Regulation (EU) 2024/1787 of the European Parliament and of the Council of 13 June 2024 on the reduction of methane emissions in the energy sector and amending Regulation (EU) 2019/942 (Text with EEA relevance)

The measurements and quantifications referred to in this Article shall be carried out in accordance with the standards and technical prescriptions, as applicable, established under Article 32. Until the date of application of those standards or technical prescriptions, operators and undertakings shall follow state-of-the-art industry practices and use the best technologies available for the measurement and quantification of methane emissions. In that context, operators and undertakings established in the Union may use the latest OGMP 2.0 technical guidance documents approved by 4 August 2024 for such purposes.

Operators and undertakings established in the Union shall compare source-level quantification of methane emissions and site-level measurement of methane emissions. If there are statistically significant discrepancies between the source-level quantification and the site-level measurement of methane emissions, operators and undertakings shall:

Where information is confidential in accordance with Directive (EU) 2016/943 of the European Parliament and of the Council (24), the operators or undertakings concerned shall indicate in the report the type of information that is withheld and the reasons therefor.

The competent authorities shall make the reports referred to in this Article available to the public and the Commission in accordance with Article 5(4), within 3 months from their submission by the relevant operators or undertakings.

By 5 May 2025 for existing sites and within 6 months from the date of start of operations for new sites, operators shall submit a leak detection and repair programme (‘LDAR programme’) to the competent authorities.

Operators shall initiate the first type 2 LDAR survey of all components under their responsibility in accordance with the LDAR programme as soon as possible from 4 August 2024.

Without prejudice to the obligation to carry out type 2 LDAR surveys in accordance with this Article, when a type 1 LDAR survey is required, operators may choose to carry out a type 2 LDAR survey instead of a type 1 LDAR survey.

As part of the LDAR surveys, operators may use advanced detection technologies, provided that:

By way of derogation from the fourth subparagraph of paragraph 2 of this Article, where operators that produce or process oil or natural gas provide evidence, on the basis of measurements from the 5 preceding years which have been reported by the operators in accordance with Article 12 and assessed by a verifier, that less than 1 % of all their components and subcomponents in each site are leaking and that the aggregated methane emissions associated with those leaks represent less than 0,08 % of the total volume of gas or 0,015 % of the total mass of oil processed or extracted, different LDAR survey frequencies for components at sites where no leaks were identified may be applied, subject to the approval of the competent authorities and provided that:

The LDAR surveys shall be carried out with detection devices that allow to identify leaks as follows, for each type of component:

By 5 August 2025, the Commission shall, by means of an implementing act, specify:

Operators shall repair or replace all components found to be emitting methane at or above the following levels at standard temperature and pressure and using detection devices in accordance with the manufacturer specifications for operation and maintenance:

The repair or replacement of the components referred to in paragraph 8 shall take place immediately after detection. If the repair cannot be carried out immediately after detection, it shall be attempted as soon as possible and no later than 5 days after detection and shall be completed within 30 days after detection.

Where one or more of the conditions set out in paragraph 9, sixth subparagraph, points (a) to (e), apply and a shutdown is required before the repair or replacement can be undertaken, operators shall minimise the leak within 24 hours of detection and shall repair the leak by the end of the next scheduled shutdown or within a year, whichever is sooner, unless carrying out an earlier repair could reasonably be expected to lead to a situation whereby the amount of methane vented during repair operations would very likely be significantly higher than the amount of methane that would leak in the absence of a repair, or unless carrying out an earlier repair could reasonably be expected to lead to security of supply issues in small connected systems as defined in Directive (EU) 2019/944.

Operators shall establish without delay, keep updated and make fully available to the competent authorities a record of all decisions to delay repair pursuant to this Article, including all necessary evidence justifying each decision and the corresponding repair and monitoring schedules.

Notwithstanding paragraph 2, operators shall survey components that were found to be emitting:

Without prejudice to the reporting obligations pursuant to paragraph 14, operators shall record all identified leaks, irrespective of their size, and shall regularly survey them and ensure that they are repaired in accordance with paragraph 9.

Every year, operators shall submit all repair and monitoring schedules and a report summarising the results of all LDAR surveys completed during the previous year to the competent authorities of the Member State where the relevant assets are located.

Operators may delegate any of the tasks set out in this Article. Delegated tasks shall not affect the responsibility of operators and shall not impact the effectiveness of supervision by the competent authorities.

