EUROPEAN COMMISSION Brussels, 23.11.2022 COM(2021) 804 final/2 2021/0424(COD) CORRIGENDUM



This document corrects document COM (2021) 804 final of 15.12.21



Concerns all language versions.



The text shall read as follows: Proposal for a REGULATION OF THE EUROPEAN PARLIAMENT AND OF THE COUNCIL on the internal markets for renewable and natural gases and for hydrogen (recast) {SEC(2021) 431}

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EXPLANATORY MEMORANDUM 1.CONTEXT OF THE PROPOSAL •Reasons for and objectives of the proposal 1.1 Introduction The European Union has set an ambitious goal to be the first climate neutral continent by 2050. To achieve this, Member States and the European Parliament have agreed, in the European Climate Law, to reduce greenhouse gas emission by at least 55% by 2030. In order to achieve these targets and, at the same time, contribute to competitiveness, growth and jobs, the energy system needs a systemic change: We have to reduce the use of fossil fuels – including fossil gas – and increase renewable sources. Therefore, we need to design today an ambitious transition of the gas sector towards low-carbon and renewable gases. Fossil gas constitutes around 95% of today’s gaseous fuels consumed in the EU. Gaseous fuels, account for roughly 22% of total EU energy consumption today (including around 20% of EU electricity production, and 39% of heat production). According to the relevant scenarios used by the Climate Target Plan Impact Assessment, the share of gaseous fuels to total EU energy consumption in 2050 would be about 20%. Gaseous fuels will play an important part in the energy mix by 2050, requiring the decarbonisation of the gas sector via a forward-looking design for competitive decarbonised gas markets. Despite their minor contribution to the current EU energy mix, biogas, biomethane, renewable and low carbon hydrogen as well as synthetic methane (all together renewable and low carbon gases) would represent some 2/3 of the gaseous fuels in the 2050 energy mix, with fossil gas with CCS/U (carbon capture, storage and utilisation) representing the remainder. The present initiative is equally part of the Fit-for-55 package. It covers the market design for gases, including hydrogen. It will remove existing regulatory barriers and create the conditions for this to take place in a cost effective manner. This is an important part of moving to integrated energy system that minimises the costs of transition towards climate neutrality, in particular for consumers and open new opportunities for reducing their energy bills and active participation in the market. Hydrogen is expected to be used mainly in the areas where electrification is not an option, including today’s energy-intensive industry (e.g. refineries, fertilisers, steel making) and certain heavy-duty transport sectors (maritime transport, aviation, long distance heavy vehicles). Developing a dedicated hydrogen infrastructure is necessary to release the full potential of hydrogen for these specific end-use applications. The objective of promoting renewable and low-carbon gases is to decarbonise these sectors, increase the flexibility of the electricity system thanks to power-to-X technologies, strengthen security of supply by reducing dependence on natural gas imports and allow to store (and produce) electricity. This allows linking various sectors of the economy, in conjunction with other forms of storage and flexibility, such as batteries and demand response. Likewise, it will support self-production and smart use of distributed energy supply, contribute to greater consumer empowerment. Consumers also need clear and easily accessible information to help change energy consumption patterns and switch to renewable and low carbon solutions, similarly to what they are able to do in electricity market. While aiming for a maximum of renewable hydrogen from 2030 onwards, in the short and medium term other forms of low-carbon gases in particular low-carbon hydrogen can play a role, primarily to rapidly reduce emissions from existing hydrogen production and support the parallel and future uptake of renewable hydrogen. In line with the EU hydrogen strategy, the production of renewable hydrogen in the EU should reach 1 million tonnes by 2024 and up to 10 million by 2030. From then onwards, renewable hydrogen should be deployed at a large scale and replace low-carbon hydrogen. An efficient and sustainable development of renewable and low-carbon gases as well as the hydrogen market requires to adapt the market framework.This is because the renewable and low-carbon gases today face regulatory barriers for market and grid access that represent a comparative disadvantage versus natural gas. Moreover, for a decarbonised gas market to be set up and contribute to the energy transition, significantly higher shares of renewable energy sources in an integrated energy system with an active participation of consumers in competitive markets are needed. This should allow consumers to benefit from affordable prices, good standards of service, and effective choice of offers mirroring technological developments. The deployment of various renewable and low carbon types of gases are likely to emerge in parallel and are expected to develop at a different pace across the EU: ·a hydrogen-based infrastructure will progressively complement the network for natural gas; ·a gas infrastructure in which fossil gas will progressively be replaced by other sources of methane. In addition, events on increasing energy prices have reminded us that the resilience of the European energy system is increasingly important as the EU energy system integrates more decentralised renewable energy and fossil fuels are gradually phased out. The security of supply and risk preparedness arrangements of the gas sector must be fit for the clean energy transition. The Commission’s Communication on tackling rising energy prices (A toolbox for action and support), highlights the interplay between security of supply, the optimal use of storage capacities and the volatility of energy prices. 1.2 Objectives of the proposal The present initiative seeks to facilitate the penetration of renewable and low-carbon gases into the energy system, enabling a shift from natural gas and to allow for these new gases to play their needed role towards the goal of EU climate neutrality in 2050. Within this context, it addresses the following areas: Low level of customer engagement and protection in the green gas retail market. For new gases to play a full role in the energy transition, the retail market rules should empower customers to make renewable and low carbon choices. This is not currently the case. Moreover, there is no common EU terminology and certification system for low carbon fuels and gases. In addition, the retail gas markets exhibit market concentration and low levels of new entry and innovation. This prevents customers from benefiting from competition by making low carbon choices. To be able to make sustainable energy choices, customers need sufficient information on their energy consumption and origin, as well efficient tools to participate in the market. Moreover, Member States should take the necessary measures to protect vulnerable and energy poor customers. The decarbonised gas market should not be developed without them being able to fully benefit from it and by addressing all generations’ needs, from young to elderly. Hydrogen infrastructure and hydrogen markets. The current regulatory framework for gaseous energy carriers does not address the deployment of hydrogen as an independent energy carrier via dedicated hydrogen networks. There are no rules at EU level on tariff-based investments in networks, or on the ownership and operation of dedicated hydrogen networks. In addition, no harmonized rules on (pure) hydrogen quality exist. Consequently, barriers exist for the development of a cost-effective, cross-border hydrogen infrastructure and competitive hydrogen market, a prerequisite for the uptake of hydrogen production and consumption. The present proposal seeks to address these deficiencies. It includes a proposal for a system of terminology and certification of low carbon hydrogen and low carbon fuels.

