The EU Methane Regulation (2024/1787): LDAR and reporting duties for energy operators

Since 4 August 2024, Regulation (EU) 2024/1787 has been in force. It sets the first Union-wide rules on methane emissions from the energy sector: oil, gas, coal, and, from 1 January 2027, the importers of those fuels.

For an oil or gas operator, two obligations frame everything else: a leak detection and repair programme (LDAR) and quantified reporting of methane emissions. The clock is already running. The LDAR programme was due by 5 May 2025, the first source-level report by 5 February 2026, and the site-level report by 5 February 2027.

What Regulation (EU) 2024/1787 covers

The regulation governs methane emissions across the energy chain: production and transport of oil and gas, storage, liquefied natural gas, and coal mining. Methane has a high short-term warming effect, and diffuse leaks spread across installations account for a large share of it. The text requires you to look for those leaks actively, fix them, and prove you have done so.

Three operational pillars follow: measure and quantify emissions, detect and repair leaks (LDAR), and report the results to the competent authority. The first pillar is what puts your field teams to work on site, because it turns a paper obligation into regular inspection campaigns. Routine venting and flaring are restricted in parallel, and where flaring is permitted the flare has to reach at least 99% destruction and removal efficiency.

The reference text is published on EUR-Lex: Regulation (EU) 2024/1787.

Who is affected

The rules apply to operators of oil and gas installations in the Union: production, gathering, processing, transmission, distribution and underground storage, along with LNG terminals. Coal mine operators are also in scope, with their own set of rules. Operating mines measure and report ventilation and drainage emissions, and even closed or abandoned underground mines fall under measurement obligations from 5 May 2026.

From 1 January 2027, the regulation extends measurement, reporting and verification (MRV) obligations to importers placing oil, gas and coal on the Union market. An importer will have to document how methane emissions are tracked at its non-Union suppliers, and show that contracts signed or renewed after entry into force carry MRV measures equivalent to the EU rules. This changes the nature of supply contracts, because methane data becomes a clause to demand upstream. An Irish gas importer sourcing from outside the EU, for example, will need that supplier data on file rather than assembling it after the fact.

The LDAR programme: what you do on site

LDAR (leak detection and repair) is the operational core of the regulation for oil and gas. Each operator of an existing site had to submit its LDAR programme to the competent authority by 5 May 2025. The programme describes the components under survey (valves, flanges, connectors, seals, compressors and other potential leak points), the detection method, and the frequency of campaigns.

The regulation distinguishes two types of survey, with different detection thresholds:

• Type 1: a threshold of 7,000 ppm. Less sensitive surveys, run at a higher frequency to catch large leaks and super-emitter events.
• Type 2: a threshold of 500 ppm. More sensitive surveys, able to detect smaller leaks before they grow.

For existing sites, the first Type 2 survey was due by 5 August 2025. The frequency of later campaigns is set out in Annex I and runs over several years depending on the component and the type of site. It is not uniform, and it falls to the operator to keep the schedule component by component. On top of the campaigns themselves, operators have to send the competent authority an annual report summarising every LDAR survey completed in the previous year, together with their repair and monitoring schedules.

Repair deadlines

When a leak is detected, the counter starts. The regulation sets short deadlines:

1. A first repair or a temporary fix must happen within 5 days of detection.
2. The full repair must be completed within 30 days.

If the repair requires a plant shutdown or parts that are not available, the delay has to be justified and documented, not simply noted. Each detected leak then becomes a traceable record with a detection date, an intervention date, a concentration measurement, and proof of repair.

Keeping the records

LDAR records (detections, measurements, repairs) must be kept for 10 years and made available to the competent authority on request. This is a substantive requirement, not a formality. A reading with no date, no component location and no follow-up is worth nothing on the day of an inspection. The measured concentration, the component identifier, the GPS position and the timestamp form the verifiable minimum.

The emissions reports: the timeline

Beyond LDAR, the regulation requires quantified reports in successive stages, each more detailed than the last.

• 5 February 2026: source-level reporting. You report estimated emissions by source category.
• 5 February 2027: site-level reporting, with measured quantification and reconciliation between the source estimates and site measurements.

These reports are checked by an independent verifier, who issues a statement on whether they conform to the regulation. Moving from source level to site level is demanding: it assumes real measurements on the installations, not only theoretical emission factors. The data gathered during your LDAR campaigns feeds these reports directly, which argues for structured recording from the very first campaign rather than reconstruction after the fact.

The deadlines at a glance

1. 5 May 2025: LDAR programme submitted to the competent authority.
2. 5 August 2025: first Type 2 survey campaign.
3. 5 February 2026: source-level emissions report.
4. 1 January 2027: MRV obligations for importers take effect.
5. 5 February 2027: site-level emissions report.
6. 5 August 2030: the maximum methane intensity value applies.

These dates are set by the regulation itself. The exact submission arrangements (formats, portal, receiving authority) are defined at national level, so each operator should confirm the applicable filing channel with its competent authority. In Ireland, the energy regulator is the Commission for Regulation of Utilities; in other Member States the receiving authority differs, and the contact point should be checked rather than assumed.

Penalties

The regulation provides for penalties set by each Member State, and they are meant to bite. Fines can reach up to 20% of annual turnover for the most serious breaches. Beyond the amount, the real exposure is proof. An authority that asks for ten years of LDAR history expects complete, dated records, not a declaration of good faith. A programme that looks tidy on paper but lacks usable field records carries the same risk as no programme at all.

How to prepare

The hard part is not understanding the regulation. It is producing and keeping the data Annex I requires, campaign after campaign, on sites that are often remote and without a network signal. A few concrete points to frame the preparation:

• Map the components under survey per site and their inspection frequency under Annex I.
• Standardise the survey form: component identifier, campaign type (1 or 2), measured concentration in ppm, GPS position, timestamp, photo.
• Set up repair tracking with the 5-day and 30-day counters, and the justification for any delays.
• Prepare the aggregation of readings into the source-level report (2026) and then the site-level report (2027).
• Organise 10-year archiving that stays accessible during an inspection.

One point deserves attention on frequency: Annex I sets it across several years and varies it by component and site type. A single inspection calendar for an entire estate will not be enough. You need a verifiable schedule per component, and a way to prove the survey happened when the schedule said it would.

This is exactly the work that a structured field-capture tool such as FormRift makes manageable. Your field teams record each reading on mobile (concentration, component, GPS position, photo, timestamp), even offline on sites without coverage, and the data syncs as soon as the network returns. Every entry feeds a complete audit trail: the traceability the competent authority expects on the day of an inspection, across ten years of history. That is the use we describe for the energy sector, built on the features of standardised capture, secure storage and real-time visibility, the simplicity, audit trail and security that turn inspections, audits and reports into records that hold up.

Regulation (EU) 2024/1787 does not only ask you to look for leaks. It asks you to prove that you look for them, that you repair them, and that you keep a trace of everything.