Member States shall ensure that certification, accreditation schemes or equivalent qualification schemes, including suitable training programmes, are available to LDAR service providers and to operators with respect to the LDAR surveys.

Without prejudice to Directives 2008/56/EC (26) and 2013/30/EU (27) of the European Parliament and of the Council, the competent authorities may decide to exempt offshore oil and gas components located in their territory at a water depth greater than 700 metres from the requirements under this Article if the operator concerned can provide robust evidence that the impact on the climate of potential methane emissions from those components is highly likely to be negligible.

Venting shall be prohibited except in the circumstances provided for in this Article. Routine flaring shall be prohibited.

Venting or flaring shall be allowed only in case of an emergency or malfunction.

Notwithstanding paragraph 2, venting or flaring shall be allowed where unavoidable and strictly necessary and subject to the reporting obligations set out in Article 16.

Where venting is allowed pursuant to paragraphs 2 and 3, operators shall vent only where flaring is not technically feasible due to lack of flammability or inability to sustain a flame, risks endangering safety of operations or personnel or where it would have a worse environmental impact in terms of emissions. In such a situation, as part of the reporting obligations set out in Article 16, operators shall notify and provide evidence to the competent authorities of the necessity to use venting instead of flaring.

Equipment that vents shall be replaced by non-emitting alternatives where those are commercially available and if they meet the standards or technical prescriptions for components designed to vent established under Article 32.

In addition to the conditions set out in paragraphs 2 and 3, flaring shall be allowed only where either re-injection, utilisation on-site, storage for later use or dispatch of methane to a market are not feasible for reasons other than economic considerations. In such a situation, as part of the reporting obligations set out in Article 16, operators shall demonstrate to the competent authorities the necessity to use flaring instead of either re-injection, utilisation on-site, storage for later use or dispatch of methane to a market.

Where a site is built, replaced or refurbished in whole, operators shall install and use only commercially available zero-emitting pneumatic devices, compressors, atmospheric pressure storage tanks, sampling and measuring devices and dry gas seals. Where a site is replaced or refurbished in part, operators shall install and use in that part only commercially available zero-emitting pneumatic devices, compressors, atmospheric pressure storage tanks, sampling and measuring devices and dry gas seals.

Operators shall comply with this Article without delay and, in any case, not later than 5 February 2026 for existing sites and not later than 12 months from the date of start of operations for new sites. Where operators are unable to comply with this Article due to exceptional delay caused by the need to obtain a permit or any other administrative authorisation from the relevant authorities or the unavailability of venting or flaring equipment, they shall provide the competent authorities with a detailed implementation schedule. That schedule shall include sufficient evidence of the fulfilment of the conditions laid down in this paragraph. The competent authorities may require modifications to that schedule.

Operators shall notify the competent authorities of venting events and flaring events:

Operators shall submit to the competent authorities annual reports on all venting events and flaring events, referred to in paragraph 1 of this Article and in Article 15, in accordance with the elements set out in Annex III and as part of the relevant report referred to in Article 12.

Where a site is built, replaced or refurbished in whole or in part, or where new flare stacks or other combustion devices are installed, operators shall install only flare stacks or combustion devices with an auto-igniter or continuous pilot burner and with a destruction and removal efficiency by design level of at least 99 %.

Operators shall ensure that all flare stacks or other combustion devices comply with the requirements of paragraph 1 by 5 February 2026.

Operators shall inspect flare stacks or other combustion devices every 15 days in accordance with Annex IV, except where they are not used on a regular basis. Where flare stacks or other combustion devices are not used on a regular basis, operators shall inspect them before each use.

Where auto-igniters or continuous pilot burners are used, operators shall use flame supervision equipment to constantly monitor the main flare flame or the pilot flame to ensure that venting does not occur due to a flame-out condition.

By 5 August 2025, Member States shall establish and make publicly available an inventory of all inactive wells, temporarily plugged wells and permanently plugged and abandoned wells on their territory or under their jurisdiction that are recorded or where information or evidence on their location is available or where their location can be identified with all reasonable efforts. That inventory shall include at least the elements set out in Part 1 of Annex V.