Renewable and low-carbon gases in the existing gas infrastructure and markets, and energy security. Today, renewable and low-carbon gases represent a minor share in the EU energy mix. To untap their potential, access to the gas wholesale market, i.e. the virtual trading points, represents a key prerequisite. Abolishing costs for cross-border trade of those gases and facilitating connection of production facilities will also improve the business case. Differences in gas quality parameters and in the volume of hydrogen blended in the natural gas system can affect the design of gas infrastructure, end-user applications and cross-border system interoperability, thus risk fragmenting the internal market. However, current gas quality rules are not fit to deal with future developments. On LNG, addressing the residual barriers regarding access to LNG terminals could open the way to import renewable and low carbon gases from abroad supporting the decarbonisation of the EU gas market. Finally, preserving and strengthening resilience in the transition require appropriate arrangements of security of supply. Network planning. As outlined in the Commission’s Energy System Integration Strategy, coordinated planning and operation of the entire EU energy system, across multiple energy carriers, infrastructures, and consumption sectors is a prerequisite to achieve the 2050 climate objectives. Current network planning schemes and practices are deficient asthere are discrepancies between the EU-wide ten-year network development plan (‘TYNDP’) and national network development plans (‘NDP’) A better linkage between TYNDP and NDP would allow transnational exchange of information on transmission systems usage. Security of supply and storage. In reaction to the significant and EU-wide energy price increases in autumn 2021, the European Council invited the Commission to swiftly consider medium and long-term measures that increase the resilience of the EU’s energy system including measures which enhance security of supply. To contribute to a timely response to this crisis and possible new crisis at Union level, this proposal includes specific measures to improve cooperation and resilience, notably to ensure a more effective and coordinated use storage and operational solidarity arrangements. The measures are targeted to reinforce the resilience of the EU energy system against future shocks in a timely manner. They cover measures in this Regulation and Regulation (EU) 2017/1938 on security of gas supply. In order to ensure a coherent response, the measures on security of supply are part of this legislative proposal and not proposed as a separate legislative proposal. As indicated in the Communication on energy prices of 13 October 2021 entitled ‘Tackling rising energy prices: a toolbox for action and support’, coordination of security of supply across borders is crucial for the resilience against future shocks. The measures proposed require Member States to explicitly make storages part of their security of supply risks assessments at regional level, including risks linked to the control of storage by entities from third countries. Member States should consider storage measures through regional cooperation in case of unaddressed risks. The proposal defines enabling conditions to deployment of voluntary joint procurement of gas strategic stocks to be used in case of emergency. Measures are also introduced to improve the transparency and access to storages, address cybersecurity risks of gas and facilitates bilateral solidarity arrangements between Member States in case of crisis. The Commission encourages the Member States to proceed with solidarity arrangements without waiting so that even in a severe crisis households receive the gas they need. •Consistency with existing policy provisions in the policy area The proposed initiative is strongly linked and complementary to the legislative proposals brought forward in the context of the Fit-for-55 package to implement the European Green Deal, including: The revised Renewable Energy Directive (‘RED II’), which is the main EU instrument dealing with the promotion of energy from renewable sources. It aims to accelerate the penetration of renewable energy, including renewable gases in the energy system. Its proposed amendment increases the target for renewable sources in the EU’s energy mix to 40% and promotes the uptake of renewable fuels, such as renewable hydrogen in industry and transport, with additional targets. In relation to this initiative, the RED II defines renewable hydrogen as ‘renewable fuels of non-biological origin’ and ‘biomass fuels’ that meet a 70% greenhouse gas emission reduction compared to fossil fuels setting specific sub-targets for the consumption of renewable hydrogen (50% of total hydrogen consumption for energy and feedstock purposes in industry by 2030 and 2.6% of the energy supplied to the transport sector). The Energy Efficiency Directive ('EED') and the related Energy Performance of Buildings Directive ('EPBD') including the proposals for their amendment interact with the present initiative as they affect the level and structure of gas demand. Energy efficiency measures can alleviate energy poverty and reduce consumer vulnerability. As gaseous fuels are currently dominating theEuropean heating and cooling supply and the cogeneration plants, their efficient use stays at the core of the energy efficiency measures. The Gas Directive and the Gas Regulation are coherent with the energy efficiency first principle: an open and competitive EU market with prices that reflect energy carriers’ production costs, carbon costs, and external costs and benefits would efficiently provide clean and safe hydrogen to end users who value it most. The TEN-E Regulation, as proposed by the Commission in December 2020, aims to better support the modernisation of Europe's cross-border energy infrastructure for the European Green Deal. It introduces hydrogen infrastructure as a new infrastructure category for European Network Development. The present initiative is complementary to the proposed TEN-E Regulation as it focuses on alignment of the national plans with the requirements of the European wide Ten Year Network Development plan. As announced in the EU strategy to reduce methane emissions, the Commission will propose legislation to reduce methane emissions in the energy sector. The initiative will seek to improve information for all energy-related methane emissions. The present initiative is complementary as it seeks to facilitate the penetration of renewable and low-carbon gases, enabling a shift from natural gas. •Consistency with other Union policies The Emission Trading Scheme (´ETS´) increases the price of using fossil fuels relative to renewable and low-carbon gases and, thus, fosters the demand for such gases and investments in related production technology. The Commission has proposed strengthening, including reinforcements in and extensions to the aviation sector, maritime and road transport, and buildings. Under this Scheme all hydrogen production facilities are included, as well as electrolysers with a production capacity exceeding 25 tonnes/day. The Innovation Fund, which was established by the EU Emission Trading System (EU ETS) Directive for the period 2021 to 2030, is one of the funding instruments supporting the transition to a climate neutral Europe by 2050. The Innovation Fund, which was established by the EU ETS Directive for the period 2021 to 2030, is one of the funding instruments supporting the transition to a climate neutral Europe by 2050. The revision of the Energy Taxation Directive strives to align the taxation of energy products with EU energy and climate policies, promote clean technologies and remove outdated exemptions and reduced rates that currently encourage the use of fossil fuels. Under the revised Directive, products covered by the Directive are grouped and ranked according to their environmental performance. According to this, the revision sets a preferential minimum levels of taxation of EUR 0.15/ GJ (compared to EUR 10.75/GJ for fossil fuels) For renewable and low-carbon hydrogen fuels used as motor fuels. For renewable and low-carbon hydrogen fuels used as heating fuels, it sets a preferential minimum levels of taxation of EUR 0.15/ GJ (compared to EUR 0.6/GJ for natural gas). The revised Alternative Fuels Infrastructure Regulation (AFIR), which will repeal Directive 2014/94/EU on deployment of alternative fuels infrastructure (AFID), as proposed by the Commission in July 2021, aims to tackle rising emissions in road transport to support the transition to a nearly zero-emission car fleet by 2050. The Regulation requires Member States to expand their network of recharging and refuelling infrastructure in line with zero emissions car sales, and to install charging and fuelling points at regular intervals on major highways. The revision of the Alternative Fuel Infrastructure Regulation will require one refuelling stations (min. 2 t/day, 700 bar) every 150 km along the TEN-T core network and in every urban node by 2030; this would result in around 700 HRS along transport nodes, and 88 HRS in urban nodes. The Amendment of the Regulation setting CO2 emission standards for cars and vans aims to ensure a clear pathway from 2025 towards zero-emission transport. The regulation notably defines zero-emission vehicles as battery electric vehicles, fuel-cell and other hydrogen powered vehicles, and sets a target of zero average emissions of the new vehicle fleets by 2030. The FuelEU Maritime proposal aims to increase the share in the fuel mix of international maritime transport of sustainable low and zero-carbon alternative fuels including: liquid biofuels, e-liquids, decarbonised gas (including bio-LNG and e-gas), decarbonised hydrogen and decarbonised hydrogen-derived fuels (including methane, and ammonia). The focus on fuels and power technologies should enable significant and rapid emission reductions, using fully the existing technologies and infrastructure alongside incentives provided by other measures to be proposed. It will also facilitate the definition of decarbonisation pathways for the entire maritime cluster. The REFuel EU Aviation proposal which targets to advance the potential of sustainable aviation fuels to reduce aviation’s GHG footprint is yet largely untapped. In order to decrease significantly its emissions, the aviation sector will need to reduce its current reliance on fossil jet fuel and rely increasingly on the use of sustainable aviation fuels (SAF) in the years to come. The proposal sets out a minimum share of 0.7% of ‘synthetic aviation fuels’ in the aviation fuels supplied to aircraft operators where ‘synthetic aviation fuels’ are renewable fuels of non-biological origin, as defined in the renewable energy directive. 2.LEGAL BASIS, SUBSIDIARITY AND PROPORTIONALITY •Legal basis The objectives of this initiative cannot be achieved on a national level. The planned measures of the present initiative seek to advance the four objectives set out in Article 194 of the Treaty of the Functioning of the European Union (TFEU), while at the same time contributing to the decarbonisation of the EU’s economy. The planned measures are to be adopted on the basis of Article 194 (2) TFEU together with Article 114 (1) TFEU. In the field of energy, the EU has a shared competence pursuant to Article 4 (2) (i) TFEU.

The present initiative also builds upon a comprehensive set of legislative acts that have been adopted and updated during the past two decades. With the objective of creating an internal energy market, the EU has adopted four consecutive legislative packages between 1996 and 2019, with the overarching aim of integrating markets and liberalising national electricity and gas markets. These provisions cover a wide range of aspects, from market access to transparency, consumer rights, increase the liquidity of gas markets, and the independence of regulatory authorities. •Subsidiarity (for non-exclusive competence) Currently, there are no rules at EU-level regulating dedicated hydrogen networks or markets and low-carbon hydrogen and low-carbon fuels. In view of the current efforts at EU and national levels to promote the use of renewable hydrogen as a replacement for fossil fuels, Member States would be incentivised to adopt rules on the transport of hydrogen through dedicated infrastructure at national level. This creates the risk of a fragmented regulatory landscape across the EU, which could hamper the integration of national hydrogen networks and markets, thereby preventing or deterring cross-border trade in hydrogen. Harmonising rules for hydrogen infrastructure at a later stage (i.e. after national legislation is in place) would lead to increased administrative burdens for Member States and higher regulatory costs and uncertainty for companies, especially where long-term investments in hydrogen production and transport infrastructure are concerned. The creation of a regulatory framework at EU-level for dedicated hydrogen networks and markets would foster the integration and interconnection of national hydrogen markets and networks. EU-level rules on the planning, financing and operation of such dedicated hydrogen networks would create long-term predictability for potential investors in this type of long-term infrastructure, in particular for cross-border interconnections (which might otherwise be subject to different and potentially divergent national laws). When it comes to biomethane, without an initiative at EU level, it is likely that by 2030 a regulatory patchwork would still exist regarding access to wholesale markets, connection obligations and transmission system operator (TSO)- distribution system operator (DSO) coordination measures. Likewise, without some harmonisation at the EU level, renewable and low-carbon gases producers will be facing vastly different connection and injection costs across the EU, resulting in an unequal playing field. Without further legislation at the EU level Member States would continue to apply different gas quality standards and rules on hydrogen blending levels, risking cross-border flow restrictions and market segmentation. Gas quality standards would continue to be mainly defined by the quality parameters of natural gas, limiting the integration of renewable gases in the network All these aspects are likely to lower cross-border trade with renewable and low-carbon gases that might be compensated by higher natural gas imports. The utilisation of the LNG terminals and imports could remain restricted to natural gas, despite that no adaptation of LNG terminals would be necessary in case competitive biomethane or synthetic methane from non-EU sources were available. National netwrok planning will be required to be developed only in Member States where certified Independent Transmission Operators (ITO) and Independent System Operators (ISO) are operating. While most Member States have a single gas national development plan within which gas operators cooperate, there is still limited cross-sector cooperation. EU coordinated emergency preparedness for the current gas sector has proven to be more efficient than action only at national level. •Proportionality The initiative complies with the proportionality principle. It falls within the scope of Article 194 of the Treaty on the Functioning of the European Union. The policy intervention is proportional to the dimension and nature of the problems defined and the achievement of the set objectives. The proposal does not go beyond what is necessary to achieve the general objective pursued to facilitate the decarbonisation of gaseous fuels in a competitive manner at least economic costs whilst ensuring energy security and placing consumers at the heart of the energy markets. The preferred set of options are considered proportionate and builds to the extent possible on existing approaches. The balance between obligations and consideration of the different capabilities to act among Member States and private entities is considered appropriate given the imperative of achieving climate neutrality by 2050. •Choice of the instrument Building on the overall evaluation of the current regulatory framework for the gas market, the instruments chosen are a Directive, to recast the Directive 2009/73/EC, and a Regulation to recast Regulation No 715/2009. The choice of a recast of these existing legal acts will enhance legal clarity. Recourse to an amending act may have been inadequate to address a wide set of new provisions. The choice of the instruments thus calls for a revision of rules already adopted and implemented, as a natural evolution of current legislation,in view of this changes. Further acts will need to be amended through the Gas Regulation such as: the SoS Regulation (EU) 2017/1938, ACER Regulation (EU) 2019/942 and REMIT Regulation (EU) No 1227/2011. 3.RESULTS OF EX-POST EVALUATIONS, STAKEHOLDER CONSULTATIONS AND IMPACT ASSESSMENTS •Ex-post evaluations/fitness checks of existing legislation The entry into force of the Third Energy package has positively contributed to the competition and performance of the internal energy markets. Nevertheless, the current regulatory framework for gas focuses on fossil-based natural gas and does not fully anticipate the emergence of alternatives for methane gases (including natural gas and biomethane), such as hydrogen. A re-examination of the current gas market regulatory framework is needed and it has already been announced in the European Commission’s communication on a hydrogen strategy for a climate-neutral Europe. Given the different potential in EU Member States for the production of renewable and low carbon hydrogen, a suitable market framework could facilitate hydrogen to play its role as an energy carrier and as an enabler of energy system integration. On this basis, four main drivers have been identified under Problem area I of the Impact Assessment: (i) decarbonisation will result in the emergence of a European hydrogen value chain reliant on a cross-border hydrogen market; (ii) lack of hydrogen infrastructure investments hinder market development; (iii) hydrogen infrastructure is likely to constitute a natural monopoly, resulting in non-competitive market structures; (iv) diverging hydrogen quality rules may hinder cross-border flows and incur additional costs.

