations for gas grid operators under the regulation?

Leak Detection and Repair (LDAR) programmes are at the heart of the EU Methane Regulation’s operational requirements. Every operator of underground pipelines and above-ground infrastructure must establish and maintain a formal LDAR plan. This covers not only buried pipelines but also compressor stations, metering and control stations, and storage facilities.

The key obligations under the LDAR framework include:

• Setting up an LDAR plan and conducting the first Type-2 LDAR survey, with the initial deadline set for August 2025
• Recording all identified leaks regardless of their size
• Retaining leak records for a minimum of 10 years
• Triggering a repair obligation when a leak exceeds the relevant threshold, which for Type-2 underground components under Article 14(8) is 1,000 ppm or 5 g/h

The detection sensitivity of the technology you choose directly affects how often you need to inspect. More sensitive technology qualifies for longer inspection intervals, which creates a practical incentive to invest in higher-performing systems. This is not just a technical consideration; it has real implications for the long-term cost of running a compliant pipeline inspection programme.

What’s the difference between Type 1 and Type 2 detection methods?

The EU Methane Regulation distinguishes between two levels of aerial inspection for underground infrastructure, broadly referred to as Type 1 and Type 2. The key differentiator is sensitivity.

1. Type 1 inspections use less sensitive detection methods and therefore require more frequent surveys to maintain an equivalent level of confidence in network integrity. Type 2 inspections meet a higher sensitivity threshold, set at 1,000 ppm or 5 g/h for underground components, and in return, operators using Type 2-certified technology can inspect underground pipelines once every three years rather than more frequently.
2. This two-tier framework is economically coherent with the regulation’s goals. A single-class framework fixed at a lower sensitivity level would remove the market incentive to develop and deploy better technology, effectively entrenching less capable systems. The two-class structure rewards operators and technology providers who invest in higher performance, which aligns directly with the regulation’s stated objective of reducing methane emissions across European gas networks.

It is also worth noting that reliable detection of underground leaks requires more than sensitivity alone. Research by METEC and the Engler-Bunte Institute shows that underground gas plumes widen before reaching the surface and do not always emerge directly above the leak. Effective detection therefore requires a measurement grid covering at least 10 metres on either side of the pipeline centerline, with a spatial resolution better than 2 metres. Technology that produces only a single line of measurement points along the pipeline cannot reliably detect real leaks under all conditions.

How does aerial methane detection help operators meet EU requirements?
Aerial methane detection offers a practical and efficient route to meeting the regulation’s LDAR and source-level reporting requirements, particularly for operators managing long-distance transmission pipelines across varied terrain. A helicopter-based system can cover large sections of network quickly, reducing the operational disruption associated with ground-based inspection methods.

For above-ground installations such as compressor stations and metering facilities, the regulation requires operators to perform two complementary measurements: first, identifying and quantifying individual emission sources at component level; and second, measuring total site emissions to verify that source-level estimates are complete. This dual approach, combining bottom-up source identification with top-down site measurement, is the basis of the OGMP 2.0 Level 5 “Gold Standard” that all EU assets must achieve by August 2028. When the two figures are compared, discrepancies reveal unaccounted emissions or miscalibrated source estimates, driving continuous improvement in data quality.

Until the forthcoming Implementing Act sets specific detection thresholds for aerial Stage 1 inspection, Article 14(7) of the regulation provides the interim legal standard: operators must use the best available technologies and the best available detection techniques, in compliance with manufacturer specifications. Third-party certification, such as DVGW G465-4-5 approval, currently satisfies this requirement and provides operators with a defensible compliance position while the Implementing Act is finalised.