By way of derogation from paragraph 1, Member States that notify to the Commission evidence of the existence on their territory or under their jurisdiction of 40 000 or more recorded inactive wells, temporarily plugged wells and permanently plugged and abandoned wells combined may adopt a plan for completing the inventory referred to in paragraph 1 and the quantification of methane emissions or the demonstration that there are no methane emissions, as applicable, in relation to those wells, including at least the elements set out in Part 1 of Annex V, and make it publicly available, provided that:

Without prejudice to paragraph 4, reports containing information on quantification of methane emissions and, where pressure monitoring equipment exists, information on pressure monitoring from all inactive wells and temporarily plugged wells shall be submitted to the competent authorities by 5 May 2026 and by 31 May every year thereafter.

Where the competent authorities are provided with quantification of methane emissions and, where pressure monitoring equipment exists, pressure monitoring data that prove that there have been no methane emissions from an onshore temporarily plugged well during the last 5 years, paragraph 3 shall cease to apply to that well.

Where the competent authorities are provided with reliable evidence of material amounts of methane emissions in an offshore inactive well or in a temporarily plugged well after the period referred to in paragraph 4, or in a permanently plugged and abandoned well and where that evidence has been confirmed by an independent third party, the competent authorities shall decide on the application to that well of the obligations set out in this Article in relation to temporarily plugged wells.

Where methane emissions are detected in inactive wells, temporarily plugged wells or permanently plugged and abandoned wells, Member States or the party responsible pursuant to paragraph 8 shall take all the necessary measures available to them for remediating, reclaiming and permanently plugging that well, as applicable, where technically feasible and taking into account the environmental impact of the necessary works in view of the associated reduction of the methane emissions.

Before submission to the competent authorities, the reports referred to in paragraph 3 of this Article shall be assessed by a verifier and shall include a verification statement issued in accordance with Article 8.

Member States shall ensure that operators fulfil the obligations laid down in paragraphs 3 to 7 and paragraph 9. Where an operator, owner, licensee or a party otherwise responsible for the well under national law provides to the competent authority adequate and reliable evidence to demonstrate that it does not have the adequate financial means to fulfil those obligations or where the party responsible cannot be identified, the Member State shall bear responsibility for those obligations.

By 5 August 2026, Member States or the party responsible pursuant to paragraph 8, shall prepare a mitigation plan to remediate, reclaim and permanently plug inactive wells and temporarily plugged wells including at least the elements set out in Part 2 of Annex V, and implement it within 12 months from the submission of the first report referred to in paragraph 3.

The competent authorities shall review and make the reports and mitigation plans referred to in this Article available to the public and the Commission in accordance with Article 5(4), within 3 months from their submission by an operator or the completion of a mitigation plan by a Member State.

Without prejudice to Directives 2008/56/EC and 2013/30/EU, the competent authorities may decide to exempt offshore oil and gas wells located at a water depth greater than 700 metres from the requirements under paragraph 3 or 9 of this Article, if robust evidence can be provided that the impact on the climate of potential methane emissions from those wells is highly likely to be negligible.

Without prejudice to Directives 2008/56/EC and 2013/30/EU, and subject to the approval of the competent authorities, offshore temporarily plugged wells and permanently plugged and abandoned wells located at water depth between 200 and 700 metres may be exempted from the requirements under paragraph 3 or 9 of this Article, where the operator can demonstrate that the impact on the climate of potential methane emissions from those wells is highly likely to be negligible by a reference to an environmental impact assessment conducted before drilling or after accidents during operations.

This Section applies to active underground and surface coal mines.

Methane emissions resulting from active underground coal mines include the following emissions:

Methane emissions resulting from active surface coal mines include the following emissions:

For underground coal mines, mine operators shall take continuous source-level direct measurements and quantification on all exhaust ventilation shafts. Mine operators shall report to the competent authorities methane emissions per ventilation shaft per year in kilotonne of methane, using equipment and methodologies resulting in a measurement accuracy with a tolerance of 0,5 kilotonne of methane per year or of 5 % of the reported amount, whichever value is lower.

Drainage station operators shall take continuous source-level direct measurements and quantification of total releases of vented and flared methane, regardless of the reasons for such venting and flaring.

For surface coal mines, mine operators shall use deposit-specific coal mine methane emission factors to quantify methane emissions resulting from mining operations. Mine operators shall establish those emission factors on a quarterly basis, in accordance with appropriate scientific standards and taking into account methane emissions from surrounding strata.

The measurements and quantification referred to in paragraphs 1, 2 and 3 shall be undertaken in accordance with the applicable standards or technical prescriptions established pursuant to Article 32. Until the date of application of those standards or technical prescriptions, mine operators shall follow state-of-the-art industry practices and use the best available technologies for the measurement and quantification of methane emissions. Mine operators shall provide competent authorities and verifiers with information on the standards, including international standards, or methodologies used.