The existing gas rules, focusing on fossil-based natural gas mainly imported from outside the EU, do not address the specific characteristics of decentralized renewable and low-carbon gases production within the EU. In addition, the growing volumes of biomethane, hydrogen but also LNG affect gas quality and thereby the design of gas infrastructure and end-user appliances. In particular, the Impact Assessment recognizes five main drivers related to this Problem Area: (i) constrained market and grid access for local producers of biomethane connected to the distribution grids, divergence of rules regarding obligation to connect and costs of grid connection for renewable and low carbon gases and intra-EU entry/exit tariffs hinder the establishment of a fully integrated, liquid and interoperable EU internal gas market; (ii) differences in gas quality and hydrogen blending levels can negatively impact cross-border flows and end-users, while current gas quality rules are not fit to deal with future developments; (iii) LNG terminals equipped to receive mainly natural gas, limited access for new gases to LNG terminals; (iv) long term supply contracts for unabated natural gas may lock-in natural gas and hinder supply of renewable gases towards 2050; (v) current energy security arrangements only address risks related to the supply of natural gas and not of renewable and low carbon gases. Concerning network planning, cooperation between TSOs and regulators needs to evolve further. The increasing penetration of intermittent energy sources requires the whole energy system to be better integrated and the infrastructure to become more interconnected ,based on a more holistic and inclusive approach The Impact Assessment outlines three main drivers regarding this Problem Area: (i) network planning varies between Member States and TSOs, separate planning for electricity and gas; (ii) no transparency on potential of existing infrastructure for repurposing or decommissioning; (iii) DSOs not explicitly included in TSO planning. Furthermore, a more harmonized system development strategy would further increment interlinkages between electricity and gases systems including hydrogen. The evaluation showed that competition needs to improve to ensure that the full benefits of market integration are passed on to EU consumers. Furthermore, consumers are still deprived from the necessary tools to get actively involved in the market. Consumer protection provisions in the analysed legislation prove to only be partially fit for purpose. In particular protection for vulnerable customers is still uneven between Member States and energy poverty continues to be significant across the EU. Concordantly, Problem Area IV identified three problem drivers: (i) untapped competition potential in retail markets; (ii) insufficient customer empowerment in terms of switching, price comparison tools, billing information, energy communities, and access to data; and (iii) inadequate consumer protection in particular for vulnerable and energy poor. •Stakeholder consultations In line with the Better Regulation Guidelines, the Commission carried out a comprehensive and inclusive stakeholder consultation based on a consultation strategy that included a range of methods and tools. This strategy aimed to ensure that all relevant evidence was taken into account, including data about costs, societal impact, and benefits of the initiative. Several consultation tools were employed: a consultation on the inception impact assessment (Roadmap), an online public consultation based on a questionnaire, a presentation by the Commission and feedback from stakeholders, including the Gas Regulatory Forum, discussions with the Member States, with members of the European Parliament and with National Regulatory Authorities, and discussions with stakeholders in a large stakeholder workshop. The Commission received 263 responses to the open public consultation. In general, respondents confirmed that they see a need to revise the Gas Directive and Gas Regulation to help to achieve decarbonisation objectives. Moreover, over 60% of respondents expect that the technological and regulatory changes necessary to decarbonise the gas market have the potential to create new jobs by 2030. Regarding the development of hydrogen infrastructure and markets, a majority of the respondents support the introduction of regulation at an early stage to foster a well-functioning and competitive hydrogen market and infrastructure. Respondents advocated for an EU legislative framework that defines key regulatory principles and takes a step-wise approach. A large majority supports e.g. third party access, rules for access to hydrogen pipelines, import terminals and storage, and advocates for network activities to be unbundled. Most respondents considered it important to define early the role of private parties in developing hydrogen infrastructure. A large majority of respondents also consider that existing and future private networks may be (temporarily) exempted from certain regulatory requirements but that convergence on a single regulatory framework needs to be assured. The vast majority of respondents consider that rights and permitting requirements for new hydrogen infrastructure should be similar to those applicable to methane gas pipelines today. Regarding the promotion of the access of renewable and low carbon gases to the existing gas market and infrastructure, stakeholders agree on a need to revise the current regulatory framework to help achieve decarbonisation objectives. A majority of stakeholders consider it important to ensure full market access and facilitate the injection of RES&LC gases into the gas grid. Many respondents advocate an obligation for network operators to connect RES&LC gases producers and introduce an injection charge reduction. The majority of respondents support as well the improvement of the transparency framework for LNG terminals. There is also a strong support for the harmonised application of gas quality standards across the EU, for reinforced cross-border coordination and increased transparency. Respondents are divided on hydrogen blending, but the majority agrees that it can provide a cost-efficient and fast first step, despite the high technical costs, to energy system decarbonisation. Few stakeholders support the removal of intra-EU cross-border tariffs. The majority of the respondents consider gas-specific security challenges and cyber-security measures as important. Regarding integrated network planning, the majority of stakeholders support aligning the timing of the Network Development Plan (NDP) with the TYNDP, and a single gas plan irrespective of the unbundling model chosen. A majority of respondents expressed even stronger support for a joint electricity and gas scenario. A substantial number of stakeholders ask for the inclusion of hydrogen projects in the NDP. Most stakeholders agree on the role of DSOs to provide and share information, with several respondents also supporting that DSOs provide their own plan including system optimisation across different sectors. Respondents also preferred a joint gas and electricity plan to joint scenarios with separate plans. Several stakeholders pointed out that a joint methane and hydrogen plan, with a separate electricity plan, would be the preferred option. Regarding customer engagement and protection in the green gas retail market, the majority of the stakeholders called for higher ambitions in the citizen/consumer-related provisions by mirroring those in the electricity market. As well, energy poverty provisions should help ensure consumers are not paying the cost of switching to clean gas-based options. Representatives of the private sector support the plans to phase out regulated prices, while some consumer organisations would opt for keeping them to protect energy poor and vulnerable consumers. Almost half of all respondents want provisions on the comparability of offers and accessibility of data, transparency, smart metering systems, and switching to be reinforced. No respondent has supported the non-regulatory approach. •Collection and use of expertise The proposed initiative and its underpinning Impact Assessment draw on evidence from the stakeholder input to the extensive consultations carried out in this respect, as well as literature review, and modelling. The literature review included the results of a serie of topical studies on key elements such as the role of hydrogen and decarbonised gas infrastructure, market and production, that were conducted for the Impact Assessment or that contributed to its scope, as well as assessments carried out in for other relevant Commission initiatives. Conclusions adopted in the framework of several stakeholder forums, most importantly the one on gas regulation (Madrid Forum), and the one on electricity regulation (Florence Forum) were also considered in the analysis. Discussions with Member States, with members of the European Parliament, with National Regulatory Authorities, ACER and discussions with other stakeholders were equally considered. •Impact Assessment Following the Better Regulation guidelines, the Commission carried out an Impact Assessment of several policy options. This work was supported by a consultation within the Commission via an Inter-Service Steering Group. The Impact Assessment was presented to and discussed with the Regulatory Scrutiny Board (RSB). TheRegulatory Scrutiny Board issued a ‘positive opinion with reservation’. Reservationswere notably addressed by: (i) integrating the conclusions of the evaluation into the problem description, (ii) spelling out the role of the initiative as part of the enabling framework of the ‘Fit for 55’ package, (iii) clarify the baseline of the impact of the policy options, (iv) distinguish more between different actors, in particular between natural gas and hydrogen producers and consumers, (v) provide an assessment of how the initiative may have different impacts for SMEs compared to other (larger) companies, (vi) better reflect the dissenting and minority views throughout the report, including in the problem definition, the construction of the options, analysis of impacts and the choice of the preferred option, (vii) improve the narrative of the report, and (viii) complete the cost and benefit tables in the appropriate format. Throughout the Impact Assessment work, a range of measures was considered across four Problem Areas to address the identified problems and problem drivers to reach the objectives of the initiative: Following an assessment of their effectiveness, efficiency, coherence and proportionality, a package of preferred options has been found best suited to contribute to the set objectives. Problem Area I: Hydrogen infrastructure and hydrogen markets Problem Area I considers the following policy options: to tender the rights for hydrogen network operation (Option 1); to introduce main regulatory principles inspired by those currently applicable to the natural gas market but adapted to the development stage of hydrogen markets (Option 2); and to establish a fully developed regulatory regime for hydrogen (similar to the one currently applicable to the natural gas sector) without need for a transition to a more mature hydrogen market (Option 3). The preferred option is to introduce key regulatory principles from the start whilst providing clarity on the final (future) regulatory regime. (Option 2b ‘Main regulatory principles with a vision’). The key benefit of this option is that it fosters market integration, provides clarity for investors, avoids the emergence of non-competitive market structures as well as costs of ex-post adjustments of rules once the market is mature, but leaves flexibility to tailor the regulation to the staged ramp-up of the hydrogen sector. Problem Area II: Renewable and low carbon gases in the existing gas infrastructure and markets, and energy security Problem Area II contains options that promote access of renewable and low-carbon (RES&LC) gases to the existing gas market and infrastructure. All options include also a progressive level of intervention for addressing energy security concerns, notably extending existing tools, standards and procedures to RES&LC gases, effective solidarity and addressing risks linked to cybersecurity for the gas sector. Option 3 “Allow and promote renewable and low-carbon gases full market access” is the preferred option for Problem Area II. This option contains measures to support access of renewable and low carbon gases to the wholesale market, LNG terminals, and transmission grid (regardless of the place of connection), including tariff discounts for injection to the grid and cross-border transport. Gas quality would be governed by a harmonised EU approach for cross-border interconnection points while leaving flexibility to the Member States. The allowed cap for hydrogen blends is set at 5% for all cross-border points – a level that is cost-efficient in terms of adaptation and abatement costs.

Allowing and promoting renewable and low-carbon full market: The measures foreseen are consistent with the Union’s efforts to fight climate change and necessary to achieve the objectives of the European Green Deal. The key benefit is that the measures will decrease the production costs for producers of renewable and low carbon gases, increase competition, liquidity and trade for renewable gases, while encouraging a reduction of greenhouse gas emissions. In this way, consumers and taxpayers will benefit as support could be lowered. It will also limit risks for energy security and save time and resources, reduce uncertainties, improve the efficiency of emergency measures, and strengthen security-specific requirements for gas companies. Problem Area III: Network planning Problem Area III considers options regarding integrated network planning. The preferred option for Problem Area III is Option 2 ‘National Planning based on European Scenarios’. The option allows for national planning but requires that it is based on joint scenarios for gas and electricity, aligned with the TYNDP and linked to the relevant National Energy and Climate Plan. It includes all relevant actors (DSOs) and enables the identification of pipelines that can be used for repurposing from methane to H2 on a level of detail that would not be easily achievable on the European level. Establish National Planning based on European Scenarios: The key benefit is that this will eliminate risks that electricity and gas TSOs plan the evolution of their systems based on incompatible assumptions. It enables sector integration and a conceptual system plan while keeping the benefits of more detailed sector-specific network development plans. It ensures a common vision of the different stakeholders implying that network planning takes into account the decarbonisation strategies at the national and EU levels, reducing the risk of potential lock-ins or stranded assets. Problem area IV: Low level of customer engagement and protection in the green gas retail market Problem Area IV contains options that postulate for a non-regulatory approach in tackling competition and consumers’ engagement or instead require addressing the problem drivers through new legislation, mostly mirroring what was already established in the electricity sector. In light of the analysis, the preferred option is Option 2 ‘Flexible legislation’, which mirrors the electricity market consumer protection and also the empowerment provisions. This option is most likely to be the most effective, efficient, and consistent with other Problem Areas. The key benefit is that it will offer significant savings potential, help new suppliers and service providers to enter the market, develop innovative products, resulting in increased competition, consumer engagement and economic benefit. It would also enable citizens and communities to increase social acceptance, mobilise private capital and facilitate the deployment of renewable and low-carbon gases. Reducing the risk of over-investments will have a positive environmental impact. •Regulatory fitness and simplification The proposals for amending the existing legislation are designed in accordance with the most cost-effective policy options scrutinised in the Impact Assessment. It is expected from some of the preferred options to increase administrative, implementation and enforcement costs for regulatory bodies and market operators. For example, higher administrative exchanges between NRAs and natural gas shippers, increased coordination efforts between DSOs and TSOs, and further regulatory and implementation efforts for Member States and national authorities might stem from the proposed measures. However, lower and more efficient regulatory costs are also expected from the amended framework. Furthermore, the Impact Assessment shows that the proposed measures offer the most cost-effective regulatory options to achieve the overarching objective of the initiative, namely the establishment of rules for the transmission, distribution, supply and storage of methane and hydrogen gases that can support the decarbonisation of the energy system while ensuring secure and affordable energy. The short-term regulatory costs entailed in some of the preferred measures must be assessed against the costs and efforts that a late integration and decarbonisation of the energy system would require in the long term. The benefits that the options are expected to produce in terms of support for renewable sources, energy system integration, consumer protection and energy security will largely outweigh the immediate administrative and implementation costs. The proposal further contributes to simplifying the current regulatory framework by harmonising the provisions on gas infrastructure and market with the new regulatory architecture conceived by the Clean Energy Package for the electricity sector. Higher alignment between sectors is expected to benefit many regulatory areas, notably consumer empowerment and protection, governance and regulatory oversight. Similar contributions are also foreseen in the early introduction of a regulatory framework for hydrogen infrastructures and markets. Whilst these rules will likely increase the immediate administrative costs and regulatory burdens for national authorities and market operators, an early harmonisation of regulatory principles for hydrogen is expected to significantly lower future compliance costs and prevent the risk of major regulatory divergences and implementation costs. •Fundamental rights Safeguarding EU values and citizens’ fundamental rights and security in a developing green, digital energy environment, is of paramount importance. The proposed policy measures on data management were developed with this in mind, aiming at ensuring widespread access and use of digital technologies and data-driven services while at the same time guaranteeing a high level of the right to private life and to the protection of personal data, as enshrined in Articles 7 and 8 of the Charter of Fundamental Rights of the EU, and the General Data Protection Regulation. 4.BUDGETARY IMPLICATIONS The budgetary impact on the EU budget associated to the proposal under this package concerns the human resources of the Agency for the Cooperation of Energy Regulators (ACER) and of the European Commission’s Directorate-General (DG) for Energy which are described in the Legislative Financial Statement accompanying the Commission proposal for a recast of the [Gas Regulation]. Essentially, the new tasks to be carried out by ACER, notably as regards rules facilitating the development of a competitive hydrogen sector, but also the increasing complexity of gas markets due to an increasing share of other gases than natural gas, require a phasing in of 21 additional FTE in ACER from 2023 onwards. For implementing the proposed new rules for a new and growing sector, for integrating new types of gases into the gas market and infrastructure as well as for enforcing the strengthened consumer provisions, also the human resources of DG Energy need to be reinforced by 5 additional FTE. 5.OTHER ELEMENTS •Implementation plans and monitoring, evaluation and reporting arrangements Progress monitoring will consist of a two-tier approach of annual reporting by ACER and an evaluation by the Commission. ACER’s mandate of annual monitoring and reporting of market performance in its annual market monitoring report (obligation in Regulation (EC) No. 715/2009) will be retained, with its scope extended to hydrogen. Within one year of the adoption of the proposals, the Commission will invite ACER to review and update its current monitoring indicators (with the involvement of affected stakeholders) to ensure their continuing relevance for monitoring progress towards the objectives underlying the present proposals. ACER will continue relying on the already established data sources used for the preparation of the market monitoring report, extended with relevant data on hydrogen.

ACER's annual reporting will replace the Commission's reporting obligations that are currently still existing under the Gas Directive. The detailed proposals will ensure that ACER’s monitoring is complementary to other monitoring exercises (esp. monitoring under the Governance of the Energy Union and Climate Action) avoiding any overlaps. The Commission will carry out a fully-fledged evaluation of the impact of the proposed initiatives, including the effectiveness, efficiency, continuing coherence and relevance of the proposals, within a given timeline after the entry into force of the adopted measures (indicatively, five years). By 31 December 2030, the Commission shall review the Directive and shall submit a report to the European Parliament and to the Council. •Explanatory documents (for directives) Following the ruling of the European Court of Justice in Commission vs Belgium (case C-543/17), Member States must accompany their notifications of national transposition measures with sufficiently clear and precise information, indicating which provisions of national law transpose which provisions of a directive. This must be provided for each obligation, not only at ‘article level’. If Member States comply with this obligation, they would not need, in principle, to send explanatory documents on the transposition to the Commission. The Regulation will be directly and uniformly implemented in the Member States, and hence not requiring an Explanatory Document. •Detailed explanation of the specific provisions of the proposal The proposed revised directive consists of ten chapters comprising 91 articles. Chapter 1 – Subject matter, scope and definitions This chapter sets out the subject matter and scope of the rules for the transmission, distribution, supply, and storage of gases using the natural gas system as well as the rules for the transport, supply and storage of hydrogen using the hydrogen system. It also defines the main terms used in the proposed directive. Chapter 2 – General rules for the organisation of the markets This chapter lays down the rules to ensure competitive, consumer-centred, flexible and non-discriminatory markets for gas. It contains provisions on market access such as the free choice of supplier, market-based supply prices, public service obligations, sustainability, certification of renewable and low carbon gases, promotion of regional cooperation, and technical and procedure rules. Chapter 3 – Consumer empowerment and protection and retail markets This chapter provides in particular a set of rights for the consumer: It elaborates on basic contractual rights, switching rights and fees, and rules on comparison tools, active customers, and citizen energy communities. It also contains provisions on billing, smart and conventional metering, and data management. It also contains provisions on single points of contact, right to out-of-court dispute settlement, vulnerable customers, and retail markets. Chapter 4 – Third party access to infrastructure This chapter is divided into 3 sections to cover the following: access to natural gas infrastructure, access to hydrogen infrastructure, and refusal of access and connection. Chapter 5 – Rules applicable to transmission, storage and system operators of natural gas This chapter elaborates on tasks of transmission, storage and LNG system operators, confidentiality and decision-making powers. Chapter 6 – Distribution system operators of natural gas This chapter sets the designation of distribution system operators, their tasks, the decision-making powers regarding the connection of the new production facilities for renewable and low-carbon gases to the distribution system, the unbundling of distribution system operators, the confidentiality obligations of distribution system operators, provisions on closed distribution systems, and combined operator.