Where relevant, mine operators shall estimate coal post-mining methane emissions using coal post-mining emission factors, updated annually, based on deposit-specific coal samples and in accordance with appropriate scientific standards.

By 5 August 2025 and by 31 May every year thereafter, mine operators and drainage station operators shall submit a report to the competent authorities containing data on yearly source-level methane emissions in accordance with this Article.

The competent authorities shall make the reports referred to in this Article available to the public and the Commission in accordance with Article 5(4), within 3 months from submission by mine operators.

Flaring with a destruction and removal efficiency by design level below 99 % and venting of methane from drainage systems shall be prohibited from 1 January 2025, except in the case of an emergency or a malfunction, or where unavoidable and strictly necessary for maintenance and except venting in accordance with paragraph 2. In such cases, drainage station operators shall vent only if flaring is not technically feasible or risks endangering safety of operations or personnel. In such a situation, as part of the reporting obligations set out in Article 23, drainage station operators shall demonstrate to the competent authorities the necessity of venting instead of flaring.

Venting of methane through ventilation shafts in coal mines emitting more than 5 tonnes of methane per kilotonne of coal mined, other than coking coal mines, shall be prohibited from 1 January 2027, except in the case of an emergency.

By 5 August 2027, the Commission shall adopt a delegated act in accordance with Article 34 to supplement this Regulation by setting out restrictions on venting methane from ventilation shafts for coking coal mines.

Without prejudice to Articles 107 and 108 of the Treaty on the Functioning of the European Union (TFEU), Member States may use a system of incentives to reduce methane emissions based on fees, charges or penalties, as referred to in Article 33, in order to ensure that operators of existing coal mines comply with the obligations, set out in paragraphs 1 and 2 of this Article.

From 1 January 2025, drainage station operators shall notify the competent authorities of all venting events and all flaring events with a destruction and removal efficiency by design level below 99 %:

The competent authorities shall make the information submitted to them pursuant to this Article available to the public and the Commission on an annual basis in accordance with Article 5(4).

By 5 August 2025, Member States shall set up and make publicly available an inventory of all closed underground coal mines and abandoned underground coal mines in their territory or under their jurisdiction where operations ceased after 3 August 1954, in accordance with the methodology and including at least the elements set out in Part 1 of Annex VIII.

From 5 May 2026, methane emissions shall be measured in all closed underground coal mines and abandoned underground coal mines where operations ceased after 3 August 1954.

If the observed annual methane emissions from an element listed in Part 1, point 1.5, of Annex VIII is below 1 tonne of methane for 6 consecutive years in the case of flooded underground coal mines or 12 consecutive years in the case of non-flooded underground coal mines, no further monitoring and reporting shall be taken for that specific element.

Upon request from the responsible party, competent authorities may exempt closed underground coal mines and abandoned underground coal mines from the requirements of paragraphs 2 and 3 of this Article and Part 1, point 1.5, of Annex VIII where the responsible party demonstrates that those mines have been fully flooded for at least 10 years prior to the date of the request.

Where the competent authorities receive reliable evidence of material amounts of methane emissions from a closed underground coal mine or abandoned underground coal mine as referred to in paragraph 4, the obligations set out in paragraphs 2 and 3 shall apply to that coal mine.

Reports containing estimates of yearly source-level methane emissions data shall be submitted to the competent authorities by 5 August 2026 and by 31 May every year thereafter.

Mine operators or Member States shall be responsible for the compliance with the requirements referred to in paragraphs 2 to 6 of this Article as regards closed underground coal mines. Member States shall be responsible for the compliance with the requirements referred to in paragraphs 2 to 6 of this Article as regards abandoned underground coal mines. In the case of alternative uses of abandoned underground coal mines, the permit holder referred to in Article 26(3) shall be responsible for the compliance with the requirements referred to in paragraphs 2, 3 and 6 of this Article.

The competent authorities shall make the reports referred to in this Article available to the public and the Commission, in accordance with Article 5(4), within 3 months from submission by the party responsible.

On the basis of the inventory referred to in Article 25, Member States shall develop and implement a mitigation plan to address methane emissions from closed underground coal mines and abandoned underground coal mines where operations ceased after 3 August 1954.