Chapter 7 – Rules applicable to the dedicated hydrogen networks This chapter provides in particular tasks of hydrogen network, storage and terminal operators, provision on existing hydrogen networks, geographically confined hydrogen networks, closed hydrogen systems, interconnectors with third countries, and confidentiality for operators. Chapter 8 – Integrated Network planning This chapter elaborates on network development and powers to make investment decisions, on hydrogen network development reporting, as well as on financing new cross-border hydrogen infrastructure. Chapter 9 – Unbundling of transmission system operators This chapter is divided into six sections to cover the following: ownership unbundling, independent system operators, independent transmission operators, the unbundling of dedicated hydrogen networks operators and the designation, the certification of natural gas and hydrogen system operators, and unbundling and transparency of accounts. Chapter 10 – Regulatory authorities This chapter focuses on the designation and independence of regulatory authorities, on general objectives of the regulatory authority, on their duties and powers, on the regulatory regime for cross-border issues, on compliance with the network codes guidelines, and on record keeping. Chapter 11 – Final provisions The last chapter focuses on final provisions and includes articles notably on safeguard measures, level playing field, technical agreements, derogations, empowerment procedure, the exercise of delegation, committee procedure, reporting, repeal, transposition, entry into force, Addressees. Annex I is about the minimum requirements for billing and billing information. Annex II deals with smart metering in natural gas. Annex III lists the date of application and the transposition limits of the repealed Directive and its amendments. Annex IV contains a correlation table. The proposed revised regulation consists of eight chapters comprising 69 articles. Chapter 1 – Subject matter, scope and definitions This chapter sets out the subject matter and scope of the rules regarding the objectives of the Energy Union, climate and energy framework as well as consumers. It also defines the main terms used in the proposed regulation. Chapter 2 – General rules for the organisation of the markets and infrastructure access This chapter lays down the general principles as well as the separation of regulated asset bases, third party access services, market assessment for renewable and low carbon gases, principles of capacity-allocation mechanisms and congestion-management procedure, trading of capacity rights, balancing rules and imbalance charges, certification, and cooperation of transmission system operators. Chapter 3 – Network access

This chapter elaborates on tariffs for access to networks, and discounts. Chapter 4 – Transmission, storage, LNG, and hydrogen terminal system operation This chapter sets out provisions on firm capacity for renewable and low carbon gases, cross border coordination on gas quality, hydrogen blends, the European network of transmission system operators for gas, monitoring by ACER, regulatory authorities, consultations, costs, regional cooperation, TYNDP, transparency requirements, and record-keeping. Chapter 5 – Distribution system operation This chapter lays down the rules on firm capacity for renewable and low carbon gases, cooperation between DSOs and TSOs, transparency requirement, the European entity for distribution system operators. It includes procedures and tasks. Chapter 6 – Access to dedicated hydrogen networks This chapter focuses on cross-border coordination on hydrogen quality, the European Network of Network Operators for Hydrogen, its tasks, TYNDP for hydrogen, costs, and consultation, the monitoring by ACER, regional cooperation, and transparency requirements. Chapter 7 – Network codes and guidelines This chapter sets out provisions for the adoption of network codes and guidelines, the establishment of network codes, amendments of network codes, guidelines, right of Member States to provide for more detailed measures, provision of information and confidentiality, and penalties. All three rules are adapted to hydrogen. Chapter 8 – Final provisions This chapter focuses on final provisions and includes articles notably on new natural gas and hydrogen infrastructure, committee procedure, exemptions, derogations, the exercise of delegation, amendments to regulations, amendment to extend the Regulation on security of gas supply to RES&LC gases and to include measures on cybersecurity, solidarity and storage, repeal, and entry into force. Annex I contains guidelines. Annex II contains the inserted Annex IX to Regulation 2017/1938 Annex III contains information on the repealed Regulation with list of the successive amendments Annex IV contains a correlation table. 🡻 715/2009 (adapted) ⇨ new 2021/0424 (COD)

Proposal for a REGULATION OF THE EUROPEAN PARLIAMENT AND OF THE COUNCIL on conditions for access to the the internal markets for renewable and natural gases gas transmission networksand for hydrogen and repealing Regulation (EC) No 1775/2005 (recast) THE EUROPEAN PARLIAMENT AND THE COUNCIL OF THE EUROPEAN UNION, Having regard to the Treaty establishing the European Community ⌦ Treaty on the Functioning of the European Union ⌫ , and in particular Article 95 ⌦ 194 (2) ⌫ thereof, Having regard to the proposal from the European Commission, After transmission of the draft legislative act to the national parliaments Having regard to the opinion of the European Economic and Social Committee, Having regard to the opinion of the Committee of the Regions, Acting in accordance with the ordinary legislative procedure, Whereas: ⇩ new (1)Regulation (EU) No 715/2009 of the European Parliament and of the Council has been substantially amended several times. Since further amendments are to be made, that Regulation should be recast in the interests of clarity. 🡻 715/2009 recital 1 (adapted) (2)The internal market in natural gas, which has been progressively implemented since 1999, aims to deliver real choice for all consumers in the Community ⌦ Union ⌫ , be they citizens or businesses, new business opportunities and more cross-border trade, so as to achieve efficiency gains, competitive prices and higher standards of service, and to contribute to security of supply and sustainability. ⇩ new (3)The European Green Deal and the Climate law set the target for the EU to become climate neutral by 2050 in a manner that contributes to European competitiveness, growth and jobs. For a decarbonised gas markets to be set up and contribute to the energy transition, significantly higher shares of renewable energy sources in an integrated energy system with an active participation of consumers in competitive markets are needed.

(4)This Regulation aims to facilitate the penetration of renewable and low-carbon gases into the energy system enabling a shift from fossil gas, and to allow these new gases to play an important role towards achieving the EU’s 2030 climate objectives and climate neutrality in 2050. The Regulation aims also to set up a regulatory framework that enables and incentivises all market participants to take the transitional role of fossil gas into account while planning their activities to avoid lock-in effects and ensure gradual and timely phase-out of fossil gas notably in all relevant industrial sectors and for heating purposes. (5)The EU hydrogen strategy recognises that, as EU Member States have different potential for the production of renewable hydrogen, an open and competitive EU market with unhindered cross-border trade has important benefits for competition, affordability, and security of supply. Moreover, it stresses that moving towards a liquid market with commodity-based hydrogen trading would facilitate entry of new producers and be beneficial for deeper integration with other energy carriers. It would create viable price signals for investments and operational decisions. The rules laid down in this Regulation should thus be conducive for hydrogen markets and commodity-based hydrogen trading and liquid trading hubs to emerge and any undue barriers in this regard should be eliminated by Member States. Whilst recognising the inherent differences, existing rules that enabled efficient commercial operations developed for the electricity and gas markets and trading should be considered for a hydrogen market. 🡻 715/2009 recital 2 Directive 2003/55/EC of the European Parliament and of the Council of 26 June 2003 concerning common rules for the internal market in natural gas and Regulation (EC) No 1775/2005 of the European Parliament and of the Council of 28 September 2005 on conditions for access to the natural gas transmission networks have made significant contributions towards the creation of such an internal market in natural gas. 🡻 715/2009 recital 3 Experience gained in the implementation and monitoring of a first set of Guidelines for Good Practice, adopted by the European Gas Regulatory Forum (the Madrid Forum) in 2002, demonstrates that in order to ensure the full implementation of the rules set out in those guidelines in all Member States, and in order to provide a minimum guarantee of equal market access conditions in practice, it is necessary to provide for them to become legally enforceable. 🡻 715/2009 recital 4 A second set of common rules entitled ‘the Second Guidelines for Good Practice’ was adopted at the meeting of the Madrid Forum on 24 and 25 September 2003 and the purpose of this Regulation is to lay down, on the basis of those guidelines, basic principles and rules regarding network access and third party access services, congestion management, transparency, balancing and the trading of capacity rights. 🡻 715/2009 recital 5 (adapted) (6)⌦ [Recast Gas Directive as proposed in COM(2021) xxx] ⌫ Directive 2009/73/EC of the European Parliament and of the Council of 13 July 2009 concerning common rules for the internal market in natural gas provides for the possibility of a combined transmission and distribution system operator. The rules set out in this Regulation do not therefore require modification of the organisation of national transmission and distribution systems that are consistent with the relevant provisions of that Directive. 🡻 715/2009 recital 6 High-pressure pipelines linking up local distributors to the gas network which are not primarily used in the context of local distribution are included in the scope of this Regulation. 🡻 715/2009 recital 7 ⇨ new

(7)It is necessary to specify the criteria according to which tariffs for access to the network are determined, in order to ensure that they fully comply with the principle of non-discrimination and the needs of a well-functioning internal market and take fully into account the need for system integrity and reflect the actual costs incurred, insofar as such costs correspond to those of an efficient and structurally comparable network operator and are transparent, whilst including appropriate return on investments, ⇨ and enabling the integration of renewable and low carbon gases ⇦ and, where appropriate, taking account of the benchmarking of tariffs by the regulatory authorities. ⇨ The rules on network access tariffs in this Regulation are complemented by further rules on network access tariffs, notably in the network codes and guidelines adopted on the basis of this Regulation, in [ TEN-E Regulation as proposed in COM(2020) 824 final], [Methane Regulation as proposed in COM(2021) xxx], Directive (EU) 2018/2001 and [Energy Efficiency Directive as proposed in COM(2021) 558 final]. ⇦ ⇩ new (8)It is, generally, most efficient to finance infrastructure by revenues obtained from the users of that infrastructure and to avoid cross-subsidies. Moreover, such cross-subsidies would, in the case of regulated assets, be incompatible with the general principle of cost-reflective tariffs. In exceptional cases, such cross-subsidies could nonetheless bring societal benefits, in particular during earlier phases of network development where booked capacity is low compared to technical capacity and uncertainty as to when future capacity demand will materialise is significant. Cross-subsidies could therefore contribute to reasonable and predictable tariffs for early network users and de-risk investments for network operators. Cross-subsidies could thus contribute to an investment climate supportive to the Union’s, decarbonisation objectives. Cross-subsidies should not be financed by network users in other Member States, regardless as to whether directly or indirectly. It is thus appropriate to collect financing for cross-subsidies only from exit points to final customers within the same Member State. Moreover, as cross-subsidies are exceptional, it should be ensured that they are proportional, transparent, limited in time and set under regulatory supervision. 🡻 715/2009 recital 8 In calculating tariffs for access to networks, it is important to take account of the actual costs incurred, insofar as such costs correspond to those of an efficient and structurally comparable network operator, and are transparent, as well as of the need to provide appropriate return on investments and incentives to construct new infrastructure, including special regulatory treatment for new investments as provided for in Directive 2009/73/EC. In that respect, and in particular if effective pipeline-to-pipeline competition exists, the benchmarking of tariffs by the regulatory authorities will be a relevant consideration. 🡻 715/2009 recital 9 (adapted) ⇨ new (9)The use of market-based arrangements, such as auctions, to determine tariffs has to be compatible with the provisions laid down in ⌦ recast Gas Directive as proposed in COM(2021) xxx ⌫ Directive 2009/73/EC ⇨ and Commission Regulation (EU) 2017/459 ⇦. 🡻 715/2009 recital 10 (adapted) (10)A common minimum set of third-party access services is necessary to provide a common minimum standard of access in practice throughout the Community ⌦ Union ⌫, to ensure that third-party access services are sufficiently compatible and to allow the benefits accruing from a well-functioning internal market in natural gas to be exploited. 🡻 715/2009 recital 11 (adapted) At present, there are obstacles to the sale of gas on equal terms, without discrimination or disadvantage in the Community. In particular, non-discriminatory network access and an equally effective level of regulatory supervision do not yet exist in each Member State, and isolated markets persist. ⇩ new

(11)Arrangements on third party access should be based on the principles laid down in this Regulation. The organisation of entry-exit systems, which enable a free allocation of gas on the basis of firm capacity, was welcomed by the XXIV. Madrid Forum already in October 2013. Therefore a definition of entry-exit system should be introduced and the integration of the distribution system level in the balancing zone be ensured, which would help to achieve a level playing field for renewable and low carbon gases connected to either the transmission or distribution level. Tariff setting for distribution system operators and the organisation of capacity allocation between the transmission and distribution system should be left to the regulatory authorities on the basis of the principles enshrined in [recast Gas Directive as proposed in COM(2021) xxx]. (12)Access to the entry-exit system should be generally based on firm capacity. Network operators should be required to cooperate in a way that maximises the offer of firm capacity, which in turn enables network users to freely allocate the gas entering or exiting on the basis of firm capacity to any entry or exit point in the same entry-exit system. (13)Conditional capacity should only be offered when network operators are not able to offer firm capacity. Network operators should define the conditions for conditional capacity on the basis of operational constraints in a transparent and clear manner. The regulatory authority should ensure that the number of conditional capacity products is limited to avoid a fragmentation of the market and to ensure compliance with the principle of providing efficient third-party access. 🡻 715/2009 recital 12 (14)A sufficient level of cross-border gas interconnection capacity should be achieved and market integration fostered in order to complete the internal market in natural gas. 🡻 715/2009 recital 13 The Communication of the Commission of 10 January 2007 entitled ‘An Energy Policy for Europe’ highlighted the importance of completing the internal market in natural gas and creating a level playing field for all natural gas undertakings in the Community. The Communications of the Commission of 10 January 2007 entitled ‘Prospects for the internal gas and electricity market’ and ‘Inquiry pursuant to Article 17 of Regulation (EC) No 1/2003 into the European gas and electricity sectors (Final Report)’ demonstrated that the present rules and measures neither provide the necessary framework nor provide for the creation of interconnection capacities to achieve the objective of a well-functioning, efficient and open internal market. 🡻 715/2009 recital 14 In addition to thoroughly implementing the existing regulatory framework, the regulatory framework for the internal market in natural gas set out in Regulation (EC) No 1775/2005 should be adapted in line with those communications. 🡻 715/2009 recital 15 (adapted) ⇨ new (15)In particular, iIncreased cooperation and coordination among transmission ⇨ and, where relevant, distribution ⇦ system operators is required to create network codes for providing and managing effective and transparent access to the transmission networks across borders, and to ensure coordinated and sufficiently forward looking planning and sound technical evolution of the transmission ⇨natural gas⇦ system in the Community ⌦ Union ⌫, including the creation of interconnection capacities, with due regard to the environment. The network codes should be in line with framework guidelines which are non-binding in nature (framework guidelines) and which are developed by the ⌦ European Union ⌫ Agency for the Cooperation of Energy Regulators ⌦ (ACER) ⌫ established ⌦ in accordance with ⌫ by Regulation (EU) 2019/942 (EC) No 713/2009 of the European Parliament and of the Council of 13 July 2009 establishing an Agency for the Cooperation of Energy Regulators (the Agency). ⌦ ACER ⌫ The Agency should have a role in reviewing, based on matters of fact, draft network codes, including their compliance with the framework guidelines, and it should be enabled to recommend them for adoption by the Commission. ⌦ ACER ⌫ The Agency should assess proposed amendments to the network codes and it should be enabled to recommend them for adoption by the Commission. Transmission system operators should operate their networks in accordance with those network codes. 🡻 715/2009 recital 16 (adapted) ⇨ new (16)In order to ensure optimal management of the gas transmission network in the Community ⌦ Union, ⌫ a European Network of Transmission System Operators for Gas (the ENTSO for Gas), should be ⌦ provided for ⌫ established. The tasks of the ENTSO for Gas should be carried out in compliance with Community ⌦ the Union’s ⌫ competition rules which remain ⌦ are ⌫ applicable to the decisions of the ENTSO for Gas. The tasks of the ENTSO for Gas should be well-defined and its working method should ensure efficiency, transparency and the representative nature of the ENTSO for Gas. The network codes prepared by the ENTSO for Gas are not intended to replace the necessary national network codes for non cross-border issues. Given that more effective progress may be achieved through an approach at regional level, transmission system operators should set up regional structures within the overall cooperation structure, whilst ensuring that results at regional level are compatible with network codes and non-binding ten-year network development plans at ⌦ Union ⌫ Community level. Cooperation within such regional structures presupposes effective unbundling of network activities from production and supply activities. In the absence of such unbundling, regional cooperation between transmission system operators gives rise to a risk of anti-competitive conduct. Member States should promote cooperation and monitor the effectiveness of the network operations at regional level. Cooperation at regional level should be compatible with progress towards a competitive and efficient internal market in gas ⇨ gases ⇦.