Venting and flaring from equipment referred to in Article 25(2) shall be prohibited from 1 January 2030, unless utilisation of methane or reduction of methane emissions is not technically feasible or risks endangering environmental safety, human safety, including that of the personnel, or health. In such a situation, as part of the reporting obligations set out in Article 25, mine operators or Member States shall demonstrate the necessity of venting or flaring instead of utilisation of methane or reduction of methane emissions.

Alternative use of abandoned underground coal mines shall be allowed following a permitting procedure adapted to the specific type of alternative use of the abandoned underground coal mine. The applicant shall provide to the competent authorities a detailed plan of measures to avoid methane emissions. The permit holder shall comply with the monitoring, reporting and mitigation obligations under Article 25 and this Article.

Without prejudice to the applicable sector-specific Union law, for closed underground coal mines, existing best mitigation practices to reduce methane emissions shall be allowed.

By 5 May 2025 and by 31 May every year thereafter, importers shall provide the information set out in Annex IX to the competent authorities of the Member State in which they are established. Where importers fail to provide that information, in whole or in part, they shall provide sound justification to those competent authorities for such failure and set out the actions that they have undertaken to obtain that information.

By 5 August 2025 and by 31 August every year thereafter, Member States shall submit to the Commission the information provided by importers.

From 1 January 2027, importers shall demonstrate, and report in accordance with Article 27(1), to the competent authorities of the Member State in which they are established that the contracts concluded or renewed on or after 4 August 2024 for the supply of crude oil, natural gas or coal produced outside the Union cover only crude oil, natural gas or coal that is subject to monitoring, reporting and verification measures applied at the level of the producer that are equivalent to those set out in this Regulation.

For contracts concluded before 4 August 2024 for the supply of crude oil, natural gas or coal produced outside the Union, importers shall undertake all reasonable efforts to require that crude oil, natural gas or coal is subject to monitoring, reporting and verification measures applied at the level of the producer that are equivalent to those set out in this Regulation. Those efforts may include the amendment of those contracts.

The Commission shall issue recommendations containing optional model clauses related to the information to be provided for the purposes of paragraphs 1 and 2, to be used by importers placing crude oil, natural gas and coal on the Union market in the process of modifying or renewing existing contracts or signing new contracts for the supply of crude oil, natural gas and coal.

The competent authorities of the Member States shall protect the confidentiality of the information received from importers under this Article, in accordance with Union law. The competent authorities shall provide that information to the Commission which shall protect the confidentiality of such information, in accordance with Union law.

For the purposes of this Article, monitoring, reporting and verification measures shall be considered to be equivalent to those set out in this Regulation in the following cases:

For the purposes of paragraph 5, point (b), the Commission shall set out, by means of an implementing act, the procedure and requirements concerning evidence to be provided by a third country for establishing equivalence. That implementing act shall be adopted in accordance with the examination procedure referred to in Article 35(3).

Importers shall be exempt from the reporting obligations set out in paragraphs 1 and 2 where they import crude oil, natural gas or coal from a third country for which equivalence has been established in accordance with paragraph 6.

From 4 August 2024, where appropriate and subject to the applicable procedures, the Commission shall propose and aim for the Union to enter into cooperation frameworks with third countries from which the Union imports crude oil, natural gas or coal to support them in establishing a monitoring, reporting and verification system equivalent to that established in this Regulation. The Commission shall not recommend entering into such cooperation frameworks where those frameworks would circumvent restrictive measures adopted under Article 215 TFEU on the import of crude oil, natural gas or coal.

By 5 August 2028 and every year thereafter, for the supply contracts concluded or renewed on or after 4 August 2024, Union producers and, pursuant to Article 27(1), importers shall report to the competent authorities of the Member State in which they are established the methane intensity of the production of crude oil, natural gas and coal placed by them on the Union market calculated in accordance with the methodology set out pursuant to paragraph 4 of this Article.

By 5 August 2030 and every year thereafter, Union producers and importers placing crude oil, natural gas and coal on the Union market under supply contracts concluded or renewed after 5 August 2030 shall demonstrate to the competent authorities of the Member State in which they are established that the methane intensity of the production of crude oil, natural gas and coal placed by them on the Union market, calculated in accordance with the methodology set out pursuant to paragraph 4, is below the maximum methane intensity values established in accordance with paragraph 6 to promote the global methane emissions reductions for those products.

The competent authorities of the Member States shall protect the confidentiality of the information received from Union producers and importers under this Article, in accordance with Union law. The competent authorities shall provide that information to the Commission, which shall protect the confidentiality of such information, in accordance with Union law.

By 5 August 2027, the Commission shall adopt a delegated act in accordance with Article 34 to supplement this Regulation by setting out the methodology for calculating, at the level of the producer, the methane intensity of the production of crude oil, natural gas and coal placed on the Union market. That methodology shall take into account different production processes and site conditions, as well as existing international methodologies and best practice for calculating methane intensity. That methodology shall be non-discriminatory and based on transparent and objective criteria. When preparing such delegated acts, the Commission shall inform the Coordination Group for oil and petroleum products, the Gas Coordination Group, the Electricity Coordination Group and other relevant stakeholders.

By 5 August 2029, the Commission shall assess the potential impact of various levels of maximum methane intensity values associated with crude oil, natural gas and coal placed on the Union market at the level of the producer, and present a report to the European Parliament and to the Council. That report shall include an assessment of the potential reduction of global methane emissions, of the impact on the security of energy supply at Union and national level and on the competitiveness of the Union’s economy, and of the potential global and regional market distortions. That report shall also include a market assessment with regard to the methane intensity of current and future supplies to the Union until 2049 through both long-term contracts and spot purchases. That assessment shall analyse the situation per Member State, taking into account contractual commitments entered into before 4 August 2024, energy infrastructure capacities and potential constraints.

On the basis of the assessment referred to in paragraph 5 and on objective criteria, the Commission shall adopt delegated acts in accordance with Article 34 to supplement this Regulation by setting out the maximum methane intensity values associated with crude oil, natural gas and coal placed on the Union market at the level of the producer. Those delegated acts shall be consistent with the methodology for calculating the methane intensity of the production of crude oil, natural gas and coal placed on the Union market set out in accordance with this Article. Those delegated acts shall also specify different methane intensity classes for crude oil, natural gas and coal. Those maximum methane intensity values shall be determined separately for crude oil, natural gas and coal, covering the best performing class or classes. Those maximum methane intensity values and methane intensity classes shall take into account the different sources, production processes and site conditions and shall be set at levels that promote reductions of the global methane emissions in relation to the crude oil, natural gas and coal placed on the Union market, while preserving the security of energy supply at Union and national level, ensuring a balanced distribution of the volumes of crude oil, natural gas and coal placed on the Union market as well as non-discriminatory treatment, and protecting the competitiveness of the Union’s economy.

By 5 February 2026, the Commission shall establish and maintain a methane transparency database, including relevant information on Member States and third countries, undertakings, importers and volumes of crude oil, natural gas and coal placed on the Union market, in particular the information submitted to it pursuant to Article 12(8), Article 18(10), Article 20(7), Article 23(2), Article 25(8), Article 27(2), Article 28(4) and Article 29(3).

In addition to the information referred to in paragraph 1, the database shall include at least the following information:

By 5 August 2026, on the basis of the information available in the methane transparency database, the Commission shall publish the methane performance profiles of Member States and of Union producers or importers, as applicable, which place crude oil, natural gas or coal on the Union market, as well as of third countries from which the Union imports crude oil, natural gas or coal and of third-country producers or exporters which supply them to the Union.

The methane performance profiles published in accordance with paragraph 3 shall be updated annually and shall contain, at least and as applicable:

The methane performance profiles published in accordance with paragraph 3 shall be made publicly available online free of charge.

This Article shall apply without prejudice to Directive (EU) 2016/943.

By 5 August 2026, the Commission shall establish a global methane monitoring tool based on satellite data and input from several certified data providers and services, including the Copernicus component of the Union Space Programme established by Regulation (EU) 2021/696. To that end, the Commission may use existing international tools or frameworks, where available.

By 5 February 2026, the Commission shall establish a rapid reaction mechanism to address super-emitting events.

The Commission shall propose to establish on the Union’s behalf bilateral dialogues with third countries from which the Union imports crude oil, natural gas or coal with the aim to set up a framework for an information exchange and an early detection and warning system to detect and alert each other of the occurrence of super-emitting events and remedial measures taken or to be taken in order to prevent or stop such events. Those dialogues shall also aim to identify ways to accelerate the reduction of methane emissions in the energy sector and, if necessary, may offer an exchange of best practices and advice to set up monitoring, reporting, verification and reduction measures equivalent to those established in this Regulation.