🡻 715/2009 recital 17 (new) All market participants have an interest in the work expected of the ENTSO for Gas. An effective consultation process is therefore essential and existing structures set up to facilitate and streamline the consultation process, such as the European Association for the Streamlining of Energy Exchange, national regulators or the Agency should play an important role. 🡻 715/2009 recital 18 (adapted) ⇨ new (17)In order to ensure greater transparency regarding the development of the gas transmission network in the Community ⌦ Union ⌫ , the ENTSO for Gas should draw up, publish and regularly update a non-binding Community ⌦ Union ⌫-wide ten-year network development plan ⇨ on the basis of a joint scenario and the interlinked model ⇦ (Community ⌦ Union ⌫-wide network development plan). Viable gas transmission networks and necessary regional interconnections, relevant from a commercial or security of supply point of view, should be included in that network development plan. 🡻 715/2009 recital 19 ⇨ new (18)To enhance competition through liquid wholesale markets for gas, it is vital that gas can be traded independently of its location in the system. The only way to do this is to give network users the freedom to book entry and exit capacity independently, thereby creating gas transport through zones instead of along contractual paths. ⇨ To ensure the freedom of booking capacity independently at entry and exit points, tariffs set for one entry point should therefore not be related to the tariff set for one exit point, and vice versa offered for these points separately and the tariff should not bundle the entry and exit charge in a single price. ⇦ The preference for entry-exit systems to facilitate the development of competition was already expressed by most stakeholders at the 6th Madrid Forum on 30 and 31 October 2002. Tariffs should not be dependent on the transport route. The tariff set for one or more entry points should therefore not be related to the tariff set for one or more exit points, and vice versa. ⇩ new (19)While Commission Regulation (EU) 312/2014 establishing a Network Code on Gas Balancing of Transmission Networks provides rules for setting up technical rules that build up a balancing regime, it leaves various design choices for each balancing regime that is applied in a specific entry-exit system. The combination of choices made lead to a specific balancing regime that is applicable in a specific entry-exit system, which are currently mostly reflecting Member States territories. (20)Network users are to bear the responsibility of balancing their inputs against their off-takes with trading platforms established to better facilitate gas trade between network users. In order to better integrate renewable and low carbon gases within the entry-exit system, the balancing zone should also cover the distribution system level. The virtual trading point should be used to exchange gas between balancing accounts of network users. 🡻 715/2009 recital 20 (21)References to harmonised transport contracts in the context of non-discriminatory access to the network of transmission system operators do not mean that the terms and conditions of the transport contracts of a particular system operator in a Member State must be the same as those of another transmission system operator in that Member State or in another Member State, unless minimum requirements are set which must be met by all transport contracts. 🡻 715/2009 recital 21

There is substantial contractual congestion in the gas networks. The congestion-management and capacity-allocation principles for new or newly negotiated contracts are therefore based on the freeing-up of unused capacity by enabling network users to sublet or resell their contracted capacities and the obligation of transmission system operators to offer unused capacity to the market, at least on a day-ahead and interruptible basis. Given the large proportion of existing contracts and the need to create a true level playing field between users of new and existing capacity, those principles should be applied to all contracted capacity, including existing contracts. 🡻 715/2009 recital 22 Although physical congestion of networks is, at present, rarely a problem in the Community, it may become one in the future. It is important, therefore, to provide the basic principle for the allocation of congested capacity in such circumstances. 🡻 715/2009 recital 23 Market monitoring undertaken over recent years by the national regulatory authorities and by the Commission has shown that current transparency requirements and rules on access to infrastructure are not sufficient to secure a genuine, well-functioning, open and efficient internal market in gas. 🡻 715/2009 recital 24 (22)Equal access to information on the physical status and efficiency of the system is necessary to enable all market participants to assess the overall demand and supply situation and to identify the reasons for movements in the wholesale price. This includes more precise information on supply and demand, network capacity, flows and maintenance, balancing and availability and usage of storage. The importance of that information for the functioning of the market requires alleviating existing limitations to publication for confidentiality reasons. 🡻 715/2009 recital 25 (23)Confidentiality requirements for commercially sensitive information are, however, particularly relevant where data of a commercially strategic nature for the company are concerned, where there is only one single user for a storage facility, or where data are concerned regarding exit points within a system or subsystem that is not connected to another transmission or distribution system but to a single industrial final customer, where the publication of such data would reveal confidential information as to the production process of that customer. 🡻 715/2009 recital 26 (24)To enhance trust in the market, its participants need to be sure that those engaging in abusive behaviour can be subjected to effective, proportionate and dissuasive penalties. The competent authorities should be given the competence to investigate effectively allegations of market abuse. To that end, it is necessary that competent authorities have access to data that provides information on operational decisions made by supply undertakings. In the gas market, all those decisions are communicated to the system operators in the form of capacity reservations, nominations and realised flows. System operators should keep information in relation thereto available to and easily accessible by the competent authorities for a fixed period of time. The competent authorities should, furthermore, regularly monitor the compliance of the transmission system operators with the rules. 🡻 715/2009 recital 27 ⇨ new (25)Access to ⇨ natural⇦ gas storage facilities and liquefied natural gas (LNG) facilities is insufficient in some Member States, and therefore the implementation of the existing rules needs to be improved ⇨ , including in the transparency area. Such improvement should take into account the potential and uptake of renewable and low-carbon gases for these facilities in the internal market. ⇦ Monitoring by the European Regulators' Group for Electricity and Gas concluded that the voluntary guidelines for good third-party access practice for storage system operators, agreed by all stakeholders at the Madrid Forum, are being insufficiently applied and therefore need to be made binding.

🡻 715/2009 recital 28 ⇨ new (26)Non-discriminatory and transparent balancing systems for ⇨ natural ⇦ gas, operated by transmission system operators, are important mechanisms, particularly for new market entrants which may have more difficulty balancing their overall sales portfolio than companies already established within a relevant market. It is therefore necessary to lay down rules to ensure that transmission system operators operate such mechanisms in a manner compatible with non-discriminatory, transparent and effective access conditions to the network. 🡻 715/2009 recital 29 The trading of primary capacity rights is an important part of developing a competitive market and creating liquidity. This Regulation should therefore lay down basic rules relating to such trading. 🡻 715/2009 recital 30 ⇨ new (27)National rRegulatory authorities should ensure compliance with the rules contained in this Regulation ⇨ and the network codes and ⇦ gGuidelines adopted pursuant thereto. 🡻 715/2009 recital 31 (adapted) ⇨ new (28)In the gGuidelines annexed to this Regulation, specific ⌦ more ⌫ detailed implementing rules are defined on the basis of the Second Guidelines for Good Practice. Where appropriate, those rules will ⇨ should ⇦ evolve over time, taking into account the differences of national gas systems ⇨ and their development ⇦ . 🡻 715/2009 recital 32 (29)When proposing to amend the Guidelines annexed to this Regulation, the Commission should ensure prior consultation of all relevant parties concerned with the Guidelines, represented by the professional organisations, and of the Member States within the Madrid Forum. 🡻 715/2009 recital 33

(30)The Member States and the competent national authorities should be required to provide relevant information to the Commission. Such information should be treated confidentially by the Commission. 🡻 715/2009 recital 34 (adapted) ⇨ new (31)This Regulation and the ⇨ network codes ⇦ and gGuidelines adopted in accordance with it are without prejudice to the application of the Community⌦ Union ⌫ rules on competition. 🡻 715/2009 recital 35 (new) The measures necessary for the implementation of this Regulation should be adopted in accordance with Council Decision 1999/468/EC of 28 June 1999 laying down the procedures for the exercise of implementing powers conferred on the Commission. 🡻 715/2009 recital 36 (new) In particular, the Commission should be empowered to establish or adopt the Guidelines necessary for providing the minimum degree of harmonisation required to achieve the aims of this Regulation. Since those measures are of general scope and are designed to amend non-essential elements of this Regulation, inter alia by supplementing it with new non-essential elements, they must be adopted in accordance with the regulatory procedure with scrutiny provided for in Article 5a of Decision 1999/468/EC. ⇩ new (32)Member States and the Energy Community Contracting Parties should closely cooperate on all matters concerning the development of an integrated gas trading region and should take no measures that endanger the further integration of natural gas markets or the security of supply of Member States and Contracting Parties. (33)Transmission system operators could be allowed to reserve storages for natural gas exclusively for carrying out their functions and for the purpose of security of supply. The filling of these strategic stocks could be done by means of joint purchasing using the trading platform as mentioned in Article 10 of Commission Regulation (EU) No 312/2014 without prejudice to Union competition rules. Withdrawal of natural gas should only be possible for the transmission system operators to carry out their functions or in case of a declared emergency situation, as mentioned in Article 11 (1) of that Regulation, in order not to interfere with the regular functioning of the market. (34)Where a regional markets integration is undertaken, the relevant transmission system operators and regulatory authorities should address issues having a cross-border impact such as tariff structures, balancing regime, capacities at remaining cross-border points, investment plans and the fulfilment of transmissions system operators’ and regulatory authorities’ tasks. (35)The energy transition and the continuing integration of the gas market will require further transparency on the allowed or target revenue of the transmission system operator. A number of decisions related to natural gas networks will be based on that information. For example, the transfer of transmission assets from a natural gas network to a hydrogen network or the implementation of an inter-TSO compensation mechanism (ITC) require more transparency than currently exists. In addition, the assessments of tariff evolutions on the long term requires clarity on both natural gas demand and cost projections. Transparency on allowed revenue should enable the latter. Regulatory authorities should, in particular, provide information on the methodology used to calculate the revenues of transmission system operators, the value of their regulatory asset base and its depreciation over time, the value of operational expenditures, the cost of capital applied to transmission system operators and the incentives and premia applied. (36)Transmission system operators’ expenditures are predominantly fixed costs. Their business model and the current national regulatory frameworks rely on the assumption of a long-term utilisation of their networks entailing long depreciation periods (30 to 60 years). In the context of the energy transition, regulatory authorities should therefore be able to anticipate gas demand decrease to modify the regulatory arrangements in due time and prevent a situation where the cost recovery of transmission system operators through tariffs threatens the affordability for consumers due to an increasing ratio of fixed costs to gas demand. Where necessary, the depreciation profile or remuneration of transmission assets could, for example, be modified. (37)Transparency on transmission system operators allowed or target revenue should be increased to enable benchmarking and an assessment by network users. Increased transparency should also facilitate cross-border cooperation and the setting up of ITC mechanisms between operators either for regional integration or for the implementation of tariff discounts for renewable and low carbon gases as set out in this Regulation. (38)In order to exploit the most economic locations for the production of renewable and low carbon gases, network users should benefit from discounts in capacity-based tariffs. These should include a discount for injection from renewable and low carbon gases production facilities, a discount for tariffs at entry points from and exit points to storage facilities and a discount on the cross-border tariff and entry points from LNG facilities. In case of a change of the value of non-cross border discounts, the regulatory authority needs to balance out the interest between networks users and network operators taking into account stable financial frameworks specifically for existing investments, in particular for renewable production facilities. Where possible, indicators or conditions for changing the discount should be provided sufficiently before any decision to change the discount is taken. This discount should not affect the general tariff setting methodology, but should be provided ex-post on the relevant tariff. In order to benefit from the discount, network users should present the required information towards the transmission system operator on the basis of a certificate which would be linked to the union database.

(39)Revenue decreases from the application of discounts shall be treated as general revenue decreases, e.g. from reduced capacity sales and need to be recovered via tariffs in a timely manner, for instance by an increase of the specific tariffs following the general rules contained in Article 15 of this Regulation. The Commission should be empowered to change the discount levels via delegated acts to mitigate structural imbalances of revenues for transmission system operators. (40)In order to increase efficiencies in the natural gas distribution networks in the Union and to ensure close cooperation with transmission system operators and the ENTSO for Gas, an entity of distribution system operators in the Union (‘EU DSO entity’) should be provided for which also includes natural gas distribution system operators. The tasks of the EU DSO entity should be well-defined and its working method should ensure efficiency, transparency and representativeness among Union distribution system operators. The EU DSO entity should closely cooperate with the ENTSO for Gas on the preparation and implementation of the network codes where applicable and should work on providing guidance on the integration inter alia of distributed generation and other areas, which relate to the management of distribution networks. (41)Distribution system operators have an important role to play when it comes to the integration of renewable and low carbon gases into the system, as for example about half of the biomethane production capacity is connected to the distribution grid. In order to facilitate the participation of these gases in the wholesale market, production facilities connected to the distribution grid in all Member States should have access to the virtual trading point. Furthermore in accordance with the provisions of this Regulation distribution system operators and transmission system operators should work together to enable reverse flows from the distribution to the transmission network or to ensure the integration of the distribution system through alternative means, equivalent in effect, to facilitate the market integration of renewable and low carbon gases. (42)The integration of growing volumes of renewable and low-carbon gases in the European natural gas system will change the quality of natural gas transported and consumed in Europe. To ensure unhindered cross-border flow of natural gas, maintain the interoperability of markets and enable market integration, it is necessary to increase transparency on gas quality and on the costs of its management, provide for a harmonised approach on the roles and responsibilities of regulatory authorities and system operators and reinforce cross-border coordination. While ensuring a harmonised approach on gas quality for cross-border interconnection points, Member States’ flexibility as regards the application of gas quality standards in their domestic natural gas systems should be maintained. (43)The blending of hydrogen into the natural gas system is less efficient compared to using hydrogen in its pure form and diminishes the value of hydrogen. It also affects the operation of gas infrastructure, end-user applications, and the interoperability of cross-border systems. The Member States’ decision on whether to apply blending hydrogen in their national natural gas systems should be preserved. At the same time, a harmonised approach on blending hydrogen into the natural gas system in the form of a Union-wide allowed cap at cross-border interconnection points between Union Member States, where transmission system operators have to accept natural gas with a blended hydrogen level below the cap, would limit the risk of market segmentation. Adjacent transmission systems should remain free to agree on higher hydrogen blending levels for cross-border interconnection points. (44)A strong cross-border coordination and dispute settlement process between transmission system operators on gas quality, including on biomethane and hydrogen blends, is essential to facilitate efficient transport of natural gas across natural gas systems within the Union and thereby to move towards greater internal market integration. Enhanced transparency requirements on gas quality parameters, including on gross calorific value, Wobbe Index and oxygen content, and hydrogen blends and their development over time combined with monitoring and reporting obligations should contribute to the well-functioning of an open and efficient internal market in natural gas. (45)In order to amend non-essential elements of this Regulation and to supplement this Regulation in respect of non-essential elements of certain specific areas which are fundamental for market integration, the power to adopt acts in accordance with Article 290 of the Treaty on the Functioning of the European Union should be delegated to the Commission. It is of particular importance that the Commission carry out appropriate consultations during its preparatory work, including at expert level, and that those consultations be conducted in accordance with the principles laid down in the Interinstitutional Agreement of 13 April 2016 on Better Law-Making. In particular, to ensure equal participation in the preparation of delegated acts, the European Parliament and the Council should receive all documents at the same time as Member States' experts, and their experts should systematically have access to meetings of Commission expert groups dealing with the preparation of delegated acts. (46)Commission Regulation (EU) 2015/703 sets out interoperability and data exchange rules for the natural gas system, in particular with respect to interconnection agreements, including rules for flow control, measurement principles for gas quantity and quality, rules for the matching process and for the allocation of gas quantities, communication procedures in case of exceptional events; common set of units, gas quality, including rules on managing cross-border trade restrictions due to gas quality differences and due to differences in odorisation practices, short- and long-term gas quality monitoring and information provision; data exchange, and reporting on gas quality; transparency, communication, information provision and cooperation among relevant market participants. (47)In order to ensure optimal management of the Union hydrogen network and to allow trading and supplying hydrogen across borders in the Union, a European Network of Network Operators for Hydrogen (‘ENNOH’) should be established. The tasks of the ENNOH should be carried out in compliance with Union competition rules. The tasks of the ENNOH should be well-defined and its working method should ensure efficiency, transparency and the representative nature of the ENNOH. The network codes prepared by ENNOH should not replace the necessary national network codes for non cross-border issues. (48)Until the ENNOH is established, a temporary platform should be set up under the lead of the Commission with the involvement of ACER and all relevant market participants, including the ENTSO for Gas, the ENTSO for Electricity and the EU DSO entity. This platform should support early work on scoping and developing issues relevant for the building up of the hydrogen network and markets without formal decision-making powers. The platform should be dissolved once ENNOH is established. Until the ENNOH is established, the ENTSO for Gas will be responsible for the development of Union-wide network development plans, including hydrogen networks. (49)In order to ensure transparency regarding the development of the hydrogen network in the Union, the ENNOH should establish, publish and regularly update a non-binding Union-wide ten-year network development plan for hydrogen targeted at the needs of the developing hydrogen markets. Viable hydrogen transportation networks and necessary interconnections, relevant from a commercial point of view, should be included in that network development plan. The ENNOH should participate in the development of the energy system wide cost-benefit analysis – including the interlinked energy market and network model including electricity, gas and hydrogen transport infrastructure as well as storage, LNG and electrolysers –, the scenarios for the ten-year network development plans and the infrastructure gaps identification report as set out in Articles 11, 12 and 13 of [the TEN-E Regulation as proposed in COM(2020) 824 final] for the development of the lists of projects of common interest. For that purpose, the ENNOH should closely cooperate with the ENTSO for Electricity and the ENTSO for Gas to facilitate system integration. The ENNOH should undertake those tasks for the first time for the development of the 8th list of projects of common interest, provided it is operational and in the position to deliver the necessary input to the ten-year network development plan by 2026. (50)All market participants have an interest in the work expected of the ENNOH. An effective consultation process is therefore essential. Overall, ENNOH should seek, build on and integrate in its work experience with infrastructure planning, development and operation in cooperation with other relevant market participants and their associations. (51)Given that more effective progress may be achieved through an approach at regional level, hydrogen network operators should set up regional structures within the overall cooperation structure, while ensuring that results at regional level are compatible with network codes and Union-wide non-binding ten-year network development plans. Member States should promote cooperation and monitor the effectiveness of the network at regional level. (52)Transparency requirements are necessary to ensure that trust in the emerging hydrogen markets in the Union can develop among market participants. Equal access to information on the physical status and functioning of the hydrogen system is necessary to enable all market participants to assess the overall demand and supply situation and to identify the reasons for market price developments. Information should be always disclosed in a meaningful and easily accessible manner and on a non-discriminatory basis. (53)The ENNOH will establish a central, web-based platform for making available all data relevant for market participants to gain effective access to the network. (54)The conditions for access to hydrogen networks in the early phase of market development should ensure efficient operation, non-discrimination and transparency for network users while preserving sufficient flexibility for operators. Limiting the maximum duration of capacity contracts should reduce the risk of contractual congestion and capacity hoarding. (55)General conditions for granting third-party access to hydrogen storage facilities and hydrogen terminals should be set out in order to ensure non-discriminatory access and transparency for network users. (56)Hydrogen network operators should cooperate to create network codes for providing and managing transparent and non-discriminatory access to the networks across borders and to ensure coordinated development of the network in the Union, including the creation of interconnection capacities. The network codes should be in line with non-binding framework guidelines developed by ACER. ACER should have a role in reviewing, based on matters of fact, draft network codes, including their compliance with the framework guidelines, and it should be enabled to recommend them for adoption by the Commission. ACER should assess proposed amendments to the network codes and it should be enabled to recommend them for adoption by the Commission. Hydrogen network operators should operate their networks in accordance with those network codes. (57)The network codes prepared by the ENNOH are not intended to replace the necessary national rules for non-cross-border issues. (58)The quality of hydrogen transported and consumed in Europe can vary depending on its production technology and transportation specificities. Therefore, a harmonised approach at Union level to hydrogen quality management at