Based on the monitoring carried out in the context of the dialogues referred to in paragraphs 2 and 3, the Commission shall keep the European Parliament and the Council informed about the notifications of super-emitting events and the implementation of remedial measures in the Union and in third countries from which the Union imports crude oil, natural gas or coal and any potential impact on the security of energy supply at Union and national level.

This Article shall apply without prejudice to Directive (EU) 2016/943.

The Commission shall, in accordance with Article 10(1) to (5) of Regulation (EU) No 1025/2012, request one or more European standardisation organisations to draft harmonised standards for:

Where no delegated act has been adopted in accordance with paragraph 1 of this Article, the Commission is empowered to adopt delegated acts in accordance with Article 34 to supplement this Regulation by establishing mandatory technical prescriptions, or parts thereof, for the purposes of:

Member States shall lay down the rules on penalties applicable to infringements of this Regulation and shall take all measures necessary to ensure that they are implemented.

Member States shall, in accordance with national law, ensure that the competent authorities have the power to impose at least the following administrative penalties and administrative measures for infringements of Article 12, Article 14(14), Article 16(2), Article 20, Article 23(1), Article 27(1), Article 28(1) and (2) and Article 29(1) and (2), provided that they do not endanger the security of energy supply:

Where the legal system of the Member State does not provide for administrative fines, fines may be imposed by the competent national courts at the request of the competent authorities. Those fines shall be effective and their effect shall be equivalent to that of the administrative fines imposed by administrative authorities.

In the exercise of their powers under this Article, competent authorities shall cooperate closely to ensure that their powers are exercised, and that the administrative penalties and administrative measures they impose are designed and applied, in an effective and consistent way across the Union.

At least the following infringements shall be subject to penalties:

Where the conditions set out in Article 15(8) are fulfilled, Member States shall consider reducing or not imposing penalties on operators for the implementation period deemed necessary by the national authorities.

Member States shall take into account at least the following indicative criteria for the imposition of penalties, as appropriate:

Member States shall publish annually information on the type and size of the penalties imposed under this Regulation, the infringements and the operators, undertakings, mine operators or importers upon which penalties have been imposed.

The power to adopt delegated acts is conferred on the Commission subject to the conditions laid down in this Article.

The power to adopt delegated acts referred to in Article 22(3), Article 27(1), Article 29(4) and (6), and Article 32 shall be conferred on the Commission for a period of 5 years from 4 August 2024 to be tacitly extended for periods of an identical duration.

The delegation of power referred to in Article 22(3), Article 27(1), Article 29(4) and (6), and Article 32 may be revoked at any time by the European Parliament or by the Council. A decision to revoke shall put an end to the delegation of the power specified in that decision. It shall take effect the day following the publication of the decision in the Official Journal of the European Union or at a later date specified therein. It shall not affect the validity of any delegated acts already in force.

Before adopting a delegated act, the Commission shall consult experts designated by each Member State in accordance with the principles laid down in the Interinstitutional Agreement of 13 April 2016 on Better Law-Making.

As soon as it adopts a delegated act, the Commission shall notify it simultaneously to the European Parliament and to the Council.

A delegated act adopted pursuant to Article 22(3), Article 27(1), Article 29(4) and (6), or Article 32 shall enter into force only if no objection has been expressed either by the European Parliament or by the Council within a period of 2 months of notification of that act to the European Parliament and the Council or if, before the expiry of that period, the European Parliament and the Council have both informed the Commission that they will not object. That period shall be extended by 2 months at the initiative of the European Parliament or of the Council.

The Commission shall be assisted by the Energy Union Committee established by Article 44 of Regulation (EU) 2018/1999. That committee shall be a committee within the meaning of Regulation (EU) No 182/2011.

Where reference is made to this paragraph, Article 4 of Regulation (EU) No 182/2011 shall apply.

Where reference is made to this paragraph, Article 5 of Regulation (EU) No 182/2011 shall apply.

The Commission shall monitor and review the application of this Regulation and submit, by 1 January 2028 and every 5 years thereafter, a report to the European Parliament and to the Council.

The first report referred to in paragraph 1 shall in particular review the following:

For the purpose of this Article, the Commission may request information from Member States and competent authorities and shall take into account in particular the information provided by Member States in their integrated National Energy and Climate Plans and the updates thereto and in their National Energy and Climate progress reports pursuant to Regulation (EU) 2018/1999.